liquefied natural gas (lng) floating storage & regasification terminal

1

Government of Jamaica

Liquefied Natural Gas (LNG)

Floating Storage & Regasification

Terminal

August 31, 2011

2 Section I. Instruction to Bidders

Acronyms BDS Bid Data Sheet BOD Basis of Design BOT Build, Own, Operate and Transfer CFR Cost and Freight CIF Cost, Insurance and Freight CIP Carriage and Insurance Paid to (named place of destination) CPM Critical Path Method CPT Carriage Paid to CV Curriculum Vitae DAF Delivery at Frontier DAT Delivery at Terminal DDP Delivered Duty Paid (named place of destination) DDU Delivered Duty Unpaid DES Delivered Ex Ship DEQ Delivered Ex Quay EXW Ex factory, ex works or ex warehouse FAS Free alongside Ship FCA Free Carrier FEED Front End Engineering Design FIDIC Fédération Internationale des Ingénieurs Conseils (International

Federation of Consulting Engineers) FOB Free on Board FSRU Floating Storage and Regasification Unit FSU Floating Storage Unit GCC General Conditions of Contract GOJ Government of Jamaica GSA Gas Sales Agreement HFO Heavy Fuel Oil HH Henry Hub HSE Health, Safety and Environment ICC International Chamber of Commerce IFB Invitation for Bids ITB Instructions to Bidders JEP Jamaica Energy Partners JGT Jamaica Gas Trust JPS Jamaica Public Service Company Limited JVCA Joint Venture, Consortium or Association

Section I. Instruction to Bidders 3

LNG Liquefied Natural Gas LNGC LNG Carrier LOC Letter of Credit MOU Memorandum of Understanding NCC National Contracts Commission NEP National Energy Policy OCG Office of the Contractor General ORF Onshore Receiving Facility OT Open Tender OUR Office of Utilities Regulation PAJ Port Authority of Jamaica PCJ Petroleum Corporation of Jamaica PEP Project Execution Plan QAQC Quality Assurance/Quality Control RFP Request for Proposal SBD Standard Bidding Document SBLC Standby Letter of Credit SCC Special Conditions of Contract SPV Special Purpose Vehicle SRT Storage and Regasification Terminal TS Technical Specifications and Drawings TUA Teminal Use Agreement


Glossary

Procuring Entity The Government of Jamaica acting on behalf of the Jamaica Gas Trust

Project The Jamaica LNG Project which is comprised of the development and operation of a LNG SRT in Jamaica.

Contractor The legal entity that is party to and performs a works contract, the other party to the contract being the “Procuring Entity.”

Cabinet The executive and policy making arm of the Government of Jamaica.

joint venture An ad hoc association of firms that pool their resources and skills to undertake a large or complex contract in the role of “Contractor,” with all firms (partners in the JV) being legally liable, jointly and severally, for the execution of the contract in the event of a partner’s withdrawal.

subcontractor An individual or company hired by a Contractor to perform a specific task or portion of the contracted Works.

Works The total work involvement in the Build – Own – Operate – Transfer (BOT) of the LNG SRT, as is more specifically described in Section V, Works Requirements.

In writing For the purpose of this document, means authenticated handwritten, typed, or printed; a document prepared in writing can be transmitted by telex, electronic mail, facsimile, with proof of receipt; and in the form requested by the sender.


B I D D I N G D O C U M E N T S Issued on: August 31, 2011

for

Procurement of Liquefied Natural Gas (LNG)

Floating Storage & Regasification Terminal

ICB: 2011/L002

Project: Jamaica LNG Project

Procuring Entity: Government of Jamaica, on behalf of the Jamaica Gas Trust


Table of Contents

PART 1 – Bidding Procedures ..............................................................................................7 Introduction ....................................................................................................................8 Background ....................................................................................................................9 Market ............................................................................................................................9 Jamaica Energy Regulation..........................................................................................11 Project Organization ....................................................................................................13 Commercial Structure ..................................................................................................15 Credit Requirements ....................................................................................................17 Information Memorandum ...........................................................................................17 Clean Development Mechanism (CDM) .....................................................................18 RFP Schedule ...............................................................................................................18 Section I. Instructions to Bidders ................................................................................19 General Requirements ..................................................................................................21 Project Execution Plan .................................................................................................21 Project Organization ....................................................................................................21 Project Planning & Master Schedule ...........................................................................22 Procurement/ Sub-Contracting .....................................................................................23 Quality Assurance and Quality Control .......................................................................23 Health, Safety, Security and Environment Management .............................................24 Project Risk Management Plan ....................................................................................24 Section II. Bid Data Sheet ...........................................................................................47 Section III. Evaluation and Qualification Criteria ......................................................52 Section IV. Bidding Forms .........................................................................................54

PART 2 –Works Requirements ...........................................................................................61 Section V. Works Requirements .................................................................................62

PART 3 – Conditions of Contract and Contract Forms ................................................63

PART 4 – Attachments .........................................................................................................78 Attachment 01 - Information Memorandum ................................................................79 Attachment 02 - Basis of Design .................................................................................80 Attachment 03 - SRT Scope of Work ..........................................................................81 Attachment 04 - Pipeline & ORF Scope of Work .......................................................82 Attachment 05 - Pipeline & ORF Functional Specification ........................................83 Attachment 06 - Regas Plant Functional Specification ...............................................84 Attachment 07 - FSRU Functional Specification ........................................................85 Attachment 08 - Jetty Design Philosophy ....................................................................86 Attachment 09 - Pipeline & ORF Operating Philosophy.............................................87 Attachment 10 - FSRU Operating Philosophy.............................................................88 Attachment 11 - Personnel CV Forms .........................................................................89 Attachment 12 - Financial Resources Forms ...............................................................92 Attachment 13 - Letter from the Caribbean Coast Area Management Foundation

(C-CAM) ..........................................................................................................94 Attachment 14 - National Environment & Planning Agency (NEPA), Permit

Roadmap for LNG Project ...............................................................................95


PART 1 – BIDDING PROCEDURES


Introduction To improve its international competitiveness and reduce its dependence on

imported petroleum, the Government of Jamaica (GOJ) has implemented a

strategy to diversify its energy supply. The strategy aims at introducing

natural gas into Jamaica’s energy supply mix to obtain security of supplies and

achieve long-term stability in energy prices and environmental sustainability in

energy provision.

Under this strategy, it is proposed to import liquefied natural gas (LNG) to

Jamaica under long-term contractual arrangements and vaporize such LNG,

initially to meet the needs of power generation and bauxite/alumina

production. The initial estimate of demand in these sectors is equivalent to

approximately 0.8 million tonnes of LNG per year, with the expansion of the

bauxite/alumina sector and construction of new Independent Power Producers

(IPPs) likely to raise the base LNG demand to around 2.5 million tonnes per year

by 2025. It is expected that the importation of LNG will help to spur additional

industrial and commercial growth that would benefit from the availability of

natural gas and lower energy prices.

In order to execute on this plan to diversify its energy supply with the

importation of LNG, the GOJ has approved the issuance of two Requests for

Proposals (RFPs), one for LNG Supply and the other for the Infrastructure

required for the receiving, storage and re-gasification of the LNG. These RFPs

will be issued concurrently in order to provide close coordination between the

processes. A draft of the Terminal Use Agreement (TUA) will be made available

by September 21, 2011 and will be posted on the website at

http://www.cabinet.gov.jm/procurement.

http://www.cabinet.gov.jm/procurement�


Background Jamaica has been exploring the option of introducing natural gas as an

alternative fuel since 2001. The initiative was conceived to derive benefit for

Jamaica by lessening its near total dependency on oil products and its exposure

to the volatility inherent in the international oil markets.

This initiative led to the execution of a Memorandum of Understanding (MOU) in

2004 between the GOJ and the Government of Trinidad and Tobago to

cooperate on the development of an LNG project in Jamaica based on LNG

supplied from Trinidad. A result of this cooperation was a Front End

Engineering and Design (FEED) study by Mustang Engineering, which was

completed in 2006 for an onshore LNG receiving, storage and regasification

terminal located at Port Esquivel, St. Catherine Parish. The negotiations to

purchase LNG from Trinidad and Tobago were suspended in late 2006.

In 2009, the GOJ renewed its efforts to pursue LNG as the preferred primary

fuel diversification option under its National Energy Policy (NEP). By 2006, LNG

Floating Storage Regasification Unit (FSRU) technology had sufficiently matured

for it to be considered for Jamaica, due in part to the perceived lower costs

and shorter implementation timeframe compared to the previous onshore

terminal concept.

A RFP was issued by the Petroleum Corporation of Jamaica (PCJ) in November

2009 for the infrastructure required to utilize a FSRU, the related berthing

facilities and the natural gas pipeline network (on-and off-shore) that would

deliver natural gas to the various end-users throughout the island. In response

to a review of the tender process undertaken by the Office of the Contractor

General (OCG) that process was aborted and, the Cabinet approved, in June

2011, the issuance of a new tender for the LNG Infrastructure. The Cabinet

also approved a separate and concurrent RFP for LNG Supply.

Market There have been various estimates for natural gas demand in Jamaica made by

different groups over the last decade. The current LNG Project Team worked

closely with the potential end users in the power and bauxite mining and


alumina refining industries to confirm these estimates and provide an updated

summary of the potential firm demand for natural gas/LNG in Jamaica.

Natural gas will be largely used by the power generation and the

bauxite/alumina sectors. It will primarily serve as a replacement for Heavy

Fuel Oil (HFO) which is currently being used in these industries. The estimated

potential market for natural gas in Jamaica is in excess of 2 million tonnes of

LNG per annum (mtpa), yet this Supply RFP will be limited to the initial firm

demand.

The first phase of the Jamaica LNG Project is focused on three key end users:

Jamalco, Jamaica Public Service Company Ltd. (JPS) and Jamaica Energy

Partners (JEP). Letters from these three potential end users stating their

interest in purchasing natural gas from this project are attached at the end of

this RFP. Jamalco, which has been operating in Jamaica since 1959 is a

bauxite/alumina producer in which Alcoa is the majority owner. JPS holds an

exclusive license for electricity transmission and distribution in Jamaica and an

affiliate of JPS is currently planning to build a 360 MW power plant in Old

Harbour, as a result of a RFP for new independent power producer (IPP)

generation capacity issued by the Office of Utilities Regulation (OUR) and won

by the JPS affiliate. JEP is an IPP operator and currently operates two medium-

speed diesel power barges in Old Harbour operating on HFO with a production

capacity of 125 MW.

The phase one firm demand for LNG is shown in the table below:

Potential future demand will include additional bauxite/alumina producers, as

well as new power generation plants and the conversion of some of the existing

power plants. The demand from the bauxite/alumina industry will be highly


dependent upon the delivered price of the natural gas, which is a key input

factor in the ongoing initiative for these plants to remain competitive in the

world market.

The future power generation demand forecast is taken from the OUR’s

Generation Expansion Plan 2010 (available at http://www.our.org.jm)

The forecast of future LNG demand for Jamaica is shown in the following graph:

, which

estimates additions to the generation base in Jamaica. Additional uses of

natural gas in the residential, commercial and transportation sectors have not

been included in these forecasts.

Jamaica Energy Regulation As part of a National Energy Diversification Strategy, the development of a

natural gas sector is considered a vital ingredient for the economic

sustainability of Jamaica’s development model. Introducing imported natural

gas into Jamaica’s energy supply mix will enhance security of energy supplies,

and achieve a greater degree of long-term stability in energy prices, while

fostering environmental sustainability in energy provision. A key economic

driver is the goal of improving Jamaica’s international competitiveness by

reducing the cost of energy inputs on a unit basis.

http://www.our.org.jm/�


A draft regulatory policy document has been prepared with the objective of

establishing an appropriate legislative and regulatory framework for an

integrated and environmentally sustainable LNG import, storage and

vaporization and delivery into a natural gas transport system.

The integrated project will be composed of a number of elements which will

serve as the foundation for a natural gas industry in Jamaica as noted below:

i. Physical Facilities;

• Harbour and associated jetty facilities to receive LNG tankers and

provide regular harbour services;

• Storage, liquefaction and vaporization plant for imported LNG;

and

• Transmission and distribution network of pipelines to supply

natural gas to downstream buyers;

ii. A natural gas industry encompassing all forms of natural gas (gaseous,

liquid or compressed) and including encompassing upstream and

downstream markets, import and export, and the transportation sector

(both marine and land based);.

iii. Development of indigenous natural gas resources;

iv. The erection of a gas/industrial park in the long run, facilitating small/

medium and large industrial projects on a stratified basis to support the

long term sustainable economic development of Jamaica, improving its

international competitiveness and providing new employment

opportunities;

v. Promoting the utilization of cryogenic energy; and

vi. An environment conducive to investment in LNG and natural gas

infrastructure, as well as the emergence of and the commercialization of

the natural gas sector.

The GOJ has decided that the introduction of natural gas will be by private

sector-led projects, in which one or more private entities will take primary

responsibility for the design, financing and development of the entire


infrastructure required to facilitate the importation, storage, and regasification

of LNG and the distribution transmission of natural gas.

In the short to medium term, the LNG project will target the power and

bauxite/alumina sectors. In the medium to long term the natural gas sector

could be expanded to make gas available to industrial, commercial and

transport customers. At a later date the household sector is also expected to be

added to the customer base. In the longer term, natural gas may be discovered

within Jamaican territory to supplement the supply derived from imported

natural gas.

The ultimate goal of the Jamaican energy policy is to establish a well-defined

governance, institutional and regulatory framework for the development of the

energy sector as a whole. The policy is expected to provide for the

establishment of institutions; rules; technical, operations, transport, health and

safety standards; public education programs; and processes and procedures

that would define and regulate the marketplace and its operations, including

provisions to support the financing of investments; protection of the

environment; and jurisdictions for the enforcement of breaches of legal

requirements and protections, including the protection of local/foreign

investors.

The legal and regulatory policy and the resulting legislation will be consistent

with the National Energy Policy (which can be found at

http://www.men.gov.jm/PDF_Files/Energy_Policy/Energy%20Policy%20-

%20October%2021,%202009.pdf)

Project Organization

. In designing a legal and regulatory

framework, it is envisaged that there will be a comprehensive gas statute

regulating the various aspects of the gas industry.

The Prime Minister established the LNG Steering Committee in December 2010

to oversee the development of the Jamaica LNG Project due to the importance

to the national economy of a successful outcome to the endeavours. The LNG

Steering Committee is chaired by Mr. Christopher Zacca, a well-known

Jamaican businessman and Special Advisor to the Prime Minister, and is

comprised of key private sector participants and representatives of various GOJ

http://www.men.gov.jm/PDF_Files/Energy_Policy/Energy%20Policy%20-%20October%2021,%202009.pdf�

http://www.men.gov.jm/PDF_Files/Energy_Policy/Energy%20Policy%20-%20October%2021,%202009.pdf�


agencies involved with the energy sector. The LNG Steering Committee reports

to the Minister of Energy & Mining, the Honourable Clive Mullings.

The LNG Steering Committee is assisted in fulfilling its mandate by experienced

international advisors that have been engaged to provide key functions in the

development of the LNG Project:

a) LNG Project Manager (Mr. Ernie Megginson)

b)

– Mr. Megginson has over 30

years of energy and project management experience. He successfully

managed the development, construction and start-up/operations of

large-scale natural gas-fired projects in Thailand and Indonesia for two

of the energy majors, Texaco and Chevron.

Financial Advisor (Taylor-DeJongh)

c)

– Taylor-DeJongh (TDJ) is an

independent investment banking firm providing strategic, project finance

and mergers and acquisitions advisory services for conventional and

renewable energy, oil & gas, industrial and infrastructure clients

globally. TDJ is globally respected for its expertise in project finance

advisory services and is consistently ranked among the top global

financial institutions for energy finance advise.

LNG Commercial Advisor (Featherwood Capital)

d)

- Featherwood Capital

provides energy related consulting services and commercial support for

the development of LNG infrastructure throughout the world.

Featherwood Capital LLC has extensive knowledge of the North American

and International LNG industry as well as the natural gas transportation

and distribution markets.

LNG Technical Advisor (WorleyParsons)

e)

– WorleyParsons is a worldwide

engineering firm with extensive experience with regasification terminal

design, onshore and subsea pipelines, floating production, storage and

off-loading systems. WorleyParsons has experience in both conventional

onshore and Floating Storage and Regasification System (FSRU).

Legal Advisors (Local & International) – The LNG Project has engaged

well-qualified local and international legal counsels. The local external

legal counsel, Livingston, Alexander & Levy, was established in 1911 and


is one of the oldest and most respected legal firms in Jamaica. The

external international legal counsel, Latham & Watkins, is one of the

largest legal firms in the world, with over 2,000 attorneys with global

offices in 29 different locations. Latham has been involved with large

infrastructure project development and financing, including LNG

projects.

The LNG Steering Committee will initially manage the establishment of the LNG

Project in Jamaica, including issuing the RFPs, evaluating the responses and

negotiating, to the degree required, the project agreements. A private sector

Special Purpose Vehicle (SPV), the Jamaica Gas Trust (JGT), will be established

and will be the legal counterparty to execute the various commercial

agreements.

Commercial Structure After considering several alternatives, the LNG Steering Committee and its

Advisors determined that the establishment of a privately-held Special Purpose

Vehicle (SPV), Jamaica Gas Trust (JGT), would be the preferred structure to

establish the creditworthiness of the Jamaica LNG Project’s commercial value

chain and secure a successful outcome for the people of Jamaica.

The JGT will contract for the purchase of LNG through the SPA, secure the

provision of LNG unloading, storage, regasification through a Terminal Services

Agreement (TUA) and as required natural gas transportation services to

accomplish the onward sale of natural gas (regasified LNG) to the Off-Takers.

The basic commercial framework is set out in the graphic below. The “LNG

Seller” will sell LNG to the JGT, who will in turn sell gas to Off-Takers labeled

as “End Users” pursuant to Gas Sales Agreements (GSA). The JGT will enter into

a TUA, which is separate from the SPA, with the Infrastructure Provider as

determined by the Infrastructure RFP.


The JGT will establish a subsidiary (OPCO) that will perform scheduling of LNG

imports, LNG inventory management, pipeline nominations and gas sales. The

management of payments to the LNG Seller, which originate with the Off-

Takers payments under the GSA’s, will pass through a “lock-box” structure,

which will be established at a trust bank by the JGT for the benefit of the

Seller and the Infrastructure Provider.

In order to establish the credit worthiness of the JGT to satisfy its obligations

to the LNG Seller and Infrastructure Provider, the JGT will be capitalized by at

least One Hundred Million United States Dollars (USD $100 million) of cash, in

addition to Standby Letters of Credit (LOC) totaling One Hundred Million United

States Dollars (USD $100 million) from the Off-Takers, which are the “End

Users”.

LNG Seller

Jamalco

New 360 MW IPP

JEP

Infrastructure Provider

LNG Sales

Payment

Gas SalesPayment

LNG Buyer/ Jamaica Gas Trust Co.

Payment Regas Services

Physical Form & Flow

Liquid

SRT PipelineLNG Ship End User

Gas


Receipt of payments from the End Users, which are in turn due to be remitted

to the LNG Supplier and Infrastructure Provider, will be aggregated and

distributed by an authorized Trust agent which will be an internationally

recognized bank. The flow of funds will follow a structured “water fall” as

illustrated below:

Credit Requirements The JGT will provide a guarantee under the TUA to the successful Bidder of One

Hundred Million United States Dollars (USD 100 million) based on the

capitalization of the JGT for the entire term of the TUA, including any

extensions thereof.

The successful Bidder under the TUA would be required to guarantee an

identical amount to the JGT in the form of a contractual obligation to pay if

the successful Bidder is an investment grade-rated entity or, in the form of a

Standby Letter of Credit (SBLC), if the successful Bidder is not a rated entity, in

both cases for the entire term of the TUA including any extensions thereof.

Information Memorandum Further information on the Jamaican economy, the End Users and the

commercial structure, can be found in the Information Memorandum, which


was prepared by Taylor-DeJongh, the LNG Project’s Financial Advisors, and can

be found in Attachment 01 of this RFP package.

Clean Development Mechanism (CDM) As part of the GOJ’s fuel diversification strategy, the GOJ anticipates that the

LNG fuel switching initiative to generate substantial carbon credits under the

Kyoto Protocol, or its successor agreements. Any bidder to this tender is

expected to support the CDM compliance of the projects and to support the

feasibility of this initiative, and assure maximum benefit for the Jamaican

economy as a whole. Specific ideas and support actions by the respondents

with respect to the CDM support will be appreciated and will receive additional

points in the evaluation of the bid submissions per Section III, Evaluation and

Qualification Criteria. This assistance is not anticipated to place a material

burden on the successful bidder.

RFP Schedule The proposed schedule (subject to change) for this RFP for LNG Floating Storage & Regasification Terminal (SRT) is as follows:

• Wed., Aug. 31, 2011

•

– Issuance of RFP

Mon., Sept. 26, 2011

•

– Pre-Bid Meeting in Kingston, Jamaica

Tue., Sept. 27, 2011

•

– Site Visit to Port Esquivel

Wed., Nov. 30, 2011

•

– Deadline for receipt of RFP submissions

Mon., Jan. 30, 2012

– Notification of the Selected Bidder


Section I. Instructions to Bidders

Table of Clauses PART 1 – Bidding Procedures ..............................................................................................7

A. General ..............................................................................................................................21 1. Scope of Bid .....................................................................................................25 2. Source of Funds ...............................................................................................25 3. Fraud and Corrupt Practices............................................................................25 4. Eligible Bidders ...............................................................................................27 5. Eligible Materials, Equipment, and Services ..................................................28

B. Contents of Bidding Document ...................................................................................29 6. Sections of Bidding Document .......................................................................29 7. Clarification of Bidding Document, Site Visit, Pre-Bid Meeting ....................29 8. Amendment of Bidding Document ..................................................................30

C. Preparation of Bids .......................................................................................................31 9. Cost of Bidding ................................................................................................31 10. Language of Bid ...............................................................................................31 11. Documents Comprising the Bid .......................................................................31 12. Letter of Bid, and Schedules ............................................................................32 13. Alternative Bids ...............................................................................................32 14. Bid Prices and Discounts .................................................................................33 15. Currencies of Bid and Payment .......................................................................33 16. Documents Comprising the Technical Proposal ..............................................34 17. Documents Establishing the Qualifications of the Bidder ...............................34 18. Period of Validity of Bids ................................................................................34 19. Bid Security .....................................................................................................35 20. Format and Signing of Bid ...............................................................................36

D. Submission and Opening of Bids ................................................................................37 21. Sealing and Marking of Bids ...........................................................................37 22. Deadline for Submission of Bids .....................................................................37 23. Late Bids ..........................................................................................................37 24. Withdrawal, Substitution, and Modification of Bids ......................................38 25. Bid Opening .....................................................................................................38

E. Evaluation and Comparison of Bids ...........................................................................39 26. Confidentiality .................................................................................................39 27. Clarification of Bids .........................................................................................40 28. Deviations, Reservations, and Omissions ........................................................40 29. Determination of Responsiveness ....................................................................40 30. Non-material Non-conformities .......................................................................41 31. Correction of Arithmetical Errors ....................................................................41 32. Conversion to Single Currency ........................................................................42


33. Margin of Preference .......................................................................................42 34. Evaluation of Bids............................................................................................42 35. Comparison of Bids .........................................................................................43 36. Qualification of the Bidder ..............................................................................43 37. Procuring Entity’s Right to Accept Any Bid, and to Reject Any or All Bids .44

F. Award of Contract .........................................................................................................44 38. Award Criteria .................................................................................................44 39. Notification of Award ......................................................................................44 40. Signing of Contract ..........................................................................................45 41. Performance Security .......................................................................................45 Table of Forms ...........................................................................................................54

PART 2 –Works Requirements ...........................................................................................61

PART 3 – Conditions of Contract and Contract Forms ................................................63

PART 4 – Attachments .........................................................................................................78


Section I. Instructions to Bidders A. General

Bidder’s technical proposal shall conform to the format outlined in this document, thereby demonstrating capability to perform all necessary Works to achieve the outlined objectives. The technical proposal shall consist of all the required information listed in each of the following sections in the order given.

In all cases, the GOJ reserves the right to accept or reject submitted proposals(s) at its sole discretion without stating any cause or reason, and without any cost or liability or obligation on the part of the GOJ.

General Requirements It is intended that this Request for Proposal (RFP) be reviewed in conjunction with the following documentation, which is attached:

• Basis of Design

• SRT Scope of Work

• Pipeline & ORF Scope of Work

• Pipeline & ORF Functional Specification

• Regas Plant Functional Specification

• FSRU Functional Specification

• Jetty Design Philosophy

• Pipeline & ORF Operating Philosophy

• FSRU Operating Philosophy

Bidders shall strictly comply with the stipulations contained in the Basis of Design (BOD). Any deviations to the BOD shall be clearly identified in the Technical Proposal.

Project Execution Plan The Bidder must submit an overall Project Execution Plan (PEP) covering Contractor’s Project/Administration/Interface Management, Engineering, Procurement, Construction, Testing & Commissioning and Operation and as part of the requirements specified in Section V. Works Requirements.

Project Organization Bidders shall provide their project organization chart identifying the contractor’s representative and key personnel dedicated to the performance of the Works. The


chart shall also show the relationship of contractor's representative and his project team to the other parts of the Bidder’s organization together with the relationship proposed with major subcontractors or joint venture / consortium participants.

Bidder shall provide the appropriate number of skilled personnel for the Project in accordance with the proposed project organization chart.

Bidder must provide details of the organization structure for the project team. For a joint venture/partnership arrangement, the organization structure of each individual company shall be included, as well as the combined organization structure, indicating the relationship between the various entities within the joint venture/partnership.

Bidder shall provide a corporate organization chart showing the reporting relationship of the personnel identified below, and their role in managing contracts of this nature:

• Directors

• Officers

• Senior Managers

The organization chart shall be supported by resumes of key personnel substantiating their technical qualifications and relevant experience to manage and supervise the Works.

Project Planning & Master Schedule Bidder shall provide a preliminary Project Execution Plan (PEP) to demonstrate to the Procuring Entity that Bidder clearly understands all aspects of the Works and has the resources and full capability to complete the Works within Procuring Entity’s required schedule. Bidder shall additionally provide a similar preliminary PEP for each subcontractor where responsibility for execution of particular aspects of the Works has been delegated by the Bidder.

Bidder’s submission shall include the following information:

Level 1 schedule for the Works covering all phases of the Works, specifically referencing project management, engineering, procurement, surveys, fabrication, transportation, installation and tie-in, pre-commissioning, mechanical completion, commissioning, and final documentation. The schedule shall clearly demonstrate that Bidder fully understands the Works and the ability to comply with the schedule.

Schedule of major items of construction plant and equipment to be used during each phase in the execution of the contract (including information covering: general specifications, capacity and capability, etc).


Management process for each phase of the Works in accordance with the proposed organization, clearly indicating the methods Bidder will use to perform and control each phase of the Works.

Description of Bidder’s project management and control system. Bidder shall demonstrate that the following functions are fulfilled in an integrated system:

• Planning and scheduling of the Works

• Progress reporting and forecasting

• Resource allocation

• Engineering Management

• Procurement & Materials Management

• Construction Management

• Installation Management

• Safety Management

• Document Control

• Material Control

• Subcontractor Management

• Detailed description of selected technology.

Procurement/ Sub-Contracting Bidder shall describe in its preliminary project execution plan how it intends to plan, manage, and carry out the procurement and subcontracting activities as outlined in the Section V. Works Requirements. Bidder must demonstrate a sound, logical, well structured procurement process that addresses all relevant aspects of procurement planning, fabrication and management.

Bidder shall confirm that a person within their organization is familiar with Governmental bodies and authorities who will be required to be assigned to support the process of certification and compliance with Government requirements in accordance with applicable standards, codes, laws and regulations.

Bidder shall provide details of the subcontractors to be utilized in the execution of the Works.

Quality Assurance and Quality Control Bidder shall provide its Quality Assurance and Quality Control (QAQC) plan for the performance of the Works.


Health, Safety, Security and Environment Management Bidder shall confirm that it, and its subcontractors performing Works under the Contract, has existing, proven, Health, Safety and Environmental manuals and procedures that adequately cover all aspects of the Works. Bidder shall include a copy of Bidder’s HSE policy in the bid submittal.

Project Risk Management Plan Bidder shall submit a Risk Management Plan outlining the risk assessments and mitigation measures to be performed..


1. Scope of Bid 1.1 In connection with the Invitation for Bids indicated in the Bid Data Sheet (BDS), the Procuring Entity, issues these Bidding Documents for the procurement of Works as specified in Section V, Works Requirements. The name, and identification of the International Competitive Bidding (ICB) are provided in the BDS.

1.2 Throughout these Bidding Documents:

(a) the term “in writing” means communicated in written form and delivered against receipt;

(b) except where the context requires otherwise, words indicating the singular also include the plural and words indicating the plural also include the singular; and

(c) “day” means calendar day.

2. Source of Funds 2.1 The Procuring Entity has committed funds toward the cost of the project and intends to apply a portion of the funds to eligible payments under the contract.

3. Fraud and Corrupt Practices

3.1 Government of Jamaica requires that bidders, suppliers, contractors, consultants and concessionaries (including their respective officers, employees and agents), adhere to the highest ethical standards, and report to the Government o f Jamaica (GOJ)all suspected acts of fraud or corruption of which they have knowledge or become aware both during the Bidding Process and throughout negotiation or execution of a contract. The definitions of actions set forth below involve the most common types of fraud and corruption, but are not exhaustive. For this reason, the GOJ shall also take action in the event of any similar deed or complaint involving alleged acts of fraud and corruption, even when these are not specified in the following list. The GOJ shall in all cases proceed with the established procedure referred to in Clause 3.1 (c). In pursuit of this policy, the GOJ:

(a) defines, for the purpose of this provision the terms set forth below as follows:

i. “corrupt practice” means the offering, giving, receiving, or soliciting, directly or indirectly, of anything of value to influence the action of a public official in the procurement process or in contract execution;


ii. “fraudulent practice” means a misrepresentation or omission of facts in order to influence a procurement process or the execution of a contract, to the detriment of Government of Jamaica and includes collusive practice among bidders (prior to or after bid submission) designed to establish bid prices at artificial non-competitive levels and to deprive Government of the benefits of free and open competition;

iii. “collusive practice” means a scheme or arrangement between two or more bidders, with or without the knowledge of the Procuring Entity, designed to establish bid prices at artificial non-competitive levels or to influence the action of any party in the procurement process or the execution of a contract; and

iv. “coercive practice” means harming or threatening to harm, directly or indirectly, persons or their property to influence their participation in the procurement process or affect the execution of a contract;

(b) will reject a proposal for award if it determines that the Bidder recommended for award has, directly or through an agent, engaged in corrupt, fraudulent, collusive or coercive practices in competing for the Contract in question;

(c) will sanction a firm or individual, including declaring them ineligible, either indefinitely or for a stated period of time, to be awarded a GOJ-financed contract if it at any time determines that they have, directly or through an agent, engaged, in corrupt, fraudulent, collusive or coercive practices in competing for, or in executing, a GOJ-financed contract; and

(d) will have the right to require that a provision be included in Bidding Documents and in contracts financed by a GOJ, requiring bidders, suppliers, contractors and consultants to permit GOJ to inspect their accounts and records and other documents relating to the Bid submission and


contract performance and to have them audited by auditors appointed by the GOJ.

4. Eligible Bidders 4.1 A Bidder may be a natural person, private entity, government-owned entity—subject to ITB 4.6—or any combination of such entities supported by a letter of intent to enter into an agreement or under an existing agreement in the form of a joint venture or association (JVA). In the case of a joint venture or association unless otherwise specified in the BDS, all partners shall be jointly and severally liable.

4.2 A Bidder, and all parties constituting the Bidder, may have the nationality of any country. A Bidder shall be deemed to have the nationality of a country if the Bidder is a citizen or is constituted, incorporated, or registered and operates in conformity with the provisions of the laws of that country. This criterion shall also apply to the determination of the nationality of proposed subcontractors or suppliers for any part of the Contract including related Services.

4.3 A Bidder shall not have a conflict of interest. All Bidders found to have a conflict of interest shall be disqualified. A Bidder may be considered to have a conflict of interest with one or more parties in the bidding process, if :

(a) they have controlling partners in common; or

(b) they receive or have received any direct or indirect subsidy from any of them; or

(c) they have the same legal representative for purposes of the bid; or

(d) they have a relationship with each other, directly or through common third parties, that puts them in a position to have access to information about or influence on the bid of another Bidder, or influence the decisions of the Purchaser regarding this bidding process; or

(e) a Bidder participates in more than one bid in this bidding process. Participation by a Bidder in more than one Bid will result in the disqualification of all Bids in which the party is involved. However, this does not limit the inclusion of the same subcontractor in more than one bid; or


(f) are or have been associated in the past, with a firm or any of its affiliates which have been engaged by the Procuring Entity to provide consulting services for the preparation of the design, specifications, and other documents to be used for the procurement of the Works that are the subject of the bid; or,

(g) a Bidder participated as a consultant in the preparation of the design or technical specifications of the works that are the subject of the bid;

(h) a Bidder was affiliated with a firm or entity that has been hired (or is proposed to be hired) by the Procuring Entity as Engineer for the contract.

4.4 A Bidder that is under a declaration of ineligibility during the period of time established by the Government of Jamaica in accordance with ITB Clause 3, at the date of contract award, shall be disqualified.

4.5 This bidding is open only to pre-qualified Bidders.

4.6 In accordance with the Government of Jamaica Handbook of Public Sector Procurement Procedures October, 2010 (http://www.mof.gov.jm) the Bidder shall have to demonstrate that they have paid such taxes, duties, fees and other impositions as may be levied in Jamaica.

4.7 Where deemed necessary, the bidders should be registered with the National Contracts Commission “Registry of Public Sector Contractors” (http://www.ocg.gov.jm).

5. Eligible Materials, Equipment, and Services

5.1 The materials, equipment and services to be supplied under the Contract may have their origin in any country. At the Procuring Entity’s request, Bidders may be required to provide evidence of the origin of materials, equipment and services.

5.2 For purposes of ITB 5.1 above, “origin” means the place where the materials and equipment are mined, grown, produced or manufactured, and from which the services are provided. Materials and equipment are produced when, through manufacturing, processing, or substantial or major assembling of components, a commercially recognized product results that is substantially in its basic characteristics or in purpose or utility from its

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components.

B. Contents of Bidding Document

6. Sections of Bidding Document

6.1 The Bidding Documents consist of Parts 1, 2, and 3, which include all the Sections indicated below, and should be read in conjunction with any Addenda issued in accordance with ITB 8.

PART 1 Bidding Procedures

• Section I. Instructions to Bidders (ITB)

• Section II. Bid Data Sheet (BDS)

• Section III.Evaluation Criteria and Qualification Criteria

• Section IV. Bidding Forms PART 2 Works Requirements

• Section V. Works Requirements

PART 3 Conditions of Contract and Contract Forms

• Section VI. Term Sheet

6.2 The Invitation for Bids issued by the Procuring Entity is not part of the Bidding Document.

6.3 The Procuring Entity is not responsible for the completeness of the Bidding Documents and their addenda, if they were not obtained directly from the source stated by the Procuring Entity in the Invitation for Bids.

6.4 The Bidder is expected to examine all instructions, forms, terms, and specifications in the Bidding Document. Failure to furnish all information or documentation required by the Bidding Documents may result in the rejection of the bid.

7. Clarification of Bidding Document, Site Visit, Pre-Bid Meeting

7.1 A prospective Bidder requiring any clarification of the Bidding Document shall contact the Procuring Entity in writing at the Procuring Entity’s address indicated in the BDS or raise his enquiries during the pre-bid meeting if provided for in accordance with ITB 7.4. The Procuring Entity will respond in writing to any request for clarification, provided that such request is received no later than twenty-one (21) days prior to the deadline for submission of bids. The Procuring Entity shall forward copies of its response to all Bidders who have acquired the Bidding Document in accordance with ITB 6.3,


including a description of the inquiry but without identifying its source. Should the Procuring Entity deem it necessary to amend the Bidding Document as a result of a request for clarification, it shall do so following the procedure under ITB 8 and ITB 22.2.

7.2 The Bidder is advised to visit and examine the Site of Works and its surroundings and obtain for itself on its own responsibility all information that may be necessary for preparing the bid and entering into a contract for construction of the Works. The costs of visiting the Site shall be at the Bidder’s own expense.

7.3 The Bidder and any of its personnel or agents will be granted permission by the Procuring Entity to enter upon its premises and lands for the purpose of such visit, but only upon the express condition that the Bidder, its personnel, and agents will release and indemnify the Procuring Entity and its personnel and agents from and against all liability in respect thereof, and will be responsible for death or personal injury, loss of or damage to property, and any other loss, damage, costs, and expenses incurred as a result of the inspection.

7.4 The Bidder’s designated representative is invited to attend a pre-bid meeting, if provided for in the BDS. The purpose of the meeting will be to clarify issues and to answer questions on any matter that may be raised at that stage.

7.5 The Bidder is requested, as far as possible, to submit any questions in writing, to reach the Procuring Entity not later than one week before the meeting.

7.6 Minutes of the pre-bid meeting, including the text of the questions raised, without identifying the source, and the responses given, together with any responses prepared after the meeting, will be transmitted promptly to all Bidders who have acquired the Bidding Documents in accordance with ITB 6.3. Any modification to the Bidding Documents that may become necessary as a result of the pre-bid meeting shall be made by the Procuring Entity exclusively through the issue of an Addendum pursuant to ITB 8 and not through the minutes of the pre-bid meeting.

7.7 Nonattendance at the pre-bid meeting will not be a cause for disqualification of a Bidder.

8. Amendment of Bidding

8.1 At any time prior to the deadline for submission of bids, the Procuring Entity may amend the Bidding


Document Documents by issuing addenda.

8.2 Any addendum issued shall be part of the Bidding Documents and shall be communicated in writing to all who have obtained the Bidding Document from the Procuring Entity in accordance with ITB 6.3.

8.3 To give prospective Bidders reasonable time in which to take an addendum into account in preparing their bids, the Procuring Entity may, at its discretion, extend the deadline for the submission of bids, pursuant to ITB 22.2

C. Preparation of Bids

9. Cost of Bidding 9.1 The Bidder shall bear all costs associated with the preparation and submission of its Bid, and the Procuring Entity shall not be responsible or liable for those costs, regardless of the conduct or outcome of the bidding process.

10. Language of Bid

10.1 The Bid, as well as all correspondence and documents relating to the bid exchanged by the Bidder and the Procuring Entity, shall be written in the language specified in the BDS. Supporting documents and printed literature that are part of the Bid may be in another language provided they are accompanied by an accurate translation of the relevant passages in the language specified in the BDS, in which case, for purposes of interpretation of the Bid, such translation shall govern.

11. Documents Comprising the Bid

11.1 The Bid shall comprise the following:

(a) Letter of Bid

(b) completed schedules as required, including priced Bill of Quantities, in accordance with ITB 12 and 14;

(c) Bid Security, in accordance with ITB 19;

(d) alternative bids, if permissible, in accordance with ITB 13;

(e) written confirmation authorizing the signatory of the Bid to commit the Bidder, in accordance with ITB 20.2;

(f) documentary evidence in accordance with ITB 17 establishing the Bidder’s qualifications to perform the contract if its Bid is accepted;

(g) Technical Proposal in accordance with ITB 16;


and

(h) any other document required in the BDS.

11.2 In addition to the requirements under ITB 11.1, bids submitted by a Joint Venture, Consortium, or Association (JVCA) shall include a copy of the Joint Venture Agreement entered into by all partners. Alternatively, a Letter of Intent to execute a Joint Venture Agreement in the event of a successful bid shall be signed by all partners and submitted with the bid, together with a copy of the proposed agreement.

12. Letter of Bid, and Schedules

12.1 The Letter of Bid and Schedules, including the Bill of Quantities, shall be prepared using the relevant forms furnished in Section IV, Bidding Forms. The forms must be completed without any alterations to the text, and no substitutes shall be accepted. All blank spaces shall be filled in with the information requested.

13. Alternative Bids

13.1 Unless otherwise indicated in the BDS, alternative bids shall not be considered.

13.2 When alternative times for completion are explicitly invited, a statement to that effect will be included in the BDS, as will the method of evaluating different times for completion.

13.3 Except as provided under ITB 13.4 below, Bidders wishing to offer technical alternatives to the requirements of the bidding document must first price the Procuring Entity’s design as described in the bidding document and shall further provide all information necessary for a complete evaluation of the alternative by the Procuring Entity, including drawings, design calculations, technical specifications, breakdown of prices, and proposed construction methodology and other relevant details. Only the technical alternatives, if any, of the lowest responsive Bidder conforming to the basic technical requirements shall be considered by the Procuring Entity.

13.4 When specified in the BDS, Bidders are permitted to submit alternative technical solutions for specified parts of the Works, and such parts will be identified in the BDS, as will the method for their evaluating, and described in Section V, Work’s Requirements.


14. Bid Prices and Discounts

14.1 The prices and discounts quoted by the Bidder in the Letter of Bid and in the Bill of Quantities shall conform to the requirements specified below.

14.2 The Bidder shall fill in rates and prices for all items of the Works described in the Bill of Quantities. Items against which no rate or price is entered by the Bidder will not be paid for by the Procuring Entity when executed and shall be deemed covered by the rates for other items and prices in the Bill of Quantities.

14.3 The price to be quoted in the Letter of Bid, in accordance with ITB 12.1, shall be the total price of the Bid, excluding any discounts offered.

14.4 The Bidder shall quote any unconditional discounts separately and the methodology for their application in the Letter of Bid, in accordance with ITB 12.1.

14.5 Unless otherwise provided in the BDS and the Contract, the rates and prices quoted by the Bidder are subject to adjustment during the performance of the Contract in accordance with the provisions of the Conditions of Contract. In such a case, the Bidder shall furnish the indices and weightings for the price adjustment formulae in the Schedule of Adjustment Data and the Procuring Entity may require the Bidder to justify its proposed indices and weightings.

14.6 If so indicated in ITB 1.1, bids are being invited for individual lots (contracts) or for any combination of lots (packages). Bidders wishing to offer any price reduction for the award of more than one Contract shall specify in their bid the price reductions applicable to each package, or alternatively, to individual Contracts within the package. Price reductions or discounts shall be submitted in accordance with ITB 14.4, provided the bids for all lots (contracts) are submitted and opened at the same time.

14.7 All duties, taxes, and other levies payable by the Contractor under the Contract, or for any other cause, as of the date 28 days prior to the deadline for submission of bids, shall be included in the rates and prices and the total Bid Price submitted by the Bidder.

15. Currencies of 15.1 The currency(cies) of the bid shall be, as specified


Bid and Payment in the BDS.

15.2 Bidders may be required by the Procuring Entity to justify, to the Procuring Entity’s satisfaction, their local and foreign currency requirements, and to substantiate that the amounts included in the unit rates and prices and shown in the Summary of Payment Currency Schedule, in which case a detailed breakdown of the foreign currency requirements shall be provided by Bidders.

16. Documents Comprising the Technical Proposal

16.1 The Bidder shall furnish a Technical Proposal including a statement of work methods, equipment, personnel, schedule and any other information as stipulated in Section IV, in sufficient detail to demonstrate the adequacy of the Bidders’ proposal to meet the work requirements and the completion time.

17. Documents Establishing the Qualifications of the Bidder

17.1 To establish its qualifications to perform the Contract in accordance with Section III, Evaluation and Qualification Criteria, the Bidder shall provide the information requested in the corresponding information sheets included in Section IV, Bidding Forms.

17.2 Domestic Bidders, individually or in joint ventures, applying for eligibility for domestic preference shall supply all information required to satisfy the criteria for eligibility as described in ITB 33.

18. Period of Validity of Bids

18.1 Bids shall remain valid for the period specified in the BDS after the bid submission deadline date prescribed by the Procuring Entity. A bid valid for a shorter period is deemed non responsive and shall be rejected by the Procuring Entity.

18.2 In exceptional circumstances, prior to the expiration of the bid validity period, the Procuring Entity may request Bidders to extend the period of validity of their bids. The request and the responses shall be made in writing. If a bid security is requested in accordance with ITB 19, it shall also be extended. A Bidder may refuse the request without forfeiting its bid security. A Bidder granting the request shall not be required or permitted to modify its bid, except as provided in ITB 18.3.


19. Bid Security 19.1 Unless otherwise specified in the BDS, the Bidder shall furnish as part of its bid, a bid security in original form and in the amount and currency specified in the BDS.

19.2 The bid security shall be a demand guarantee at the Bidder’s option, in any of the following forms:

(a) an unconditional bank guarantee;

(b) an irrevocable letter of credit;

(c) a cashier’s or certified check; or

(d) another security indicated in the BDS,

from a reputable source from an eligible country. If the bid security furnished by the Bidder is in the form of a bond issued by an insurance or bonding institution located outside the Procuring Entity’s Country, it shall have a correspondent financial institution located in the Procuring Entity’s Country to make it enforceable. The bid security shall be submitted either using the Bid Security Form included in Section IV, Bidding Forms, in the case of a bank guarantee, or in another substantially similar format approved by the Procuring Entity prior to bid submission. In either case, the form must include the complete name of the Bidder.

19.3 Any bid not accompanied by an enforceable and compliant bid security, if one is required in accordance with ITB 19.1, shall be deemed non responsive and rejected by the Procuring Entity.

19.4 The bid security of the successful Bidder shall be returned as promptly as possible once the successful Bidder has signed the Contract and furnished the required performance security.

19.5 The bid security may be forfeited:

i. if a Bidder withdraws its bid during the period of bid validity specified by the Bidder on the Letter of Bid Form, except as provided in ITB 18.2 or

ii. if the successful Bidder fails to:

(i) sign the Contract in accordance with ITB 40; or

(ii) furnish a performance security in


accordance with ITB 41.

19.6 The bid security of a JVCA shall be in the name of the JVCA that submits the bid. If the JVCA has not been legally constituted at the time of bidding, the Bid Security shall be in the names of all future partners as named in the letter of intent referred to in ITB 4.1.

19.7 If a bid security is not required in the BDS, and

(a) if a Bidder withdraws its bid during the period of bid validity specified by the Bidder on the Letter of Bid Form, except as provided in ITB 18.2, or

(b) if the successful Bidder fails to:

(i) sign the Contract in accordance with ITB 40; or

(ii) furnish a performance security in accordance with ITB 41;

20. Format and

Signing of Bid 20.1 The Bidder shall prepare one original of the

documents comprising the bid as described in ITB 11 and clearly mark it “ORIGINAL.” Alternative bids, if permitted in accordance with ITB 13, shall be clearly marked “ALTERNATIVE.” In addition, the Bidder shall submit copies of the bid, in the number specified in the BDS and clearly mark them “COPY.” In the event of any discrepancy between the original and the copies, the original shall prevail.

20.2 The original and all specified copies of the bid shall be typed or written in indelible ink and shall be signed by a person duly authorized to sign on behalf of the Bidder. This authorization shall consist of a written confirmation as specified in the BDS and shall be attached to the bid. The name and position held by each person signing the authorization must be typed or printed below the signature. All pages of the bid where entries or amendments have been made shall be signed or initialed by the person signing the bid.

20.3 Any inter-lineation, erasures, or overwriting shall be valid only if they are signed or initialed by the person signing the bid.


D. Submission and Opening of Bids

21. Sealing and Marking of Bids

21.1 The Bidder shall enclose the original and all specified copies of the bid, including alternative bids, if permitted in accordance with ITB 13, in separate sealed envelopes, duly marking the envelopes as “ORIGINAL”, “ALTERNATIVE” and “COPY.” These envelopes containing the original and the copies shall then be enclosed in one single envelope.

21.2 The inner and outer envelopes shall:

(a) bear the name and address of the Bidder;

(b) be addressed to the Procuring Entity in accordance with ITB 22.1;

(c) bear the specific identification of this bidding process indicated in the BDS 1.1; and

(d) bear a warning not to open before the time and date for bid opening.

21.3 If all envelopes are not sealed and marked as required, the Procuring Entity will assume no responsibility for the misplacement or premature opening of the bid.

21.4 The Proposals shall be deposited in the TENDER BOX provided at the address specified in the BDS.

22. Deadline for Submission of Bids

22.1 Bids must be received by the Procuring Entity at the address and no later than the date and time indicated in the BDS. When so specified in the BDS, bidders shall have the option of submitting their bids electronically. Bidders submitting bids electronically shall follow the electronic bid submission procedures specified in the BDS.

22.2 The Procuring Entity may, at its discretion, extend the deadline for the submission of bids by amending the Bidding Document in accordance with ITB 8, in which case all rights and obligations of the Procuring Entity and Bidders previously subject to the deadline shall thereafter be subject to the deadline as extended.

23. Late Bids 23.1 The Procuring Entity shall not consider any bid that arrives after the deadline for submission of bids, in accordance with ITB 22. Any bid received by the Procuring Entity after the deadline for submission of bids shall be declared late, rejected, and returned


unopened to the Bidder.

24. Withdrawal, Substitution, and Modification of Bids

24.1 A Bidder may withdraw, substitute, or modify its bid after it has been submitted by sending a written notice, in accordance with ITB 21, duly signed by an authorized representative, and shall include a copy of the authorization in accordance with ITB 20.2, (except that withdrawal notices do not require copies). The corresponding substitution or modification of the bid must accompany the respective written notice. All notices must be:

(a) prepared and submitted in accordance with ITB 20 and ITB 21 (except that withdrawals notices do not require copies), and in addition, the respective envelopes shall be clearly marked “WITHDRAWAL,” “SUBSTITUTION,” “MODIFICATION;” and

(b) received by the Procuring Entity prior to the deadline prescribed for submission of bids, in accordance with ITB 22.

24.2 Bids requested to be withdrawn in accordance with ITB 24.1 shall be returned unopened to the Bidders.

24.3 No bid may be withdrawn, substituted, or modified in the interval between the deadline for submission of bids and the expiration of the period of bid validity specified by the Bidder on the Letter of Bid Form or any extension thereof.

25. Bid Opening 25.1 The Procuring Entity shall open the bids in public, in the presence of Bidders` designated representatives and anyone who choose to attend, and at the address, date and time specified in the BDS. Any specific electronic bid opening procedures required if electronic bidding is permitted in accordance with ITB 22.1, shall be as specified in the BDS.

25.2 First, envelopes marked “WITHDRAWAL” shall be opened and read out and the envelope with the corresponding bid shall not be opened, but returned to the Bidder. No bid withdrawal shall be permitted unless the corresponding withdrawal notice contains a valid authorization to request the withdrawal and is read out at bid opening. Next, envelopes marked “SUBSTITUTION” shall be opened and read out and exchanged with the corresponding bid being substituted, and the substituted bid shall not be opened, but returned to the Bidder. No bid substitution shall be permitted unless the


corresponding substitution notice contains a valid authorization to request the substitution and is read out at bid opening. Envelopes marked “MODIFICATION” shall be opened and read out with the corresponding bid. No bid modification shall be permitted unless the corresponding modification notice contains a valid authorization to request the modification and is read out at bid opening. Only envelopes that are opened and read out at bid opening shall be considered further.

25.3 All other envelopes shall be opened one at a time, reading out: the name of the Bidder and whether there is a modification; the Bid Price(s), including any discounts and alternative offers; the presence of a bid security, if required; and any other details as the Procuring Entity may consider appropriate. Only discounts and alternative offers read out at bid opening shall be considered for evaluation. If so requested by the Procuring Entity in the BDS, the Letter of Bid and the Bill of Quantities are to be initialed by representatives of the Bidder attending bid opening in the manner indicated in the BDS. No bid shall be rejected at bid opening except for late bids, in accordance with ITB 23.1 or non-submission of valid Tax Compliance Certificate and National Contractions Commission registration.

25.4 The Procuring Entity shall prepare a record of the bid opening that shall include, as a minimum: the name of the Bidder and whether there is a withdrawal, substitution, or modification; the Bid Price, per lot if applicable, including any discounts and alternative offers; and the presence or absence of a bid security, if one was required. The Bidders’ representatives who are present shall be requested to sign the record. The omission of a Bidder’s signature on the record shall not invalidate the contents and effect of the record. A copy of the record shall be distributed to all Bidders.

E. Evaluation and Comparison of Bids

26. Confidentiality 26.1 Information relating to the evaluation of bids and recommendation of contract award shall not be disclosed to Bidders or any other persons not officially concerned with such process until information on Contract award is communicated to all Bidders.


26.2 Any attempt by a Bidder to influence the Procuring Entity in the examination, evaluation, comparison and post-qualification evaluation of the bids or Contract award decisions may result in the rejection of its bid.

26.3 Notwithstanding ITB 26.2, from the time of bid opening to the time of Contract award, if any Bidder wishes to contact the Procuring Entity on any matter related to the bidding process, it must do so in writing.

27. Clarification of Bids

27.1 To assist in the examination, evaluation, and comparison of the bids, and qualification of the Bidders, the Procuring Entity may, at its discretion, ask any Bidder for a clarification of its bid. Any clarification submitted by a Bidder that is not in response to a request by the Procuring Entity shall not be considered. The Procuring Entity’s request for clarification and the response shall be in writing. No change in the prices or substance of the bid shall be sought, offered, or permitted, except to confirm the correction of arithmetic errors discovered by the Procuring Entity in the evaluation of the bids, in accordance with ITB 31.

27.2 If a Bidder does not provide clarifications of its bid by the date and time set in the Procuring Entity’s request for clarification, its bid may be rejected.

28. Deviations, Reservations, and Omissions

28.1 During the evaluation of bids, the following definitions apply:

(a) “Deviation” is a departure from the requirements specified in the Bidding Document;

(b) “Reservation” is the setting of limiting conditions or withholding from complete acceptance of the requirements specified in the Bidding Document; and

(c) “Omission” is the failure to submit part or all of the information or documentation required in the Bidding Document.

29. Determination of Responsiveness

29.1 The Procuring Entity’s determination of a bid’s responsiveness is to be based on the contents of the bid itself, as defined in ITB11.

29.2 A substantially responsive bid is one that meets the terms, conditions, and specifications of the Bidding Document without material deviation, reservation,


or omission. A material deviation, reservation, or omission is one that,

(a) if accepted, would

(i) affect in any substantial way the scope, quality, or performance of the Works specified in the Contract; or

(ii) limit in any substantial way, inconsistent with the Bidding Document, the Procuring Entity’s rights or the Bidder’s obligations under the proposed Contract; or

(b) if rectified, would unfairly affect the competitive position of other Bidders presenting substantially responsive bids.

29.3 The Procuring Entity shall examine the technical aspects of the bid submitted in accordance with ITB 16, Technical Proposal, in particular, to confirm that all requirements of Section V, Works Requirements have been met without any material deviation or reservation.

29.4 If a bid is not substantially responsive to the requirements of the Bidding Document, it shall be rejected by the Procuring Entity and may not subsequently be made responsive by correction of the material deviation, reservation, or omission.

30. Non-material Non-conformities

30.1 Provided that a bid is substantially responsive, the Procuring Entity may waive any non-conformities in the bid that do not constitute a material deviation, reservation or omission.

30.2 Provided that a bid is substantially responsive, the Procuring Entity shall rectify nonmaterial nonconformities related to the Bid Price. To this effect, the Bid Price shall be adjusted, for comparison purposes only, to reflect the price of a missing or non-conforming item or component. The adjustment shall be made using the method indicated in Section III, Evaluation and Qualification Criteria.

31. Correction of Arithmetical Errors

31.1 Provided that the bid is substantially responsive, the Procuring Entity shall correct arithmetical errors on the following basis:

(a) if there is a discrepancy between the unit price and the total price that is obtained by


multiplying the unit price and quantity, the unit price shall prevail and the total price shall be corrected, unless in the opinion of the Procuring Entity there is an obvious misplacement of the decimal point in the unit price, in which case the total price as quoted shall govern and the unit price shall be corrected;

(b) if there is an error in a total corresponding to the addition or subtraction of subtotals, the subtotals shall prevail and the total shall be corrected; and

(c) if there is a discrepancy between words and figures, the amount in words shall prevail, unless the amount expressed in words is related to an arithmetic error, in which case the amount in figures shall prevail subject to (a) and (b) above.

31.2 If the Bidder that submitted the lowest responsive bid does not accept the correction of errors, its bid shall be disqualified and the Bid Security will be forfeited.

32. Conversion to Single Currency

32.1 For evaluation and comparison purposes, the Procuring Entity shall convert all bid prices expressed in various currencies into a single currency as specified in the BDS.

33. Margin of Preference

33.1 Unless otherwise specified in the BDS, a margin of preference shall not apply.

34. Evaluation of Bids

34.1 The Procuring Officer shall use the criteria and methodologies listed in this Clause. No other evaluation criteria or methodologies shall be permitted.

34.2 To evaluate a bid, the Procuring Entity shall consider the following:

(a) the bid price, excluding Provisional Sums and the provision, if any, for contingencies in the Summary Bill of Quantities, but including Daywork1

(b) price adjustment for correction of arithmetic

items, where priced competitively;

1 For Daywork to be priced competitively for Bid evaluation purposes, the Procuring Entity must list tentative

quantities for individual items to be costed against Daywork (e.g., a specific number of tractor driver staff-days, or a specific tonnage of Portland cement), to be multiplied by the bidders’ quoted rates and included in the total Bid price.


errors in accordance with ITB 31.1;

(c) price adjustment due to discounts offered in accordance with ITB 14.4;

(d) converting the amount resulting from applying (a) to (c) above, if relevant, to a single currency in accordance with ITB 32;

(e) adjustment for nonconformities in accordance with ITB 30.3;

(f) the evaluation factors indicated in Section III, Evaluation and Qualification Criteria;

34.3 The estimated effect of the price adjustment provisions of the Conditions of Contract, applied over the period of execution of the Contract, shall not be taken into account in bid evaluation.

34.4 If these Bidding Documents allows Bidders to quote separate prices for different lots (contracts), and the award to a single Bidder of multiple lots (contracts), the methodology to determine the lowest evaluated price of the lot (contract) combinations, including any discounts offered in the Letter of Bid Form, is specified in Section III, Evaluation and Qualification Criteria.

34.5 If the bid, which results in the lowest responsive bid Price, is seriously unbalanced or front loaded in the opinion of the Procuring Entity, the Procuring Entity may require the Bidder to produce detailed price analyses for any or all items of the Bill of Quantities, to demonstrate the internal consistency of those prices with the construction methods and schedule proposed. After evaluation of the price analyses, taking into consideration the schedule of estimated Contract payments, the Procuring Entity may require that the amount of the performance security be increased at the expense of the Bidder to a level sufficient to protect the Procuring Entity against financial loss in the event of default of the successful Bidder under the Contract.

35. Comparison of Bids

35.1 The Procuring Entity shall compare all substantially responsive bids to determine the lowest responsive bid, in accordance with ITB 34.2.

36. Qualification of the Bidder

36.1 The Procuring Officer shall determine to its satisfaction whether the Bidder that is selected as


having submitted the lowest evaluated and substantially responsive bid meets the qualifying criteria specified in Section III, Evaluation and Qualification Criteria.

36.2 The determination shall be based upon an examination of the documentary evidence of the Bidder’s qualifications submitted by the Bidder, pursuant to ITB 17.1.

36.3 An affirmative determination shall be a prerequisite for award of the Contract to the Bidder. A negative determination shall result in disqualification of the bid, in which event the Procuring Entity shall proceed to the next lowest responsive bid to make a similar determination of that Bidder’s qualifications to perform satisfactorily.

37. Procuring Entity’s Right to Accept Any Bid, and to Reject Any or All Bids

37.1 The Procuring Entity reserves the right to accept or reject any bid, and to annul the bidding process and reject all bids at any time prior to contract award, without thereby incurring any liability to Bidders. In case of annulment, all bids submitted and specifically, bid securities, shall be promptly returned to the Bidders.

N.B. The Procuring Entity reserves the right not to award a contract to any party with whom it is currently in litigation or with whom it has been previously involved in litigation.

F. Award of Contract

38. Award Criteria 38.1 The Procuring Entity shall award the Contract to the Bidder whose offer has been determined to be the lowest responsive bid in accordance with ITB 34.4 and is substantially responsive to the Bidding Document, provided further that the Bidder is determined to be qualified to perform the Contract satisfactorily.

39. Notification of Award

39.1 Prior to the expiration of the period of bid validity, the Procuring Entity shall notify the successful Bidder, in writing, that its bid has been accepted. The notification letter (hereinafter and in the Conditions of Contract and Contract Forms called the “Letter of Acceptance”) shall specify the sum that the Procuring Entity will pay the Contractor in consideration of the execution and completion of the Works (hereinafter and in the Conditions of Contract


and Contract Forms called “the Contract Price”) and the requirement for the Contractor to remedy any defects therein as prescribed by the Contract. At the same time, the Procuring Entity shall inform all unsuccessful bidders and shall publish the name of the winning Bidder, and the Price it offered, as well as the duration and summary scope of the contract awarded.

39.2 Until a formal contract is prepared and executed, the notification of award shall not constitute a binding Contract.

39.3 The Procuring Entity shall promptly respond in writing to any unsuccessful Bidder who, after notification of award in accordance with ITB 39.1, requests in writing the grounds on which its tender was not selected.

40. Signing of Contract

40.1 Promptly after notification, the Procuring Entity shall send the successful Bidder the Contract Agreement.

40.2 Within twenty-eight (28) days of receipt of the Contract Agreement, the successful Bidder shall sign, date, and return it to the Procuring Entity.

41. Performance Security

41.1 Within twenty-eight (28) days of the receipt of notification of award from the Procuring Entity, the successful Bidder shall furnish the performance security in accordance with the conditions of contract, subject to ITB 34.5, using for that purpose the Performance Security Form included in Section VIII, Annex to the Particular Conditions - Contract Forms, or another form acceptable to the Procuring Entity. If the Performance Security furnished by the successful Bidder is in the form of a bond, it shall be issued by a bonding or insurance company that has been determined by the successful Bidder to be acceptable to the Procuring Entity. A foreign institution providing a bond shall have a correspondent financial institution located in the Procuring Entity’s Country.

41.2 Failure of the successful Bidder to submit the above-mentioned Performance Security or sign the Contract shall constitute sufficient grounds for the annulment of the award and forfeiture of the bid security. In that event the Procuring Entity may award the Contract to the next lowest responsive Bidder whose offer is substantially responsive and is determined by


the Procuring Entity to be qualified to perform the Contract satisfactorily.

47

Section II. Bid Data Sheet The following specific data shall complement, supplement, or amend the provisions in the Instructions to Bidders (ITB). Whenever there is a conflict, the provisions herein shall supersede and prevail over those in ITB.

A. Introduction

ITB 1.1 The number of the Invitation for Bids is :

ITB 1.1

2011/L002

The Procuring Entity is:

ITB 1.1

Government of Jamaica, on behalf of the Jamaica Gas Trust

The name of the ICB is:

The identification number of the ICB is:

LNG Floating Storage & Regasification Terminal

The number and identification of lots (contracts) comprising this ICB is:

2011/L002

ITB 2.1

not applicable

The name of the Project is:

ITB 4.1 (a)

Jamaica Liquefied Natural Gas (LNG) Floating Storage & Regasification Terminal

The individuals or firms in a joint venture or association are

ITB 4.5

jointly and severally liable.

Not Applicable, as this is an Open Tender.

ITB 4.6 At the time of the tender the local bidders shall present to the Procuring Entity a valid Tax Compliance Certificate for due taxes in Jamaica.

Overseas bidders will be required to obtain a valid Tax Compliance Certificate if they are selected for contract award and where any aspect of the contract will require work to be done in Jamaica.

ITB 4.7 At the time of tender, local bidders must be registered with the National Contracts Commission (NCC) “Register of Public Sector Contractors”.

Under the National Contracts Commission “Register of Public Sector Contractors”, the required registration grade is: Mechanical Works, Electrical Works, Civil Engineering, Marine Engineering, Pipe Laying, Piling, Drilling, Steel Erection, Steel Fabrication, Instrumentation, and Industrial Maintenance.

Overseas bidders will be required to obtain NCC Registration if they are selected for contract award.

For more information: http://www.ocg.gov.jm

B. Bidding Document ITB 7.1 For clarification purposes only, the Procuring Entity’s address is:

http://www.ocg.gov.jm/�


Attention: Street Address:

The Procurement Officer

Street Address:

Office of the Cabinet, Public Sector Modernization Division

Parish: Room 219 (Upstairs), 2a Devon Road, Kingston 6

Country: Jamaica St. Andrews

Telephone: Facsimile number:

+1 (876) 929-8880-5

Electronic mail address: +1 (876) 929-7266

Website: [email protected]

http://www.cabinet.gov.jm/procurement

ITB 7.4 A Pre-Bid meeting will

Date:

take place at the following date, time and place:

Time: Monday, September 26, 2011

Place: 10:00 AM To be confirmed and on website:

A site visit conducted by the Procuring Entity

http://www.cabinet.gov.jm/procurement

will be

C. Preparation of Bids

organized

ITB 10.1 The language of the bid is: English

ITB 11.1 (h) The Bidder shall submit with its bid any other information it deems relelvant

ITB 13.1 Alternative bids are

ITB 13.2

permitted.

Alternative times for project completion will be considered and evaluated as specified in Section III, Evaluation and Qualification Criteria.

ITB 13.3 The last sentence in ITB 13.3 shall be replaced in its entirety as follows:

Only the technical alternatives, if any, of Bidders which submit bids conforming to the basic technical requirements as stated in Section V. Works Requirements, shall be considered by the Procuring Entity.

ITB 13.4 Alternative technical solutions shall be permitted for the following parts of the Works:

• Placement and volume of LNG storage • Placement of LNG vaporization capacity

If alternative technical solutions are permitted, the evaluation method will be as specified in Section III, Evaluation and Qualification Criteria.

ITB 14.5 The prices quoted by the bidder shall be: United States Dollars (USD)

mailto:[email protected]�



49

ITB 14.6 Not Applicable

ITB 14.7 ITB 14.7 shall be replaced in its entirety as follows:

Bid Prices should be presented as net of all custom duties or fees, transfer taxes stamp duties and general consumption taxes. If any custom duties or fees, transfer taxes, stamp duties or general consumption taxes or similar imposts are levied during the term of the TUA, then Bid Prices shall be adjusted to compensate for such customs duties or fees, transfer taxes stamp duties or general consumption taxes or similar imposts imposed.

The Bidder is responsible for all corporate taxes and withholding taxes with respect to earnings from and operations of the Project and services provided throughout the term of the TUA.

ITB 15.1 Bidders shall not

Source that establishes the exchange rates:

express the bid price entirely in the currency of the Procuring Entity’s country].

ITB 17.2

Bank of Jamaica, selling rate.

Not Applicable

ITB 18.1 The bid validity period shall be one hundred and twenty days (120)

ITB 19.1

days.

A bid security is required in the amount and currency of

ITB 19.2 (d)

One Million United States Dollars (US $1,000,000.00)

Other types of acceptable securities:

ITB 20.1

Not Applicable

In addition to the original of the bid shall be accompanied

ITB 20.2

by one (1) DVD or CD ROM containing an electronically searchable copy of the bid submittal and twelve (12) hard copies.

The written confirmation of authorization to sign on behalf of the Bidder shall consist of: Company Letter Head, with authorized signature stating position and contact details.

D. Submission and Opening of Bids ITB 22.1 For bid submission purposes

Attention:

only, the Procuring Entity’s address is :

Street Address: Procurement Officer

Street Address:

, Office of the Cabinet, Public Sector Moderization Division, Room 219 (Upstairs),

2a Devon Road

Parish: City: Kingston 6

St. Andrews


Country: Jamaica

The deadline for bid submission is: Date: Time:

Wednesday, November 30 2011

Bidders

10:00 AM (Jamaica time)

do not

ITB 25.1

have the option of submitting their bids electronically.

The bid opening shall take place at: Street Address:

Street Address:

Office of the Cabinet, Public Sector Modernization Division, Conference Room 212

2a Devon Road

Parish : City: Kingston 6

Country:Jamaica St. Andrews

Date: Time:

Wednesday, November 30, 2011

ITB 25.3

10:15 AM (Jamaica time)

The Letter of Bid and Bill of Quantities will not

E. Evaluation, and Comparison of Bids

be initialed by representatives of the Procuring Entity attending Bid opening.

ITB 32.1

The currency(ies) of the Bid shall be converted into a single currency as follows:

The currency that shall be used for bid evaluation and comparison purposes to convert all bid prices expressed in various currencies into a single currency is:

United States Dollars (USD)

United States Dollars (USD)

The source of exchange rate shall be:

The date for the exchange rate shall be:

Bank of Jamaica, selling rate

ITB 33.1

November 30, 2011

A margin of preference shall not

ITB 34.1

apply.

ITB 34.1 shall be replaced in its entirety as follows:

The Procuring Entity shall use the criteria stated in Section III, Evaluation and Qualification Criteria for the evaluation of the bids. No other evaluation criteria or methodologies shall be permitted.





The Procuring Entity shall compare all substantially responsive bids to determine the lowest responsive bid, defined as the bid receiving the highest evaluated score as determined in accordance

51

with Section III, Evaluation and Qualification Criteria.


The Procuring Entity shall enter into contract negotiations with the Bidder whose offer has been determined to be the highest evaluated score as determined in accordance with Section III, Evaluation and Qualification Criteria. If these negotiations do not result in an executed TUA, or if the Bidder fails to provide the required Performance Security, the Procuring Entity may:

a) Forfeit the bid security; and

b) Proceed to enter into contract negotiations the next highest evaluated score as determined in accordance with Section III, Evaluation and Qualification Criteria.


The successful Bidder will be required to furnish the Performance Security in accordance with the provisions and schedules contained in the TUA.

52

Section III. Evaluation and Qualification Criteria

Only bids determined to be substantially responsive in accordance with ITB 29 shall be evaluated according to the following criteria:

# Criteria Maximum

Points

1.0

Bidder Qualifications:

Bids will be evaluated on the bidder’s previous experience with

similar projects to the SRT proposed. Bidders should provide

sufficient documentation to substantiate their claims of experience.

15

1.1

Bidder can demonstrate financing capacity and experience in the

planning, design AND operation of an SRT consisting of similar project

elements to that which is proposed.

15

1.2


planning, design OR operation of similar LNG project elements to that

which is proposed.

10

1.3


planning, design OR operation of petro-chemical projects of similar

complexity to that which is proposed.

5

1.4 Bidder cannot sufficiently demonstrate financing capacity OR relevant

experience 0

2.0

Project Cost

Project Cost will be evaluated on the proposed unit costs based on

a throughput of Two and a Half million tonnes per annum (2.5

MTPA) including the Demand Charge, Commodity Charge and

Barge Charge as stated in attached Term Sheet.

40

2.1 The proposal with the lowest overall Project Cost. 40

2.2 Proposals with evaluated Project Cost equal to or lower than the median

of the Project Cost of all responsive proposals 25

2.3 Proposals with evaluated Project Cost higher than the median of the

Project Cost of all responsive proposals 10

3.0

Execution Schedule

Project schedule will be evaluated on the responsiveness to the

project start date. Bidders should substantiate their proposed

schedule with enough detail in the Project Execution Plan to

ensure all proposed major project milestones are included.

15

3.1 Proposal with a firm start date for first gas delivery in Q1 2014 15

3.2 Proposal with a firm start date for first gas delivery in Q3 2014 5

3.3 Proposal with a firm start date for first gas delivery after Q3 2014 or does 0

53

# Criteria Maximum

Points

not provide a schedule

4.0

Supply Logistics

Proposals will be evaluated on their responsiveness to the Basis of

Design document which has been provided. Parameters to be

considered are: offloading rate, storage capacity, range of

LNGC’s which can call on the facility, weather availability.

10

4.1 Proposals that materially meet all specified requirements in the BOD and

propose LNG storage volumes greater than 145,000m3 10

4.2 Proposals that meet all specified requirements in the BOD but propose

LNG storage volumes between 125,000m3 and 145,000m3

5

4.3 Proposals that do not materially meet all specified requirements in the

BOD 0

5.0

Maturity of Technology

Proposals will be evaluated on the maturity of the proposed

technology, including the number of commercially and

operationally successful installations and applications.

10

5.1 Proposals that utilize proven operational technologies and an availability

of 99.9% for all major systems. 10

5.2 Proposals that rely on proven but not widely operated technology or an

assessed availability of at least 99.8% 5

5.3 Proposals that rely on unproven technology 0

6.0

Clean Development Mechanism (CDM)

Proposals that can demonstrate specific support for the securing of

carbon credits under the Kyoto Protocol.

5

6.1 Proposals responsive to CDM requirements 5

6.2 Proposals that are not responsive to CDM requirements 0

7.0

Local Capacity Building

Proposals that can demonstrate specific support for capacity

building and the use of local Jamaican personnel.

5

7.1 Proposals that include local capacity building and use of local Jamaican

personnel in their operations. 5

7.2 Proposals that do not include local capacity building and use of local

Jamaican personnel in their operations. 0

Maximum Points 100

The Procuring Entity shall enter into contract negotiations with the Bidder with the

highest evaluated score.

54

Section IV. Bidding Forms

Table of Forms

Letter of Bid............................................................................................................................55

Price Proposal.........................................................................................................................57

Form of Bid Security .............................................................................................................58

Technical Proposal .................................................................................................................60

55

Letter of Bid Date: Invitation for Bid No.:

To: _____________________________________________________________________ We, the undersigned, declare that: (a) We have examined and have no reservations to the Bidding Document,

including Addenda issued in accordance with Instructions to Bidders (ITB)8 ; (b) We offer to execute in conformity with the Bidding Document the following

Works:

LNG Floating Storage and Regasification Terminal.

(c) The total price of our Bid is as follows:

Capital Recovery Fee: __________________________________________

_____________________________________________________________

Fixed Operations & Maintenance Fee: ___________________________

_____________________________________________________________

Variable Operations & Maintenance Fee: ________________________

_____________________________________________________________

(d) Our bid shall be valid for a period of _________________ days from the

date fixed for the bid submission deadline in accordance with the Bidding Document, and it shall remain binding upon us and may be accepted at any time before the expiration of that period;

(e) If our bid is accepted, we commit to obtain a Performance Security in

accordance with the Terminal Use Agreement; (f) We are not participating, as a Bidder or as a subcontractor, in more than

one bid in this bidding process in accordance with ITB-4.3, other than alternative offers submitted in accordance with ITB-13;

(g) We, including any of our subcontractors or suppliers for any part of the

contract, have not been declared ineligible under the Procuring Entity’s country laws or official regulations; or by an act of compliance with a decision of the United Nations Security Council;

(h) We are not a government owned entity. We have paid, or will pay the

following commissions, gratuities, or fees with respect to the bidding process or execution of the Contract:

56

Name of Recipient Address Reason Amount

(If none has been paid or is to be paid, indicate “none.”)

(i) We understand that this bid, together with your written acceptance thereof included in your notification of award, shall constitute a binding contract between us, until a formal contract is prepared and executed; and

(j) We understand that you are not bound to accept the lowest responsive bid

or any other bid that you may receive. (l) We hereby certify that we have taken steps to ensure that no person acting

for us or on our behalf will engage in bribery. Name In the capacity of _ Signed Duly authorized to sign the bid for and on behalf of Dated on ______________________________ day of ______________________,

57

Price Proposal Bidder shall submit the proposed fees identified in indicative draft Terminal Use Agreement:

Fee Explanation Proposed (USD) Unit

Proposed Indexation (if applicable)

RV

The rate, in Dollars per MMBtu, that comprises the variable portion of the annual cost of service at the Terminal, which shall be $[●], subject to adjustment to account for inflation as agreed in the TUA

USD per MMBtu

RF

The rate, in Dollars per MMBtu, that comprises the fixed portion of the annual cost of service at the Terminal. RF will initially equal [●] Dollars ($[●]). RF will remain constant in all years where RV changes less than 3% from the previous year. In any contract year where RV escalates by more than 3% from the immediately preceding year, RF will escalate by a factor equal to the escalation rate of RV minus 3%.

USD per MMBtu

YF

The per-unit barge rate, of $[●] per MMBtu, subject to adjustment to account for inflation as agreed in the TUA.

USD per MMBtu

YC

The per-unit commodity rate, of $[●] per MMBtu, subject to adjustment to account for inflation as agreed in the TUA.

USD per MMBtu

YB

The per-unit barge rate, of $[●] per MMBtu, subject to adjustment to account for inflation as agreed in the TUA.

USD per MMBTU

58

Form of Bid Security

(Bank Guarantee)

__________________________ [Bank’s Name, and Address of Issuing Branch or Office]

Beneficiary: __________________________ [Name and Address of Procuring Entity]

Date: __________________________

BID GUARANTEE No.: __________________________

We have been informed that __________________________ [name of the Bidder] (hereinafter called "the Bidder") has submitted to you its bid dated ___________ (hereinafter called "the Bid") for the execution of ________________ [name of contract] under Invitation for Bids No. ___________ (“the IFB”).

Furthermore, we understand that, according to your conditions, bids must be supported by a bid guarantee.

At the request of the Bidder, we ____________________ [name of Bank] hereby irrevocably undertake to pay you any sum or sums not exceeding in total an amount of [amount in words]___________ [amount in figures] (____________) upon receipt by us of your first demand in writing accompanied by a written statement stating that the Bidder is in breach of its obligation(s) under the bid conditions, because the Bidder:

(a) has withdrawn its Bid during the period of bid validity specified by the Bidder in the Form of Bid; or

(b) having been notified of the acceptance of its Bid by the Procuring Entity during the period of bid validity, (i) fails or refuses to execute the Contract Agreement or (ii) fails or refuses to furnish the Performance Security, in accordance with the ITB.

This guarantee will expire: (a) if the Bidder is the successful Bidder, upon our receipt of copies of the contract signed by the Bidder and the Performance Security issued to you upon the instruction of the Bidder; and (b) if the Bidder is not the successful Bidder, upon the earlier of (i) our receipt of a copy your notification to the Bidder of the name of the successful Bidder; or (ii) twenty-eight days after the expiration of the Bidder’s bid.

59

Consequently, any demand for payment under this guarantee must be received by us at the office on or before that date.

This guarantee is subject to the Uniform Rules for Demand Guarantees, ICC Publication No. 458.

_____________________________

[signature(s)]

Note: All italicized text is for use in preparing this form and shall be deleted from the final product.

60

Technical Proposal Bidders shall provide the following details in respect of their Technical Proposal:

SCHEDULE 1 Bidder Qualification/Experience

SCHEDULE 2 Project Description

SCHEDULE 3 Project Execution Plan

SCHEDULE 4 Milestone Schedule

SCHEDULE 5 Project Organization2

SCHEDULE 5 Quality Assurance and Quality Control Plan

SCHEDULE 6 Health Safety and Environment Policy

SCHEDULE 7 Risk Management Plan

SCHEDULE 8 Financing Plan3

SCHEDULE 9 Comments on Terminal Use Agreement

SCHEDULE 10 Clean Development Mechanism (CDM)

2 Please use forms PER-1 and PER-2 found in Attachment 12 for personnel CVs that should be attached

to Schedule

3 Please use form FIN-1 found in Attachment 13 to provide

61

PART 2 –WORKS REQUIREMENTS

62

Section V. Works Requirements

Scope of Works The scope of the Works is described in the following documents which are attached in Part 4 (Attachments) and form an integral part of this RFP:

• Basis of Design .................................................. Attachment 02

• SRT Scope of Work ............................................. Attachment 03

• Pipeline & ORF Scope of Work ............................... Attachment 04

• Pipeline & ORF Functional Specification ................... Attachment 05

• Regas Plant Functional Specification ....................... Attachment 06

• FSRU Functional Specification ............................... Attachment 07

• Jetty Design Philosophy ....................................... Attachment 08

• Pipeline & ORF Operating Philosophy ...................... Attachment 09

• FSRU Operating Philosophy ................................ Attachment 10

63

PART 3 – CONDITIONS OF CONTRACT AND CONTRACT FORMS

64

Note: A draft of the Terminal Use Agreement (TUA) will be made available by September 21, 2011 and will be posted on the website at http://www.cabinet.gov.jm/procurement.

INDICATIVE TERM SHEET TERMINAL USE AGREEMENT

FOR JAMAICA LNG PROJECT

This indicative term sheet (the “Term Sheet”) is not intended to be, nor should be construed as, either a binding agreement between the referenced parties or an attempt to establish all of the terms and conditions relating to the proposed Terminal Use Agreement (the “TUA”). It is intended only to be indicative of certain terms and conditions that are to be reflected in the TUA. All figures, terms and conditions are subject to change and to further discussion between the referenced parties.

Operator: [●]

Customer: Jamaica Gas Trust.

TUA Overview: As described in greater detail below, Operator shall, at its sole cost and expense, perform the Terminal Services throughout the Contract Period in exchange for Customer’s payment of the Monthly Payment. At the end of the Contract Period, or as otherwise provided below, Operator will transfer to Customer all of its right, title and interest in and to the Site, the Terminal and any portion thereof (including all intellectual property rights, fixtures, fittings, plant and equipment (including test equipment and special tools), and any spare parts maintained by Operator pursuant to the TUA).

Contract Period: The period commencing upon the execution of the TUA and, subject to the exercise of the Buy-Out Option or the earlier termination of the TUA in accordance with its terms, ending twenty (20) years after the date of the Date of First Regular Delivery of LNG; provided, however

Transfer:

, that Customer shall have the right, in its sole discretion, to extend the Contract Period for an additional five (5) (for a total Contract Period of twenty-five (25) years), by providing Operator with notice not less than one (1) year prior to the end of the initial twenty (20) year Contract Period.

At the end of the Contract Period, Operator shall sell and transfer to Customer, and Customer shall purchase from Operator, free from any lien or encumbrance, all Operator’s right, title and interest in and to the Site, the Terminal and any portion thereof (including all intellectual property rights, fixtures, fittings, plant and equipment (including test equipment and special tools), and any spare parts maintained by Operator pursuant to the TUA), at


65

no additional consideration. In connection with the foregoing, Operator shall execute such bills of sale, assignment agreements or other documents as are reasonably requested by Customer to effect such sale and purchase, pursuant to mechanics to be agreed in the TUA.

Terminal Services: Operator’s (a) design, engineering, construction, testing, starting-up, operation and maintenance of the Terminal, and procurement of all materials, equipment and services necessary or advisable to accomplish the foregoing (including without limitation all consumable, chemical fills, dunnage and utilities other than the Commissioning LNG), (b) receiving and unloading LNG from vessels at the point where the outlet flanges of the unloading lines of such vessels connect with the inlet flanges of the unloading lines of the Terminal (the “Discharge Point”), (c) storage of LNG at the Terminal, (d) regasification of LNG at the Terminal, (e) delivery of regasified LNG to point of interconnection between the Terminal and the onshore pipeline at the battery limits of the Terminal (the “Delivery Point”), (f) the loading of LNG to barges from the Terminal Storage, and (g) other activities related or incidental to Operator’s performance of the foregoing.

The Terminal Services will not include (i) the supply of LNG or the transportation thereof to the Discharge Point, (ii) tug and pilot services; (iii) the procurement or arrangement of all downstream pipeline transportation or other downstream facilities required to take delivery of regasified LNG at the Delivery Point, or (iv) the marketing or sale of regasified LNG.

Terminal: The LNG terminal, as an integrated whole, to be developed, engineered, constructed, owned, operated, maintained and transferred by Operator pursuant to the terms of the TUA, and including:

(a) jetty and LNG unloading arms;

(b) LNG storage tanks, including, if applicable, tanks on a moored LNG floating storage vessel;

(c) LNG vaporization units;

(d) boil off gas facilities;

(e) general plant facilities;

(f) a berth and loading/unloading arms or lines for barge-based storage, if applicable;

(g) natural gas pipelines located within the battery limits of the Terminal;

(h) mooring facilities;

(i) shoreline protection structures; and

66

(j) all appliances, parts, instruments, appurtenances, accessories, equipment, buildings, civil engineering works, infrastructure and other property that may be incorporate or installed in, or otherwise necessary or convenient for the ownership, operation and maintenance of, any of the foregoing.

The Terminal shall, at a minimum and without limitation, comply with the following technical and operational specifications:

(i) gross storage capacity of [●] cubic meters ([●] m³) to [●] cubic meters ([●] m³), with a working capacity of [●] percent ([●]%) of the gross storage capacity, and the storage shall be able to receive and send out LNG simultaneously to provide a constant flow LNG to the regasification facility;4

(ii) nitrogen facilities with a design capacity sufficient to provide for inerting purposes at the Terminal; provided, however, that Operator will not be obliged to build nitrogen injection facilities for the treatment of regasified LNG to be delivered hereunder;

(iii) the port facilities at the Terminal will be designed to accommodate vessels with a maximum capacity of two hundred sixty five thousand cubic meters (265,000 m3), a length not to exceed three hundred thirty-five (335) meters, a breadth not to exceed fifty-five (55) meters and a scantling draft not to exceed thirteen and one half (13.5) meters; and

(iv) the Terminal will be designed to have the capacity to unload either from the port or starboard side of a vessel at a rate not less than twelve thousand cubic meters (12,000 m3) per hour when LNG is discharged at one hundred (100) meters of head at the vessel’s rail.

Site: Operator shall be solely responsible for obtaining all real property rights (whether fee simple, leasehold, easement, license, right of way or other interests) with respect to the real property necessary for the construction, ownership, operation, maintenance and transfer of the Terminal (the “Site”), including all rights of access (including seaward access), ingress, egress and use (collectively, the “Site Property Rights”). Without limitation of the foregoing, the Site Property Rights shall permit (subject to standard and reasonable terms and conditions) the ownership, operation and maintenance of the Facility for a period of not less than ninety-nine (99) years (or fee ownership), and shall be fully transferable to Customer or its designee in connection with the transfer of the Terminal to Customer or its designee as

4 Bidders to propose figures.

67

contemplated in the TUA.

Construction Phase: Operator shall, at its sole cost and expense, design, engineer and construct the Terminal in accordance with prudent industry practices, all applicable laws, permits and licenses, any insurance policies held by either party to the TUA, any warranty policies applicable to any equipment or materials incorporated into the Terminal, and the terms of any other material agreements entered into by Operator in connection with the Terminal. Operator shall carry out the design, engineering and construction pursuant to a schedule to be set forth in the TUA, and will be required to achieve certain construction milestones (each, a “Construction Milestone”) to be agreed with Customer by specified longstop dates (each, a “Construction Milestone Deadline”), as such Construction Milestone Deadlines may be adjusted in the case of Force Majeure or a failure of Customer to cause the delivery of Commissioning LNG in accordance with the TUA. The penalties for Operator’s failure to achieve any Construction Milestone by the applicable Construction Milestone Deadline will be as agreed in the TUA.

Throughout the Construction Phase, Operator shall provide to Customer monthly (and, while the Terminal is being commissioned, weekly) construction progress reports, describing, among other things, the status and progress of all construction, an update of the construction schedule, information as to whether or not any delays being experienced could reasonably be expected to result in a delay of any Construction Milestone beyond the applicable Construction Milestone Deadline, and any other information that Customer has reasonably requested in writing.

Commissioning: Operator shall perform the Terminal Services so that, on or before the applicable Construction Milestone Deadline, the Terminal is “Ready for Commissioning”, including without limitation that (a) all equipment and parts comprising the Terminal and/or necessary or advisable for the reliable, safe, efficient operation thereof have been installed, erected, aligned, and adjusted at the Site, (b) all components of the Terminal have been checked for proper operation, and all applicable pre-operational and check-out tests and initial functional tests have been successfully completed, (c) the Terminal is otherwise ready for commencement of commissioning in accordance with the TUA, (d) Operator has delivered to Customer all reports and documents required to have been delivered prior to the commencement of commissioning, and (e) Operator has certified to Customer that the Terminal is Ready for Commissioning.

Once the Terminal is Ready for Commissioning, Customer shall (i) cause the delivery of shipments of LNG for use by Operator in the commissioning of the Terminal, subject to limitations on delivery windows and quantities of LNG to be agreed in the TUA

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(the “Commissioning LNG”); provided, however

Operator shall perform the Terminal Services so that, on or before the applicable Construction Milestone Deadline, the Terminal achieves the “Commercial Operation Date”, including without limitation that (A) each component of Terminal is sufficiently complete, in accordance with the TUA, so that Owner Operator safely and lawfully commence regular commercial operation of the Terminal in accordance with the TUA, (B) the Terminal has successfully passed all applicable performance testing, (C) Operator has received, and delivered to Customer copies of, all permits, authorizations and other documents required for the regular commercial operation of the Terminal in accordance with the TUA (including any plans, drawings, specifications and operating manuals required under the TUA), and (D) Operator has certified to Customer that the Commercial Operation Date has been achieved.

, that Operator shall be responsible liable to Customer for the cost of any Commissioning LNG consumed in excess of an amount to be agreed in the TUA, and (ii) arrange for the receipt of regasified LNG at the Delivery Point in connection with such commissioning.

First Regular Delivery of LNG:

Customer shall cause regular delivery of LNG to commence within a specified period to be set forth in the TUA, which period will be updated and narrowed on or prior to specified dates to be set forth in the TUA through a windowing mechanism.

Delivery Schedule: The TUA will include a mechanism by which Operator shall propose a schedule of major maintenance of the Terminal that Operator, acting in accordance with the standards set forth in the TUA, determines should be undertaken during any Contract Year. Customer will then have an opportunity to propose modifications to such proposed schedule and, except to the extent that doing so would be inconsistent with prudent industry practices, Operator shall accommodate such proposed modifications. Such scheduling will take place sufficiently in advance of any major maintenance to allow Customer to adequately account for any major maintenance in scheduling deliveries of LNG.

Prior to the start of each month after the Commercial Operation Date, Customer shall deliver to Operator a schedule of the LNG deliveries anticipated to take place during the applicable month (taking into account any Major Maintenance scheduled to take place during such month) (each, a “Delivery Schedule”), including a forty-eight (48) hour arrival window for each such delivery (an “Arrival Window”). Each Delivery Schedule shall be structured to allow each vessel to complete discharge within thirty-six (36) hours after its arrival, assuming that (a) the vessel scheduled for the previous Arrival Window will have completed discharge within thirty-six (36) hours after the end of such

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previous Arrival Window, and (b) if the discharge of LNG from the applicable vessel would otherwise exceed the storage capacity of the Terminal, Customer will nominate the DCQ for each day during the Arrival Window and unloading of the applicable vessel. Provided that the Delivery Schedule is consistent with the foregoing, Operator shall receive and unload all cargoes of LNG that are delivered in accordance with such Delivery Schedule. The TUA will contain a windowing mechanism by which Customer will provide updates to Operator regarding the timing of LNG deliveries.

Without limitation of the foregoing, (a) Operator shall use reasonable efforts to accommodate the arrival of Customer’s vessels outside of the Arrival Window, and (b) Customer shall have the right to nominate additional cargoes of LNG during any month that are not described in the applicable Delivery Schedule, and Operator shall exercise reasonable efforts to receive and unload all such unscheduled cargoes of LNG.

Customer shall use commercially reasonable efforts to deliver sufficient quantities of LNG to the Terminal to maintain such minimum inventory level in the storage tanks as is required to maintain an average storage tank temperature of not more than minus one hundred forty degrees Celsius (-140°C) (the “Minimum Tank Inventory Level”), but otherwise shall have no obligation to deliver any volumes of LNG to the Terminal. The TUA will contain customary provisions regarding the unloading of LNG cargoes.

Quality: LNG delivered by Customer shall conform to the specifications set out in Annex 1.

Operator shall use commercially reasonable efforts to accept LNG that does not conform to such specifications (“Off-Specification LNG”) while retaining the right to reject such Off-Specification LNG if Operator cannot accept such Off-Specification LNG.

Each party shall notify the other as soon as it becomes aware that LNG delivered, or to be delivered, under the TUA is Off-Specification LNG.

Customer shall reimburse Operator for all costs incurred by Operator as a consequence of accepting any Off-Specification LNG subject to terms, conditions and limitations to be set out in the TUA.

Laytime and Demurrage:

The period of time for fully discharging each cargo of LNG shall be thirty-six (36) consecutive hours, Sundays and public holidays included (the “Allowed Laytime”). If the actual amount of time required to complete the discharge of any such cargo (including any delay caused by Operator in the applicable vessel (a) proceeding from the customary

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anchorage point to berth or (b) receiving the necessary clearance to commence discharging LNG) (the “Actual Laytime”) exceeds the Allowed Laytime for any reason other than Force Majeure or a failure of Customer to perform its obligations under the TUA, Operator shall pay to Customer demurrage in respect of such excess time at a rate per day (pro rata for any partial day) calculated as “D” in the following formula:

D = $65,000 + (Do);

Where:

Do = $15,000, subject to adjustment to account for inflation as agreed in the TUA.

Nominations: For each day after the Commercial Operation Date, subject to the availability of LNG volumes in excess of the Minimum Tank Inventory Level, Customer shall have the right to nominate for vaporization and delivery from the Terminal to the Delivery Point a quantity of regasified LNG up to four hundred twenty thousand (420,000) MMBtu a day, based on a full and evenly nominated rate throughout such day (the “Daily Contract Quantity” or “DCQ”).

Operator shall design, engineer, construct, operate and maintain the Terminal to permit continuous, real time telemetric monitoring or the usage of regasified LNG by the downstream consumers thereof, and Operator shall adjust the rate of delivery of regasified LNG to the Delivery Point on a real time basis in order to accommodate such usage; provided, however

For each day that Operator fails to provide the Terminal Services to Customer in accordance with the provisions of the TUA (including the berthing of vessels, the regasification of LNG and the delivery of regasified LNG to the Delivery Point) due to causes other than Force Majeure or a failure of Customer to perform its obligations under the TUA, Operator will be subject to such penalties as are agreed in the TUA.

, that Operator shall not be required to deliver Natural Gas to the Delivery Point in excess of one twenty-fourth (1/24) of the DCQ during any rolling hourly period. Operator will ensure that the regasified LNG can be delivered at a pressure measured at the Delivery Point of up to 98 bar at the DCQ volume.

Title and Risk of Loss:

Title to any LNG (and any regasified LNG resulting therefrom) delivered from Customer to Operator shall remain at all times with Customer and shall not pass from Customer to Operator; provided, however, that, subject Operator’s compliance with the standards of performance set forth in the TUA, Operator shall be entitled to consume, and Customer shall bear the cost of, fuel and lost-and-unaccounted-for gas resulting from to the operation of the Terminal up to a maximum aggregate amount of [●] percent

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(%[●]) of the DCQ per month.5

Risk of loss to any LNG (and any regasified LNG resulting therefrom) delivered from Customer to Operator shall pass from Customer to Operator at the Discharge Point and revert back to Customer as regasified LNG is delivered at the Delivery Point.

Payments: With respect to each month or portion thereof falling within the commissioning period, Customer shall pay Operator on a unit basis for all capacity utilized during such month (the “Commissioning Period Payment”) in accordance with the following formula:

MCP = MQR x UR

Where:

MCP = The Commissioning Period Payment, in Dollars, with respect to such month.

MQR = The total amount, in MMBtu, of regasified LNG delivered to Customer during such month.

UR = The Unit Rate, in Dollars per MMBtu, in effect during such month.

Following the Commercial Operation Date, Customer shall pay Operator each month a monthly payment (the “Monthly Payment”), as determined in accordance with the following formula, for all Terminal Services rendered by Operator during the applicable month:

MP = DC + TCC + TBC

Where:

MP = The Monthly Payment in Dollars with respect to such month.

DC = The Demand Charge with respect to such month, as determined below.

TCC = The Total Commodity Charge with respect to such month, as determined below.

TBC = The Total Barge Charge with respect to such month, as determined below.

The demand charge for a given month (the “Demand Charge”) shall be determined in accordance with the following formula:

DC = (DCQ x UR x 365)/12

Where:

5 Note to RFP: Bidders to propose figure.

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DC = The Demand Charge, in Dollars, with respect to such month.

DCQ = The Daily Contract Quantity, in MMBtu, in effect during such month.

UR = The Unit Rate, in Dollars per MMBtu, in effect during such month.

The total commodity charge for a given month, (the “Total Commodity Charge”) shall be determined in accordance with the following formula:

TCC = DDQ x DM x Yc

Where:

TCC = The Total Commodity Charge, in Dollars, with respect to such month.

DDQ = An amount in MMBtu equal to the simple average of the daily quantities of natural gas nominated by Customer and delivered to the Delivery Point by Operator during such month.

DM = The total number of days in such month.

Yc = The per-unit commodity rate, of $[●] per MMBtu, subject to adjustment to account for inflation as agreed in the TUA.6

The total barge charge for a given month (the “Total Barge Charge”) shall be determined in accordance with the following formula:

TBC = BDQ x DM x Yb

Where:

TBC = The Total Barge Charge in Dollars with respect to such month.

BDQ = An amount in MMBtu equal to the simple average of volume of LNG delivered from the Terminal to a barge or LNG vessel in accordance with the TUA for each day during such month.

DM = The total number of days in such month.

Yb = The per-unit barge rate, of $[●] per MMBtu, subject to adjustment to account for inflation as agreed in the TUA.7

6 Bidders to propose figure.


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The “Unit Rate” shall be calculated according to the following formula:

UR = (RF + RV)

Where:

UR = The Unit Rate, in Dollars per MMBtu, in effect with respect to the applicable calendar year.

RF = The rate, in Dollars per MMBtu, that comprises the fixed portion of the annual cost of service at the Terminal. RF will initially equal [__] Dollars ($[__]). RF will remain constant in all years where RV changes less than 3% from the previous year. In any contract year where RV escalates by more than 3% from the immediately preceding year, RF will escalate by a factor equal to the escalation rate of RV minus 3%.

RV = The rate, in Dollars per MMBtu, that comprises the variable portion of the annual cost of service at the Terminal, which shall be $[●], subject to adjustment to account for inflation as agreed in the TUA.8

Payment Mechanics:

The TUA shall provide for customary invoicing and payment mechanics. All payments shall be made in U.S. dollars.

Buy-Out Option: At any time from the fifteen (15th) anniversary of the Date of First Regular Delivery through the end of the Contract Period, or as otherwise provided below, Customer shall have the option, in its sole discretion, of purchasing, or causing its designee to purchase, free from any lien or encumbrance, all Operator’s right, title and interest in and to the Site, the Terminal and any portion thereof (including all intellectual property rights, fixtures, fittings, plant and equipment (including test equipment and special tools), and any spare parts maintained by Operator pursuant to the TUA) (the “Buy-Out”) for an amount equal to the net present value (calculated using a discount rate to be agreed in the TUA) of the Demand Charges (with the Unit Rate for such calculation to be based on the fixed portion of costs (RF) then in effect only, and without any amount payable in respect of the variable portion of costs (RV)) that would be due from the date the Buy-Out is consummated through the end of the then-effective Contract Period (the “Buy-Out Amount”).

As and when requested by Customer, Operator shall execute such bills of sale, assignment agreements or other documents as are


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reasonably requested by Customer to effect the Buy-Out, pursuant to mechanics to be agreed in the TUA.

Force Majeure: Neither party shall be liable for failure to perform an obligation to the extent that such failure is due to any event or circumstance beyond its control that prevents its performance of such obligation (as further defined in, and subject to the exclusions to be agreed in, the TUA, “Force Majeure”); provided, however

Notwithstanding the foregoing, if a Force Majeure event that prevents either party from performing all or substantially all of its obligations under the TUA has lasted for a period of thirty-six (36) consecutive months, the party not declaring Force Majeure shall have the right to terminate the TUA by notice of such termination delivered to the party declaring such Force Majeure;

, that if, by reason of Force Majeure affecting either party, Operator is unable to deliver regasified LNG to the Delivery Point in accordance with the TUA, Customer will not be liable for the payment of the portion of the Demand Charge allocable to such day.

provided, however, that Operator shall not be entitled to terminate the TUA due to such extended Force Majeure event if, prior to the end of such thirty-six (36) month period, Customer, or any other person or entity on Customer’s behalf, commences, and thereafter continues, to pay to Operator the Demand Charge that otherwise would be payable under the TUA on a monthly basis; and provided, further

Default and Termination:

, that Customer shall be entitled to reduce the face value of the Customer Performance Security on a Dollar-for-Dollar basis for any amounts paid to Operator pursuant to the foregoing proviso, up to an amount equal to fifty percent (50%) of the initial face value of the Customer Performance Security. Prior to the termination of the TUA, Operator shall not remove from the Site the LNG floating storage and regasification vessel or any other portion of the materials, plant or equipment necessary for the reliable, safe, efficient operation of the Terminal.

The TUA shall include customary events of default (subject to cure periods to be agreed in the TUA), including for material breaches of representations, warranties and covenants, insolvency-related events, failure to maintain any performance security required under the TUA and, in the case of Operator, failure to achieve any Construction Milestone on or before the applicable Construction Milestone Deadline; provided, however, that, in the event that Customer fails to pay to Operator any amount when due under the TUA (and after giving effect to the applicable cure period), Operator shall be entitled to draw such amounts from the Customer Performance Security; and provided, further, that Operator shall not be entitled to terminate the TUA for any failure of Customer to make any payment when due under

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the TUA unless and until Operator has drawn payment amounts from the Customer Performance Security exceeding fifty percent (50%) of the initial face value of the Customer Performance Security.

If the TUA is terminated due to an event of default by one of the parties, the non-defaulting party will be entitled to such damage remedies as are agreed in the TUA (the amount of any such damages payable, the “Termination Damages”). Notwithstanding any other provision of the TUA, in the event that the TUA is terminated by either party thereto then, prior to the effectiveness of such termination, Customer shall have the option (subject to the exercise by any other person or entity of a similar option under another agreement relating to the Terminal), in its sole discretion, of purchasing, or causing its designee to purchase, free from any lien or encumbrance, all Operator’s right, title and interest in and to the Site, the Terminal and any portion thereof (including all intellectual property rights, fixtures, fittings, plant and equipment (including test equipment and special tools), and any spare parts maintained by Operator pursuant to the TUA), at a price to be agreed in the TUA (which amount shall be reduced by the amount any Termination Damages payable by either party). If Customer elects to exercise the foregoing option, Operator shall execute such bills of sale, assignment agreements or other documents as are reasonably requested by Customer to effect such purchase, pursuant to mechanics to be agreed in the TUA.

Audit and Inspection Rights:

Customer and its representatives and designees shall have the right, from time to time, to (a) inspect the Terminal or any portion thereof, and, during the construction of the Terminal, any other site or location where any major piece of equipment, plant or material is being designed, fabricated or constructed, and (b) audit Operator’s books and records to the extent necessary to administer the TUA.

Operator Performance Security:

A guaranty from a creditworthy entity and/or letter of credit issued by a financial institution satisfactory to Customer, in each case, in form and substance satisfactory to Customer, in an aggregate amount of one hundred million Dollars ($100,000,000).

Customer Performance Security:

Security in a form to be agreed in the TUA, in an aggregate amount of one hundred million Dollars ($100,000,000).

Disputes: Disputes regarding specified technical issues shall be referred to expert determination under the Rules of Expertise of the International Chamber of Commerce Centre, pursuant to mechanics to be agreed in the TUA.

All other disputes shall be referred to final and binding arbitration

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under the London Court of International Arbitration Rules, pursuant to mechanics to be agreed in the TUA. The seat (legal place) of arbitration shall be London, England.

Governing Law: The TUA and any non-contractual obligations arising out of or in connection with it shall be governed by and construed in accordance with English law. The United Nations Convention on the International Sale of Goods and the Convention on the Limitation Period in the International Sale of Goods shall not apply to the TUA

Conditions Precedent: The TUA shall provide for customary conditions precedent applicable to the performance of each party’s obligations, together with long-stop dates for the satisfaction of conditions precedent.

Assignment: Neither party shall assign its rights or obligations under the TUA without the written consent of the other party, other than collateral assignments for purposes of financing.

Other Provisions: The TUA shall include customary representations and warranties by each party and other customary provisions including with respect to insurance, limitations of liability for consequential damages, indemnification (with customary exclusions for gross negligence and wilful misconduct) and metering and measurement requirements.

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APPENDIX A

LNG QUALITY SPECIFICATIONS, MEASUREMENT, ANALYSIS, AND CALCULATION

The LNG delivered under the TUA shall, when it is returned to a vapor condition at the Terminal, comply with the quality specifications: Gross Calorific Value: Minimum Maximum

Other Specifications: 1040 Btu/scf 1145 Btu/scf

• Hydrogen Sulphide (H2S) 5.5 mg/Nm3

Maximum

• Mercaptan Sulphur 5.0 mg/Nm3 • Total Sulphur 30 mg/Nm3 • Carbon Dioxide 0.01 molecular percentage

• Constituent elements varying within the following percentage limits (in molecular

percentage):

Nitrogen between 0.00 and 1.00 Methane between 82.50 and 100.00 Ethane between 0.00 and 9.50 Propane between 0.00 and 5.00 Isobutane between 0.00 and 3.50 Normal Butane between 0.00 and 3.00 Pentanes Plus between 0.00 and 0.50

• No water or mercury;

• The gas shall not at any time have an uncombined oxygen content in excess of ten (10) ppm by volume;

• No active bacteria or bacterial agent, including sulphate reducing bacteria or acid-producing bacterial; and

• No hazardous or toxic substances.

PART 4 – ATTACHMENTS

Attachment 01 - Information Memorandum

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PRIVATE AND CONFIDENTIAL

JAMAICA LNG

INFORMATION MEMORANDUM

AUGUST 2011

2

DISCLAIMER

The information in this Information Memorandum (the “Information Memorandum”) has been prepared from information supplied by or on behalf of the Office of the Cabinet of Jamaica and is being furnished by Taylor-DeJongh, Inc. (“TDJ” or the “Financial Advisor”) to you as a potential bidder for the roles described herein (the “Recipient”) in considering the proposed LNG project described in the Information Memorandum (the “Project”). Neither TDJ nor any of its officers, directors, or affiliates have independently verified the contents of the Information Memorandum. No representation, warranty or undertaking (express or implied) is made, and no responsibility is accepted, by TDJ or any of its officers, directors, or affiliates as to the adequacy, accuracy, completeness or reasonableness of the Information Memorandum or any further information, notice or document at any time supplied in connection with the financing. The information contained herein is confidential and has been prepared to assist interested parties in making their own evaluation of the proposed Jamaican LNG project and for no other purpose. The information is preliminary in nature and does not purport to be all-inclusive or to contain all information that a prospective party may desire. It is understood that each recipient of this Information Memorandum will perform its own independent investigation and analysis of the proposed Jamaican LNG project as it deems relevant and without reliance on TDJ. The information contained herein is not a substitute for the recipient’s independent investigation and analysis. The recipient acknowledges the Information Memorandum to include confidential, sensitive and proprietary information and agrees that it shall use precautions in accordance with its established procedures to keep the material contained in the Information Memorandum confidential. The contents of the Information Memorandum may not be reproduced or used in whole or in part for any other purpose, nor should it be disclosed to any other party, except as expressly permitted by the terms of the aforementioned confidentiality undertaking. [

3

TABLE OF CONTENTS

Table of Contents 1. The Jamaica LNG Initiative ............................................................................................................................ 6

1.1. Background ....................................................................................................................................... 6 1.2. Organization ..................................................................................................................................... 6

2. Jamaica Country Overview ............................................................................................................................ 7 2.1. Overview of the Jamaican Economy ................................................................................................ 8 2.2. Government Fiscal Situation ............................................................................................................ 9 2.3. Institutional Framework ................................................................................................................. 11

3. Bauxite Mining and Alumina Refining Industry Overview ........................................................................... 12 3.1. Jamaica’s Bauxite/Alumina Industry .............................................................................................. 12 3.2. Jamaica’s Bauxite/ Alumina Industry Major Players ...................................................................... 13 3.3. Bauxite Industry and Energy .......................................................................................................... 14

4. Power Sector Overview ............................................................................................................................... 15 4.1. Power Producers ............................................................................................................................ 15 4.2. Diversification ................................................................................................................................. 16 4.3. JPS ................................................................................................................................................... 17

4.3.1. Business ............................................................................................................................. 17 4.3.2. Shareholders ..................................................................................................................... 18 4.3.3. Historical Performance ...................................................................................................... 18 4.3.4. Offtaker Credit ................................................................................................................... 19

5. Overview of End Users ................................................................................................................................ 21 5.1. Jamalco ........................................................................................................................................... 21

5.1.1. Business ............................................................................................................................. 21 5.1.2. Shareholders ..................................................................................................................... 22 5.1.3. Historical Performance ...................................................................................................... 22 5.1.4. LNG Demand ..................................................................................................................... 22

5.2. New IPP .......................................................................................................................................... 22 5.2.1. Business ............................................................................................................................. 22 5.2.2. Shareholders ..................................................................................................................... 23 5.2.3. LNG Demand ..................................................................................................................... 23

5.3. JEP ................................................................................................................................................... 23 5.3.1. Business ............................................................................................................................. 23 5.3.2. Shareholders ..................................................................................................................... 23 5.3.3. LNG Demand ..................................................................................................................... 24

6. Infrastructure Overview .............................................................................................................................. 25 7. Commercial Structure ................................................................................................................................. 27

7.1. Overview......................................................................................................................................... 27 7.1.1. JGT ..................................................................................................................................... 27

7.2. The LNG SPA ................................................................................................................................... 28

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Table of Figures Figure 1. Map of Jamaica ........................................................................................................................................... 7 Figure 2. Jamaica GDP Breakdown ............................................................................................................................ 8 Figure 3: Principal Exports, 2009 (USD million) ......................................................................................................... 9 Figure 4: Main Destination of Exports, 2009 ............................................................................................................. 9 Figure 5. GDP & public debt forecast (USD billion) ................................................................................................. 10 Figure 6. BOJ net int’l reserves and GOJ - US 6m T-Bill spread ............................................................................... 11 Figure 7. Global Bauxite Production, 2009 (‘000 tonnes) ....................................................................................... 12 Figure 8. Global Bauxite Reserves, 2009 (‘000 tonnes) ........................................................................................... 13 Figure 9. Jamaica production (000 tonnes) ............................................................................................................. 13 Figure 10. 2008-2020 power demand by sector (‘000 MW/year) .......................................................................... 15 Figure 11. 2009 generation sector fuel mix ............................................................................................................. 17 Figure 12. JPS Generation Portfolio ......................................................................................................................... 18 Figure 13. JPS Revenue and Gross Margins ............................................................................................................. 19 Figure 14. 2014-2020 LNG demand by users (‘000 tpa) .......................................................................................... 21 Figure 15. Jamalco Ownership Structure ................................................................................................................ 22 Figure 16. New 360 MW IPP Project Company ....................................................................................................... 23 Figure 17. Jamaica SPV Ownership Structure .......................................................................................................... 27

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Table of Tables Table 1. Jamaica Alumina Refineries ....................................................................................................................... 14 Table 2. Jamaica Installed Capacity (MW) by Power Producer ............................................................................... 16 Table 3. JPS financial Ratios ..................................................................................................................................... 19 Table 4. “Base Load” End User LNG Demand .......................................................................................................... 21

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1. THE JAMAICA LNG INITIATIVE

1.1. BACKGROUND

To improve its international competitiveness and reduce its dependence on imported petroleum, the Government of Jamaica (GOJ) has implemented a strategy to diversify its energy supply. The strategy aims at introducing imported natural gas into Jamaica’s energy supply mix to obtain security of supplies and achieve long-term stability in energy prices and environmental sustainability in energy provision. Liquefied natural gas (LNG) will be imported to and regasified at an LNG Storage and Regasification Terminal (SRT) which will be located within the Portland Bight, St. Catherine Parish, on the south coast of Jamaica and transported through a natural gas transportation system to the end users in the power generation and bauxite/alumina production. The initial LNG demand from the “anchor” end users is equivalent to over 0.8 million tonnes of LNG per annum. It is envisaged that demand for LNG will increase overtime reaching 2.5 million tonnes per annum by 2025, with the expansion of the bauxite/alumina sector and construction of new gas-fired IPPs. First delivery of LNG is targeted for Q1 2014. 1.2. ORGANIZATION

In order to execute on this plan to diversify its energy supply with the importation of LNG, the GOJ has elevated the LNG initiative to the Office of the Prime Minister to provide better inter-departmental coordination and transparency. An LNG Steering Committee was established in December 2010 to oversee the development of the Jamaica LNG initiative chaired and comprised of prominent Jamaican businessman and representatives of various government agencies involved with the energy sector. The LNG Steering Committee reports to the Minister of Energy & Mining, Honourable Clive Mullings. The GOJ has approved the issuance of two Requests for Proposals (RFPs), one for LNG Supply and the other for the infrastructure required for the receiving, storage and re-gasification of the LNG. These RFPs will be issued concurrently in order to provide close coordination between the two processes. The LNG Steering Committee is managing the Jamaica LNG Project in Jamaica, including issuing the RFPs, evaluating the responses and negotiating the various agreements. A private sector Special Purpose Vehicle (SPV), as described in this document, will be established and will be the legal counterparty to execute the various commercial agreements.

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2. JAMAICA COUNTRY OVERVIEW

Jamaica is an island nation, 10,991 square kilometers in size, located in the Caribbean. The country is a parliamentary democracy, with a bicameral legislature composed of an elected House of Representatives and a nominated Senate. With a population of more than 2.7 million and a gross domestic product (GDP) of approximately USD13.8 billion in 2010, the nominal GDP per capital was USD 4,825.1 Jamaica’s economy is traditionally based around the production of bauxite/alumina, sugar and manufactured goods for export as well as a large tourist industry. The economy is currently poised for a recovery after a period of contraction during the global financial crisis. The Jamaican economy experienced annualized GDP growth of 1.5% in real GDP in the first quarter of 2011. This boost originated largely from significant expansions in mining and agriculture. Output in mining rose by 38.8%, while agricultural output increased by 13.5%.2 The Jamaican Central Bank has forecasted continued growth in the range of one to two percent for fiscal year 2011-12. Growth is expected to be driven by a government infrastructure program, as well as continued expansion in mining, tourism, and agriculture.3

Figure 1. Map of Jamaica

1 IMF 2 Jamaica Observer, May 26, 2011 3 The Jamaica Gleaner, May 20, 2011

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2.1. OVERVIEW OF THE JAMAICAN ECONOMY

Jamaica’s economy is centered on the advantages it enjoys in natural resources and climate, with successful bauxite/alumina, tourism, and agricultural industries. Bauxite is the main mineral resource found in commercial quantities in Jamaica. It is close to the surface and therefore relatively inexpensive to mine, which compensates for the low mineral concentration within the ore. This sector accounts for approximately 10% of Jamaica’s GDP. Figure 2 provides a high-level breakdown of Jamaica’s GDP.

Figure 2. Jamaica GDP Breakdown4

Jamaica has developed a robust tourism industry, capitalizing on its temperate climate, natural beaches, and proximity to North America. Tourism is not captured as a distinct sector within the services category in the national accounts, but a useful proxy, the hotel and restaurants sector, accounted for 6.8% of GDP in 2006, according to the Planning Institute of Jamaica. The contribution of tourism to the economy is greater than this figure suggests, given the support that tourism provides to other sectors, such as construction and transport. Agriculture, which accounts for 6% of GDP, is a significant source of jobs in Jamaica, accounting for approximately 20% of total employment. Sugarcane is the main crop planted on the coastal plains to the south of the island, while bananas are grown largely in the north and south-east. High-quality coffee is grown in the eastern and central highlands. Figure 3 provides a highlight of Jamaica’s principal exports. As a result of Jamaica’s language, history, and location, the country has important economic and political links with the United States, Canada, and the United Kingdom. The United States has a dominating influence on the country’s economy, due to the size, proximity, and continued migration flows. As a result, the fortunes of the Jamaican economy are closely tied with those of the United States. Figure 4 provides a breakdown of Jamaica’s destination markets.

4 EIU Country Report April 2011

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Figure 3: Principal Exports, 2009 (USD million) Figure 4: Main Destination of Exports, 2009

Growth in the Jamaican economy in the near future will be driven by improvements in mining and tourism. Alumina production is coming back on stream, although mining companies currently continue to operate with spare capacity. Tourism, a major employer, will contribute largely to the recovery in the services sector in 2011. However, the sector will not return to the strong performance of the past until demand in neighboring countries, most importantly the US, appears to be on a more solid footing.5 2.2. GOVERNMENT FISCAL SITUATION

The GOJ inherited an onerous debt burden from a financial sector crisis in the mid-1990s, which is estimated to have added to the government’s debt an equivalent of 40% of GDP. The GOJ has made gradual reduction of the public debt through the maintenance of tight fiscal and monetary policy the cornerstone of economic policymaking for many years. As a result of these measures, the public debt ratio is expected to ease substantially from a peak of 141% of GDP in 2004 to 122% of GDP by end-20126 (see Figure 5).

5 EIU April 2011 Country Report 6 EIU April 2011 Country Report

Alumina368

Sugar72.3

Bauxite85.4 Others

43.0%US

32.9%

UK4.3%

Canada10.5%China

9.3%

10

Figure 5. GDP & public debt forecast (USD billion)7

On February 4, 2010, under financial pressure in the midst of the global financial crisis, the GOJ sought a USD 1.27 billion IMF Stand-By Arrangement. As a part of this agreement, the GOJ agreed to implement a two year plan, which includes: Reform of the public sector to substantially reduce the large budget deficit, A debt strategy to reduce debt servicing costs, Reforms to the financial sector to reduce risks.

In the immediate aftermath of the IMF agreement, Fitch Ratings upgraded the GOJ long-term foreign currency issuer default rating from CCC to B-. The Rating Outlook is Stable. Fitch has also upgraded the short-term foreign currency rating to 'B' and the country ceiling rating to 'B'. The rating is underpinned by the government's commitment to maintain macroeconomic stability and implement reforms as envisioned in the IMF program, as well as stronger per capita income and governance indicators than the corresponding 'B' medians.8 Standard and Poor’s now also rates Jamaica’s long term credit risk as a B-.9 In February 2011, the GOJ successfully issued a USD 400 million Eurobond at a record low yield (7.95%), less than a year after it was forced to restructure the domestic debt with IMF assistance. Deutsche Bank and BNP Paribas, the lead managers for the transaction, reported that the issue was heavily oversubscribed with over $1 billion in orders.10 This confidence boost stemming from IMF support has also allowed monetary authorities to reduce interest rates substantially without producing depreciation pressures on the Jamaican dollar.11 Figure 6 highlights the increased investor confidence in the country, as demonstrated by the GOJ-US T-Bill spread which has steadily declined since January 2009.

7 EIU Country Report April 2011 8 Jamaica Observer, February 16, 2010 9 S&P 10 Jamaica Observer, February 16, 2011 11 EIU Country Profile 2008

90%

100%

110%

120%

130%

140%

-

4,000

8,000

12,000

16,000

20,000

2006A 2007A 2008A 2009E 2010E 2011E 2012E

GDP Net Public Debt (% of GDP)

11

Figure 6. BOJ net int’l reserves and GOJ - US 6m T-Bill spread

2.3. INSTITUTIONAL FRAMEWORK

The Government of Jamaica’s National Energy Policy 2009 – 2030 sets out a strategic vision of “a modern, efficient, diversified and environmentally sustainable energy sector providing affordable and accessible energy supplies with long-term energy security and supported by informed public behavior on energy issues and an appropriate policy, regulatory and institutional framework.” The Government of Jamaica is presently developing a Natural Gas Industry Legal and Regulatory Framework to enable the successful introduction of natural gas into Jamaica’s energy supply mix. The Framework will cover, inter alia:

• Legal, Institutional and Administration Policy • Taxation and Tax Incentives • Permitting and Licensing • Environmental and Safety Standards • Third-Party Access to Terminal and Pipeline • Rights of Way • Role of the Regulator

A draft policy is under review, with a target date for adoption by the end of 2011.

12

3. BAUXITE MINING AND ALUMINA REFINING INDUSTRY OVERVIEW

Alumina is the raw material used in the production of aluminum, the world’s most widely used non-ferrous metal. It is produced from bauxite ore, which is refined in a semi energy-intensive process into alumina. The main economic factors in bauxite extraction include the accessibility of the ore and the concentration of alumina within. Bauxite ore is a relatively minor cost in the production of aluminum, which requires large amounts of energy and thus often takes place in countries with access to low-cost energy. Consequently, Jamaican producers do not have facilities to produce aluminum, but instead focus on the front end of the aluminum value chain, which includes the mining of bauxite ore and the refining of alumina. 3.1. JAMAICA’S BAUXITE/ALUMINA INDUSTRY

Bauxite mining and alumina refining is and has been historically one of Jamaica’s most important industries and foreign exchange earners. Bauxite is the main mineral resource found in commercial quantities in Jamaica. It is close to the surface and therefore relatively inexpensive to mine, giving Jamaica a competitive advantage in extraction. Jamaica’s bauxite industry also benefits from the island’s geographic proximity to the large North American market. In 2009, Jamaica was the word’s sixth largest producer of bauxite ore (see Figure 7). Jamaica has the world’s fourth-highest bauxite reserve base, estimated at 2 billion tonnes (see Figure 8).

Figure 7. Global Bauxite Production, 2009 (‘000 tonnes)

13

Figure 8. Global Bauxite Reserves, 2009 (‘000 tonnes)

Both bauxite mining and alumina refining have been deeply affected by the global crises in 2009. Mining of bauxite has experienced a comeback in 2010, rising above pre-crisis levels, but alumina production, while increasing, has remained well below pre-crisis levels (see Figure 9).12

Figure 9. Jamaica production (000 tonnes)13

3.2. JAMAICA’S BAUXITE/ ALUMINA INDUSTRY MAJOR PLAYERS

Investors in Jamaica’s bauxite sector include Alcoa, the joint owner with the GOJ of Jamalco; UC Rusal, the majority owner of Windalco and Alpart (Alpart is a joint venture with Norsk Hydro) ; and Century Alumina, joint owner of the St Ann bauxite mine. Government efforts to attract further investment from multinationals have

12 EIU April 2011 Country Report 13 EIU Country Reports – Jamaica, February 2011 and April 2011

14

included a 2002 agreement with Alcoa to replace a bauxite royalty with an income tax regime. Alcoa subsequently expanded the Jamalco Alumina Refinery’s annual capacity from 1 million tonnes to 1.25 million tonnes in 2003 and to 1.425 million tonnes in March 2007. A much larger, USD 800 million expansion project to double capacity to 2.8 million tonnes per year has been proposed, and is pending resolution of present energy supply constraints. Jamaica’s alumina refineries, their ownership structure and nameplate capacity are depicted in Table 1 below.

Table 1. Jamaica Alumina Refineries

Facility Owner(s) Nameplate capacity Date established

Alpart Alpart (65% UC Rusal, 35% Norsk Hydro)

1.65 MMtpa 1969

Clarendon Jamalco (55% AMOJ(1), 45% CAP(2))

1.47 MMtpa 1972

Ewarton Windalco (93% UC Rusal, 7% GOJ)

0.65 MMtpa 1957

Kirkvine Windalco (93% UC Rusal, 7% GOJ)

0.60 MMtpa 1952

(1) AMOJ is owned 60% by Alcoa and 40% by Alumina Limited (2) Clarendon Alumina Production (CAP) is 100% owned by the Government of Jamaica

3.3. BAUXITE INDUSTRY AND ENERGY

The Jamaican bauxite mining/alumina refining industry competes in the world market with alumina producers with access to cheaper sources energy. While alumina producers in Jamaica use heavy fuel oil (Bunker C) and diesel, many of its competitors worldwide have access to competitively priced hydro or indigenous natural gas. The bauxite and alumina industry accounts for over one-third of total oil imports by volume.14 In 2009, two of the major alumina companies were forced to halt operations due to the high price of crude oil on the international market.15 This competitive disadvantage places the Jamaican alumina producers on the lowest quartile of the alumina global cost curve. In order to increase the competitiveness of the alumina industry in Jamaica, the sector must seek to reduce the cost and volatility of energy prices. Natural gas, purchased on long-term contracts and at stable prices, could offer an attractive alternative to the industry, which may allow it to “slide” down the cost curve away from the lowest quartile of alumina producers.

14 EIU Country Profile 2008 15 PCJ Report

15

4. POWER SECTOR OVERVIEW

Jamaica currently has an installed capacity of 853 MW. Net generation for 2010 was estimated at 4,253.8 GWh. Current peak power demand stands at 644 MW. Power demand in Jamaica is growing at a rate of around 4% per annum and the country needs to add new generating capacity soon.16 Over the next 20 years, approximately 1400 MW of new base load power plant capacity will have to be constructed in Jamaica to meet the projected demand for electricity and to displace aged power plants, depending on the penetration of generation from renewable sources. Approximately 800 MW of this new capacity needs to be constructed in the coming decade, highlighting the urgency of the issue. The capital requirements for the new power plant fleet are in the range of USD 6 billion to USD 8 billion depending on the mix of technologies that will be deployed.17 Figure 10 highlights the power demand (actual and forecasted) by sector.

Figure 10. 2008-2020 power demand by sector (‘000 MW/year)18

In December 2010, the Government of Jamaica issued an open tender for the development, financing and construction of 480 MW of base-load generating capacity on a Build, Own and Operate Basis, to be developed in two stages. The plants would sign a 20 year PPA with Jamaica Public Service Company Limited (JPS), the country’s integrated utility, subject to renewal after the initial term. The first stage plant (360 MW) is scheduled to start up in April 2014 and the second stage plant (120 MW) is scheduled to start up in 2016. 4.1. POWER PRODUCERS

Generation is dominated by the Jamaica Public Service Company Limited (JPS), which, with 637 MW, accounts for about 75% of Jamaica’s installed capacity. The balance is produced by a few smaller IPPs. Table 2 provides a breakdown of Jamaica’s installed capacity by producer. There are also a number of self-producers of electricity

16 Poten & Partners, LNG in World Markets 17 OUR 2010 Expansion Plan 18 OUR 2010 Expansion Plan

0

1,000

2,000

3,000

4,000

5,000

6,000

2008 2010 2012 2014 2016 2018 2020

Street Lighting

Large Commercial -Med. Voltage

Large Commercial - Low Voltage

Small Commercial

Residential

16

in the country, with the largest being the bauxite/alumina companies and the sugar refineries19, which are not accounted for in the table.

Table 2. Jamaica Installed Capacity (MW) by Power Producer

Generator MW

JPS 637

Jamaica Energy Partners (JEP) 124

JPPC 61

Other IPP 31

Total 853

4.2. DIVERSIFICATION

As the power needs of Jamaica continue to grow, the Government of Jamaica is committed to diversifying its energy base by introducing natural gas into its energy mix. The Government seeks to reduce its dependence on oil with the goal of reducing the overall cost and volatility of energy, which will help improve the competitiveness of the Jamaican economy. Currently, approximately 95% of Jamaican power generation is fuelled by No.2/No.6 fuel oil (see Figure 11). While expansion of the renewable sources of power is desirable, a pure renewables strategy is not seen as a viable baseload source of power. Further, the cost of large-scale conversion to renewable energy is seen as prohibitively capital intensive. Thus, the gravitation towards renewable projects for electricity generation in Jamaica has not been aggressive. Therefore, as an ageing fleet of fuel oil plants are decommissioned and peak demand continues to grow, the Government of Jamaica plans for a mixture of new natural gas and coal-fired generation to meet supply requirements.

19 OUR 2010 Expansion Plan

17

Figure 11. 2009 generation sector fuel mix20

4.3. JPS

4.3.1. BUSINESS JPS is an integrated utility that holds an exclusive license for the transmission and distribution of electricity in Jamaica for public and private purposes in all parts of the island. At the end of 2009, JPS had a customer base of 584,623 including residential, commercial and industrial consumers. Additionally, JPS buys power from the independent power producers. The Office of Utilities Regulation (OUR), the independent regulatory agency, monitors and regulates JPS JPS generates the majority of power it sells to end-users through its portfolio of fossil fuel, hydroelectric, and wind generation assets. JPS presently owns and operates eighteen (18) thermal power generating units located at four sites (Rockfort, Hunts Bay, Bogue and Old Harbour) and eight hydro plants, independently sited across the island. These JPS plants accounts for a total installed capacity of approximately 637 MW. Independent Power Producers (IPPs) presently supply approximately 190 MW of firm capacity to grid under long-term contracts with JPS, with an additional 65 MW of IPP capacity currently under construction. A wind power facility (IPP) with an installed capacity of 20.7 MW also supplies electrical energy to the grid under contract.21

20 OUR 2010 Expansion Plan 21 OUR 2010 Expansion Plan

Hydro + Wind (5%)

Fuel Oil (95%)

18

Figure 12. JPS Generation Portfolio22

4.3.2. SHAREHOLDERS JPS was privatized by the GOJ in 2001 at which time 80% of the common equity was sold to Mirant JPSCo (Barbados) SKL (Mirant). The GOJ retained a 20% shareholding in JPS. On August 9, 2007 Marubeni Caribbean Power Holdings, Inc., a wholly owned subsidiary of Marubeni Corporation of Japan, purchased Mirant’s majority shares in JPS. In April 2011 Marubeni transferred a 40% stake in JPS to the Korea East West Power Company Limited (KEWP). The sale reduces Marubeni's ownership in JPS to 40%. 4.3.3. HISTORICAL PERFORMANCE The financial performance of JPS has remained relatively steady in recent years. Even during the global financial crisis, JPS was able to maintain a positive performance with improved gross margins due to improved operational efficiency and lower than anticipated financing costs. Figure 13 and Table 3 provide a highlight of JPS’ financial performance. It should be noted that the spike in revenue in 2008 reflects the higher energy costs that were passed through to the consumers.

22 To confirm

Fossil fuel fired plant

Hydroelectric plant

Wind farm

223 MW

123 MW

40 MW224 MW

2.5 MW1.1 MW

4 MW4.8 MW

3.2 MW

6 MW

<1 MW

3 MW

19

Figure 13. JPS Revenue and Gross Margins23

Table 3. JPS financial Ratios24

Ratio 2007 2008 2009 2010 LTM (to Mar 2011)

Current 1.5x 1.6x 1.5x 1.6x 1.8x

Quick 1.2x 1.2x 1.2x 1.3x 1.6x

Total Debt/Capital (%) 40.2 44.8 44.6 46.4 47.7

EBITDA/Interest Exp. 3.2x 3.2x 3.6x 3.5x 3.6x

Total Debt/EBITDA 2.6x 3x 2.6x 2.5x 2.6x

4.3.4. OFFTAKER CREDIT JPS’ source of ultimate credit as an offtaker is their license to operate as the sole provider of transmission and distribution of electricity in Jamaica. The revenue flows to the company are determined by the OUR. The OUR determines the tariff structure charged by JPS. The tariff can be broken down into two categories, including:

• Fuel charge: represents the total cost of fuel (both from JPS and IPPs) to produce power, adjusted for system heat rate of 10,400 kJ/kWh and system losses of 19.5%

23 Capital IQ, Company Reports 24 Capital IQ, Company Reports

0%

10%

20%

30%

40%

0

200

400

600

800

1,000

2006 2007 2008 2009 1H2010 (LTM)

Revenue (Left Axis) Gross Margin (Right Axis)

20

• Non-fuel tariff: base rate set every five years, adjusted annually based on productivity offset for inflation and performance against quality of service targets set by the OUR

In essence, JPS is able to pass through all fuel costs, provided it operates within certain efficiency levels required by the OUR.

21

5. OVERVIEW OF END USERS

A summary of the prospective “base load” end users of natural gas in Jamaica is presented in Table 4 below.

Table 4. “Base Load” End User LNG Demand

End User Potential LNG Demand (tpa) Jamalco 320,000 JEP 140,000 New 360 MW IPP 370,000 Total 830,000

Figure 14 depicts the build-up of LNG demand starting in 2014 until 2020. LNG demand in 2014 is expected to be around 830,000 tpa, and includes Jamalco (320,000 tpa), JEP (140,000 tpa), and the phase I of the new IPP (370,000 tpa).

Demand is expected to increase to 1,020,000 tpa, with the phase II of the IPP (120 MW) coming on line in 2016. The figure below also depicts future LNG demand potential from new power generation as well as demand from other alumina refiners such as Alpart.

Figure 14. 2014-2020 LNG demand by users (‘000 tpa)

5.1. JAMALCO

5.1.1. BUSINESS Jamalco is a leading bauxite mining and alumina refining company in Jamaica. Founded in 1959 as Alcoa Minerals of Jamaica, the company was renamed Jamalco in 1988 as the GOJ increased its stake in the joint

0

500

1000

1500

2000

2500

3000

2014 2016 2018 2020 2022 2024 2026 2028 2030 2032

Jamalco JEPIPP Phase 1 (360 MW) IPP Phase 2 (120 MW)Additional Potential Power Demand Additional Potential Alumina Demand

22

venture. The major assets of the company consist of bauxite mining operations in Manchester and an alumina refinery in Clarendon, with an annual capacity of 1.47 million tonnes per annum of alumina. 5.1.2. SHAREHOLDERS Jamalco is majority-owned (55%) by Alcoa Minerals of Jamaica LLC (which in turn is owned by Alcoa (60%) and by Alumina Ltd (40%)). The Government of Jamaica owns 45% of Jamalco, through Clarendon Alumina Production Ltd. (see Figure 15)

Figure 15. Jamalco Ownership Structure

5.1.3. HISTORICAL PERFORMANCE High energy costs place Jamalco on the highest quartiles of the global cost curve for alumina production. Jamalco’s refining process requires large amounts of steam, which is presently produced by boilers running on heavy fuel oil. The company is trying to find a solution to replacing liquid fuel. 5.1.4. LNG DEMAND Switching from oil to natural gas would require a conversion of the steam boilers and calciners. The boilers could in the event of unavailability of natural gas run on oil (dual fuel capability). This conversion requires a USD 55 million investment. Importantly, in order to make this large investment, the LNG must be delivered at a competitive price point per MMBtu. Jamalco’s potential demand for LNG is estimated at 320,000 tonnes per annum. Jamalco is also contemplating an expansion of its mining operations output to 2.8 MMtpa of alumina, which would increase its LNG demand to 700,000 tonnes per annum. 5.2. NEW IPP

5.2.1. BUSINESS In November 2010, the Government of Jamaica issued an open tender for 480 MW of base-load generating capacity to the national grid of Jamaica on a Build, Own and Operate basis, to be developed in two stages. The plant would sign a 20 year PPA with JPS, subject to renewal after the initial term. The GOJ is encouraging the construction of natural gas-fired IPP projects by giving those projects an additional 15% weighting factor in the first two phases of the IPP evaluation process.

Alcoa Alumina Ltd.

Alcoa MineralsOf Jamaica

Clarendon Alumina Production

GOJ60% 40% 100%

55% 45%

23

A company comprised of affiliates of Marubeni, Korea East-West Power and JPS were the only bidders and are currently in negotiations with the GOJ. 5.2.2. SHAREHOLDERS The ownership structure of the new IPP is depicted in Figure 16.

Figure 16. New 360 MW IPP Project Company

5.2.3. LNG DEMAND The new 360 MW IPP will be put into operation in early 2014. This would yield a demand of approximately 370,000 tonnes of LNG per year. Additional capacity is expected to come on stream in 2016, and will yield a demand of approximately 120,000 tonnes of LNG per year. The fully operating facility would thus yield a total demand of roughly 470,000 tonnes of LNG per annum at baseload operation. 5.3. JEP

5.3.1. BUSINESS Founded in 1995, Jamaica Energy Partners (JEP) is the largest independent power producer in Jamaica. With a current electricity capacity of 124 MW, JEP produces almost 20% of electricity generated in the country. The Dr. Bird Power Facility, JEP’s existing operating generation asset, consists of two power barges composed of 11 medium speed diesel engines, located 22 miles west of Kingston in the Old Harbour/Port Esquivel area. JEP will be looking to convert the Dr. Bird facility to natural gas. JEP is also currently constructing the 66 MW West Kingston Power Plant, which is due to begin operations in March 2012. While the technology used by the project will initially run on fuel oil, JEP has been designed the plant to be converted into a natural gas-burning facility if gas becomes available.25 5.3.2. SHAREHOLDERS Jamaica Energy Partners is 100% owned by the Latin III Power Fund, which is controlled by New York-based investment firm Conduit Capital Partners, LLC.

25 Jamaica Observer, December 4, 2010

Marubeni Caribbean Power

Holdings

Jamaica Public Services Co. Ltd.

20%

Korea East-West Power

40%40%

360 MW IPPProject Company

24

5.3.3. LNG DEMAND With the conversion of the Dr. Bird Power Facility to use natural gas, the potential demand for LNG would be approximately 140,000 tpa. JEP is also developing the West Kingston Power Plant, with a proposed capacity of 66 MW. The potential LNG demand from this source would be 50,000 tpa.

25

6. INFRASTRUCTURE OVERVIEW

LNG will be regasified at a planned LNG Storage and Regasification Terminal (SRT) which will be located within the Portland Bight, St. Catherine Parish, on the south coast of Jamaica. This location was selected due to its proximity to the initial customers in both the power and alumina/bauxite industries. WorleyParsons has been engaged as the Technical Advisor for the LNG initiative and has prepared the Terms of Reference for the RFP for LNG Infrastructure which is being issued concurrently with the issuance of this RFP for LNG Supply. The SRT will be designed with minimum technical complexity and keeping safety in view considering meteorological and metocean data at site. The Terminal will be designed with zero flaring during normal operation including loading, holding and regasification modes. Only proven equipment and units will be used, considering high standards for reliability and availability, and with minimum downtime for maintenance. The base design of the SRT will be a two-berth jetty with a cross-jetty hard-piped offloading system, with a Floating Storage Regasification Unit (FSRU) or a Floating Storage Unit (FSU) plus a regasification barge, acting as the main storage and regasification facilities for the delivered LNG. The preferred location for the SRT is a near-shore concept, close to Port Esquivel. The approach channel turning basin and berthing facilities will be designed to accommodate standard LNG vessels with a maximum capacity of up to 265,000 m3, a length not to exceed three hundred thirty-five (335) meters, a breadth not to exceed fifty-five (55) meters and a scantling draft not to exceed fourteen (14.0) meters. The nominal regasification capacity of the SRT will initially supply 1.10 MMtpa (150 MMscfd), expandable to 2.65 MMtpa (350 MMscfd) in the future. The Terminal will be designed to have the capacity to accept LNG cargos that will be able to unload either from the port or starboard side at a rate of not less than twelve thousand cubic meters (12,000 m3) per hour when LNG is discharged at one hundred (100) meters of head at the LNGC’s manifold. The berthing facilities will provide for industry standard hard unloading arms, expansion drums, purging facility and lifting equipment, independent power supply etc. and mooring facilities including breasting and mooring dolphins of a design and placement consistent with best practices and the target overall terminal availability of 99.5% per annum. The terminal will be designed with a sparing philosophy that can accommodate the target availability (this will be demonstrated by a terminal RAM analysis conducted by the Supplier). LNG vessels will not be required or permitted to perform vessel-to-vessel transfers through flexible hoses. The LNG receiving terminal will be capable of storing between 125,000 m3 to 180,000 m3 with a working capacity of 98.5% of the gross storage capacity; the exact size will depend on the solution provided by the supplier. The storage will be able to receive and send out LNG simultaneously to provide a constant flow to the regasification facility. The facility will be able to provide a constant flow of natural gas all year round at name plate capacity of the regasification facility, with the exception that during times of hurricane that come within 200 nautical miles of the facility, the natural gas flow is interrupted.

26

During this time the FSRU or FSU shall be able to disconnect. The FSRU or FSU will reconnect and regasify at boiler plate capacity within 48 hours after the hurricane event. The interruption of natural gas supply during hurricanes will be kept at a minimum and shall not exceed a total duration of four days per event. Excluding hurricane events the terminal availability, i.e. constant natural gas flow will be better than 99.5% per annum over the twenty (20) year design life.

27

7. COMMERCIAL STRUCTURE

7.1. OVERVIEW

The buyer of LNG under the LNG SPA will be a newly formed company, called the Jamaica Gas Trust Co. (also “JGT”). JGT will contract on a long-term basis with the “Infrastructure Provider” for the regasification of LNG and the transportation of natural gas to the End User delivery points. JGT will sell natural gas to each of the End Users under long-term gas sales agreements (“GSA”) that follow substantially in form and substance the terms set out in the LNG SPA. This commercial structure is set out in Figure 17 below.

Figure 17. Jamaica SPV Ownership Structure

7.1.1. JGT The LNG Steering Committee will establish JGT, which will be a special purpose marketing and investment company that will undertake the role of commercial intermediary. The role of JGT is the purchase of LNG, the payment of services to the Infrastructure Provider, and the sale of natural gas to the End Users. This role would entail scheduling of LNG imports and inventory, gas sales and the management of payments to the LNG Seller and from the End Users via an escrow structure. JGT will establish a subsidiary (“LNG Opco”) that will perform scheduling of LNG imports, LNG inventory, pipeline nominations, and gas sales and the management of payments to the LNG Seller and from the End Users. LNG Opco will perform the following functions:

1. Arranging Annual Delivery Program with LNG Seller 2. Scheduling LNG deliveries and managing delays 3. Monitoring and responding to upset events such as storms 4. Managing LNG inventory in light of delivery schedules 5. Managing the provision of port services for LNG deliveries 6. Receiving pipeline nominations and interfacing with the Infrastructure Provider 7. Producing inventory and delivery reports to facilitate customer billing 8. Creating and maintaining a secure website for customer information 9. Negotiating and arranging for new customers, infrastructure and LNG supplies

LNG Seller

Jamalco

New 360 MW IPP

JEP

Infrastructure Provider

LNG Sales

Payment

Gas SalesPayment

LNG Buyer/ Jamaica Gas Trust Co.

Payment Regas Services

28

As set out in the RFP, JGT will provide liquid credit in the form of cash collateral or stand-by letters of credit in an aggregate amount of up to USD 100 million to support its contractual obligations under the LNG SPA. JGT will also put in place liquid credit to support its obligations under the TUA with the Infrastructure Provider. Formal launch of the JGT will be at the time of the second phase of the RFP.

7.2. THE LNG SPA

A synopsis of the LNG Sale & Purchase Agreement is provided below for illustrative purposes only. Bidders are provided with the draft agreement as part of the RFP package.

LNG Sale & Purchase Agreement (SPA) – Summary Term Sheet Seller: [•] (“Seller”) Buyer: Jamaican Gas Trust Company (“Buyer”) Agreement: Seller agrees to sell and deliver, and Buyer agrees to take and pay for, or pay for if made

available and not taken, LNG upon the terms and conditions of the LNG SPA. Term: [•] starting on the date of first commercial delivery, subject to: contract extension or

early termination. Annual Contract Quantity (“ACQ”):

During each Contract Year during the term of the contract, the annual contract quantity (ACQ) will be [•] million MMBTU.

ACQ Review Buyer shall have the right to request a review of the ACQ following Offtaker

Termination Event. Buyer and Seller to use reasonable endeavors to agree on changes to the ACQ. If no agreement has been reached within 60 days, Buyer shall have the right to have the ACQ Review determined by an Expert panel.

Annual Minimum Quantity (“AMQ”):

Buyer to purchase, receive and pay for, or pay for if not taken the AMQ. In determining the AMQ for any Contract Year, the ACQ shall be adjusted to take into consideration, inter alia: • LNG not taken due to FM event • Off-spec LNG not taken • LNG not taken due to late cargo arrival • LNG not made available by Seller for any reason • LNG not taken due to Buyer’s Major Overhaul or operational constraints at the

Receiving Terminal • Carry forward LNG designated for non-delivery by Buyer • Any Downward Quantity Tolerance quantity

AMQ shall be adjusted to take into consideration the following additions, inter alia:

29

• Excess quantity offered by Seller and taken by Buyer

Downward Quantity Tolerance (“DQT”)

Buyer shall have the right to reduce AMQ for any Contract Year by a quantity equal to [1 Full Cargo Lot]

Seller Liquidated Damages:

Seller shall pay to Buyer 25% of the cost that the Buyer would have incurred for non-delivery, unless due to Willful Misconduct, in which case Seller shall pay 35%.

Payment Payment for LNG delivered each month to be made by the later of (i) 10 days following

receipt of Seller’s invoice, and (ii) the 25th day of the following month. Additional details of invoicing and payment timing to be specified in LNG SPA.

Title, Risk, and Delivery Point

Title to, property in and risk in will pass from Seller to Buyer at the point where the outlet flanges of the Vessel unloading lines connect to the inlet flanges of the unloading lines of the Receiving Facility.

Quality: Gross Calorific Value: Minimum: 1020 Btu/scf, Maximum: 1120 Btu/scf

Off Spec LNG provisions to be included in the SPA. LNG Quality Specifications contained in the Appendix of the LNG SPA

Security: Buyer shall provide Seller with security in form and substance acceptable to Seller in

support of Buyer’s financial obligations under this agreement. Seller shall provide Buyer with security in form and substance acceptable to Buyer in support of Seller’s financial obligations under this agreement.

Other Key Terms:

• Governing Law : English Law • Dispute Resolution: LCIA (London place of arbitration)

Attachment 02 - Basis of Design

GOVERNMENT OF JAMAICA: OFFICE OF THE CABINET

Jamaica LNG Project Basis of Design

402010-00260 – 00-GE-BOD-0001

26 August 2011

GOVERNMENT OF JAMAICA: OFFICE OF THE CABINET JAMAICA LNG PROJECT BASIS OF DESIGN

Page i

CONTENTS

1 INTRODUCTION ................................................................................................................ 1

1.1 Background ......................................................................................................................... 1

1.2 Purpose ............................................................................................................................... 1

1.3 Abbreviations ...................................................................................................................... 1

1.4 Definitions ........................................................................................................................... 4

1.5 Units .................................................................................................................................... 4

1.6 Conversion Factor............................................................................................................... 6

2 GENERAL INFORMATION ................................................................................................ 7

2.1 Scope .................................................................................................................................. 7

2.2 Base Design Case .............................................................................................................. 7

2.3 Definition of Equipment/Package Battery Limits ................................................................. 7

2.3.1 SRT ........................................................................................................................ 7

2.3.2 Pipeline .................................................................................................................. 7

2.3.3 ORF ........................................................................................................................ 7

2.4 Schedule ............................................................................................................................. 8

2.5 Project Execution ................................................................................................................ 8

2.6 Health, Safety, Environment and Community ..................................................................... 8

2.7 Classification and Regulatory Requirements ...................................................................... 8

2.8 Insurer ................................................................................................................................. 8

2.9 Reliability/Availability .......................................................................................................... 8

2.10 Gas Export Capacity ...................................................................................................... 9

2.10.1 Gas Flow Rate ....................................................................................................... 9

2.10.2 Gas Pressure and Temperature .......................................................................... 10

3 LOCATION DATA ............................................................................................................. 11

3.1 Portland Bight Protected Area .......................................................................................... 11

3.2 Site Coordinates ............................................................................................................... 11

3.3 Pipeline Shore Crossing and Onshore Receiving Facility Location ................................. 12

3.4 Reference Coordinates ..................................................................................................... 12


Page ii

4 EMISSIONS DATA ........................................................................................................... 14

4.1 Discharge to Air ................................................................................................................ 14

4.2 Discharge to Water ........................................................................................................... 14

4.3 Discharge to Land ............................................................................................................. 14

5 SOIL AND GEOLOGICAL DATA ...................................................................................... 15

5.1 General ............................................................................................................................. 15

5.2 Onshore Soil Properties .................................................................................................... 15

5.3 Offshore Soil Properties .................................................................................................... 16

5.4 Seabed Conditions............................................................................................................ 17

5.5 Seismicity .......................................................................................................................... 17

5.6 Earthquake Spectra .......................................................................................................... 20

6 VESSEL PARTICULARS .................................................................................................. 21

6.1 FSRU Characteristics ....................................................................................................... 21

6.2 Typical LNGC Characteristics ........................................................................................... 21

6.3 Tugs .................................................................................................................................. 22

7 MARINE OPERATIONS ................................................................................................... 23

7.1 Turning Basin and Approach Channel .............................................................................. 23

7.2 Design Wind Speeds for LNGC Operations ..................................................................... 24

7.3 Underkeel Clearance ........................................................................................................ 24

7.4 Navigational Aids .............................................................................................................. 24

7.5 Security and Safety Exclusion Zones ............................................................................... 25

7.6 Jetty Procedures ............................................................................................................... 25

8 METOCEAN DATA ........................................................................................................... 27

8.1 General ............................................................................................................................. 27

8.2 Water Depth ...................................................................................................................... 27

8.3 Design Metocean Conditions ............................................................................................ 28

8.4 Hurricanes ......................................................................................................................... 29

8.5 Current Profile ................................................................................................................... 31

8.6 Winds ................................................................................................................................ 32

8.7 Tide Conditions ................................................................................................................. 34


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8.8 Storm Surge ...................................................................................................................... 35

8.9 Squalls .............................................................................................................................. 35

8.10 Marine Growth .............................................................................................................. 35

8.11 Seawater Temperature ................................................................................................. 36

8.12 Air Temperature ........................................................................................................... 36

8.13 Rainfall.......................................................................................................................... 37

8.14 Tsunami Potential ......................................................................................................... 38

8.15 Seawater Properties ..................................................................................................... 38

8.16 Splash Zone Elevation ................................................................................................. 38

9 LNG AND GAS SPECIFICATION/COMPOSITION .......................................................... 39

10 SRT ................................................................................................................................... 40

10.1 General ......................................................................................................................... 40

10.2 Storage ......................................................................................................................... 40

10.3 Flag State ..................................................................................................................... 40

10.4 Classification ................................................................................................................ 40

10.5 Design Life ................................................................................................................... 41

10.6 Design Conditions ........................................................................................................ 41

10.7 Fire Safety and Hazards Control .................................................................................. 41

10.7.1 Primary Protection System .................................................................................. 41

10.7.2 Secondary Protection Systems ............................................................................ 42

10.8 Escape, Muster, Evacuation and Rescue .................................................................... 42

10.9 Personal Safety and Live Savings Appliances ............................................................. 42

10.10 Future Expansion ......................................................................................................... 43

10.11 Design Loads and Excursions ...................................................................................... 43

10.11.1 Mooring Analysis .................................................................................................. 43

10.11.2 Design Loads ....................................................................................................... 43

10.11.3 Fender Loads ....................................................................................................... 43

10.11.4 Trim ...................................................................................................................... 43

10.12 Emergency Shutdown Valves ...................................................................................... 44

10.13 Remote Telemetry System ........................................................................................... 44


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10.14 Power Generation System ........................................................................................... 44

10.15 Cargo Tank Operations ................................................................................................ 44

10.16 Ballast System .............................................................................................................. 45

10.17 Accommodation ............................................................................................................ 45

10.18 Noise and Vibration Levels........................................................................................... 45

10.19 Corrosion Protection ..................................................................................................... 46

10.20 Boil-off Gas ................................................................................................................... 46

10.21 Overpressure Protection .............................................................................................. 47

11 JETTY ............................................................................................................................... 48

11.1 Mooring Equipment ...................................................................................................... 48

11.2 Loading Arms ............................................................................................................... 48

12 SUBSEA EXPORT PIPELINE .......................................................................................... 49

12.1 Pipeline Throughput Capacity ...................................................................................... 49

12.2 Design Life ................................................................................................................... 49

12.3 Pipeline Route Selection .............................................................................................. 49

12.4 Shore Approach Design ............................................................................................... 49

12.5 End Expansion and Thermal Offset Design ................................................................. 50

12.6 Fluid Categorization and Safety Classes ..................................................................... 50

12.7 Offshore Pipe Wall Thickness Selection ...................................................................... 50

12.8 Pipeline On-Bottom Stability ........................................................................................ 51

12.9 Concrete Coating ......................................................................................................... 51

12.10 Hydrodynamic Coefficients........................................................................................... 51

12.11 Pipeline External Anti-Corrosion Protection ................................................................. 51

12.11.1 External Anti-Corrosion Coating .......................................................................... 51

12.11.2 Cathodic Protection .............................................................................................. 52

12.12 Pipeline Inspection Requirements ................................................................................ 52

12.13 Pipeline Commissioning ............................................................................................... 52

13 ONSHORE RECEIVING FACILITIES ............................................................................... 53

13.1 Overview ...................................................................................................................... 53

13.2 Noise ............................................................................................................................ 53


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13.3 Pig Receiver ................................................................................................................. 53

13.4 Filter .............................................................................................................................. 54

13.5 Pressure Letdown Station ............................................................................................ 55

13.6 Fiscal Metering Skids ................................................................................................... 55

13.7 Indirect Fired Water Bath Heater ................................................................................. 56

13.8 Cold Vent ...................................................................................................................... 56

13.9 Utility Systems .............................................................................................................. 57

13.9.1 Instrument Air ....................................................................................................... 57

13.9.2 Utility Water .......................................................................................................... 58

13.9.3 Firewater System ................................................................................................. 58

13.9.4 Electrical Power System ...................................................................................... 58

13.9.5 Nitrogen ................................................................................................................ 59

13.9.6 SCADA ................................................................................................................. 59

14 REFERENCES ................................................................................................................. 60

Appendices

APPENDIX 1 CODES AND STANDARDS

APPENDIX 2 METEOROLOGICAL DATA

APPENDIX 3 FIELD LAYOUT DRAWING

APPENDIX 4 PIPELINE ROUTE

APPENDIX 5 PRELIMINARY MOORING ANALYSIS

APPENDIX 6 NEAR-SHORE STORM MODELLING

Further Work Requirements

a) Preliminary metocean data

b) Geotechnical report

c) Bathymetric data (around the mooring site and along the pipeline route)

d) Preliminary mooring analysis

e) Flow assurance/pipeline sizing study


Page vi

To be Advised by CONTRACTOR 1. NG arrival specifications to be confirmed

2. Mooring system and design loads to be confirmed

3. Facility availability requirements to be confirmed

4. Mooring location to be confirmed

5. NG end-users to be finalised subject to Gas Sales Agreement (GSA)

6. Cold vent design to be confirmed subject to ORF location

7. Jamaican regulatory/permitting requirements to be confirmed

8. Contracting strategy to be confirmed

9. All site specific meteorological data

10. Power generation for black start-up after hurricane

11. Ramp-up and ramp-down rates

12. FSRU characteristics

13. QFlex vessel characteristics

GOVERNMENT OF JAMAICA

JAMAICA LNG PROJECT BASIS OF DESIGN

Page 1

1 INTRODUCTION

1.1 Background

In order to improve its international competitiveness and reduce its dependence on imported

petroleum, the Government of Jamaica (GOJ) has implemented a strategy to diversify its energy

supply. The strategy aims at introducing imported natural gas into Jamaica‘s energy supply mix to

obtain security of supplies and achieve long-term stability in energy prices and environmental

sustainability in energy provision.

Under this strategy, it is proposed to import liquefied natural gas (LNG) to Jamaica under long-term

contractual arrangements and re-gasify it to initially meet the needs of power generation and

bauxite/alumina production. The initial estimate of demand in these sectors is equivalent to about

0.8-million tonnes of LNG per year, with the expansion of the bauxite/alumina sector and construction

of new IPPs likely to raise the base LNG demand to around 2.5-million tonnes per year. It is expected

that the importation of LNG will help to spur additional industrial and commercial growth that would

benefit from the availability of natural gas and lower energy prices.

To facilitate this initiative, the GOJ is seeking to develop a Liquefied Natural Gas (LNG) Storage and

Regasification Terminal (SRT) and natural gas export system in Jamaica (‗the PROJECT‘) on a Build-

Own-Operate-Transfer (BOOT) basis.

1.2 Purpose

The purpose of this document is to provide sufficient design data for the bid proposal. The

CONTRACTOR is required to collect, verify and validate all data necessary for detailed design.

1.3 Abbreviations

The abbreviations summarised in Table 1.1 are used throughout this report.

Table 1.1: Abbreviations

Abbreviation Definition

API American Petroleum Institute

ASME American Society of Mechanical Engineers

BOD Basis of Design

BOG Boil Off Gas

Cd Drag Coefficient

Cl Lift Coefficient



Page 2


Cm Inertia Coefficient

DCQ Daily Contract Quantity

DG Diesel Generator

DNV Det Norske Veritas

FBE Fusion Bonded Epoxy

FSRU Floating Storage Regasification Unit

GOJ Government of Jamaica: Office of the Cabinet

HAT High Astronomical Tide

HDD Horizontal Directional Drilling

Hs Significant wave height

IMO International Maritime Organisation

LAT Low Astronomical Tide

LEL Lower Explosive Limit

LNG Liquefied Natural Gas

LNGC Liquefied Natural Gas Carrier

LOA Length Overall

LWS Low Water at Spring Tide

mmscf Millions Standard Cubic Feet

mmscfd Millions Standard Cubic Feet per Day

mmtpa Millions Tonne Per Annum

NEPA National Environment & Planning Agency



Page 3


NFPA National Fire Protection Association

NMIA Norman Manley International Airport

NRCA Natural resources Conservation Authority

OCIMF Oil Companies International Marine Forum

ORF Onshore Receiving Facility

PCS Process Control System

PG Power Grid

PLEM Pipeline End Manifold

PM Particulate Matter

POB Persons on Board

psig Pounds per square inch (gauge)

PSV Pressure Safety Valve

RAM Reliability, Availability & Maintainability

SCADA Supervisory Control and Data Acquisition

SRT Storage and Regasification Terminal

SSHS Saffir Simpson Hurricane Scale

SWIL Smith Warner International Ltd

SWL Safe Working Load

TBABC To Be Advised By CONTRACTOR, subject to approval by COMPANY

TBC To Be Confirmed

VOC Volatile Organic Compounds



Page 4


VTS Vessel Traffic System

WOW Wait On Weather

WP WorleyParsons

1.4 Definitions

The definitions summarised in Table 1.2 are used throughout this report.

Table 1.2: Definitions

Description Definition

COMPANY The Government of Jamaica (GOJ), acting on behalf of the Jamaica Gas Trust

CONTRACTOR Reference to nominated SRT & Gas Export System Contractor(s)

PROJECT Jamaica LNG SRT Project

The words ―will‖, ―may‖, ―should‖, ―shall‖ and ―must‖ have specific meaning as follows:-

―Will‖ is used normally in connection with an action by the COMPANY rather than by CONTRACTOR.

―May‖ is used where alternatives are equally acceptable.

―Should‖ is used where a provision is preferred.

―Shall‖ is used where a provision is mandatory.

1.5 Units

The project shall use the metric ISO system of units for all project documentation, except that to

ensure that there is no misinterpretation, gas flow rates and pressures shall also be given in US units,

as is common in the oil and gas industry. Table 1.3 provides a list of the units used by the Project.

Table 1.3: Units

Parameter Unit

Actual flow rate m³/h

Area m²

Density kg/m³

Dimension mm or m



Page 5

Parameter Unit

Dynamic viscosity cP

Fouling factor m².°C/kW

Gas volume flow rate (standard conditions) S.m³/h

Gravity g = 9.81-m/s²

Head m

Heat kW

Heat rate kW/m².°C

Heat transfer coefficient kW/m².°C

Heating value (gas) MJ/sm³

Heating value (liquid) MJ/kg

Interfacial surface tension mN/m

Kinematic viscosity cSt

Knot kt

Latent heat kJ/kg

Liquid head m

Liquid volume flow rate m³/h

Mass flow rate kg/h

Material strength MPa

Noise dB(A)

Pipe diameter mm

Pipeline length m

Power kW

Pressure (absolute) kPa

Pressure (gauge) kPag

Pressure drop/length kPa/m

Radiation W/m²



Page 6

Parameter Unit

Solid/sediment concentration g/l

Specific heat kJ/kg.°C

Rotational speed rpm

Static pressure mm water

Stress kPa

Temperature °C

Thermal conductivity W/m.°C

Time h, s

Velocity m/s

Volume m³

Weight tonnes (metric)

1.6 Conversion Factor

Table 1.4 provides an indicative conversion factor NG to LNG.

Table 1.4: Unit Conversion

Convert To Multiply by

Regasified NG (mmscfd) LNG (mmtpa) 0.0076



Page 7

2 GENERAL INFORMATION

2.1 Scope

This document presents the Basis of Design (BOD) for the Jamaica LNG project. The project will

develop infrastructure for LNG receipt, storage, regasification and reticulation to its customers up to

and including Onshore Receiving Facilities where required. The scope of this document incorporates

the Storage and Regasification Terminal (SRT), mooring system, subsea pipeline and Onshore

Receiving Facility (ORF).

The data contained is grouped into three main categories:

a) Basic project data, i.e. the data which are pre-requisites, e.g. location, codes/standards, met-

ocean, etc;

b) Project fundamentals, i.e. selected parameters on which the project will be based, such as

regasification rates, design life, etc;

c) Design principles.

It is noted that this BOD is intended to be a live document, which will be updated during the project

life as additional data becomes available.

2.2 Base Design Case

The base design case for the SRT is an FSRU moored at a near-shore, dual-berth jetty. The

CONTRACTOR may choose to consider alternative mooring arrangement/terminal designs subject to

compliance with design requirements detailed in this document and positive cost-benefit analysis

relative to the base option. In the event an alternative mooring arrangement is proposed, the

CONTRACTOR must demonstrate that the LNG supplier ‗super majors‘, particularly those active in

the region these being BP, BG and Shell, will submit to mooring their LNGC vessels at the facility.

2.3 Definition of Equipment/Package Battery Limits

2.3.1 SRT

The overall battery limits of the SRT shall extend from the inlet flanges of the loading arms to the

outlet flange on the Pipeline End Manifold (PLEM) downstream of the SRT.

2.3.2 Pipeline

The gas export pipelines start at the PLEM and terminate at the inlet flange of the ORF facilities

onshore.

2.3.3 ORF

Onshore Receiving Facilities shall comprise pig receiving, preheating and pressure letdown

equipment (as required) along with custody transfer metering. Specific ORF location details shall be

confirmed by the CONTRACTOR during detailed engineering.



Page 8

2.4 Schedule

The project‘s customers will require first gas supply by Q1, 2014.

2.5 Project Execution

Refer to RFP documents [7] for details of project execution requirements.

2.6 Health, Safety, Environment and Community

An Environmental Analysis (EIA) was prepared by SWIL in January, 2007 [10]. The design shall be

undertaken in accordance with the environmental limits contained in that report, which shall be made

available to bidders. A new EIA shall be required.

2.7 Classification and Regulatory Requirements

The project facilities should be designed, constructed, installed and surveyed in compliance with the

codes and standards listed in Appendix 1 Codes and Standards and/or the appropriate equipment

specification.

In the event of an inconsistency, conflict or discrepancy between any of the Standards, Specifications

and Regulatory, the most stringent and safest requirement applicable to the project shall prevail to the

extent of the inconsistency, conflict or discrepancy. Any inconsistencies critical to the design shall be

brought to the attention of the COMPANY, or its agents, for resolution.

2.8 Insurer

The insurer may have specific requirements beyond the statutory or nominated standard

requirements. Additional requirements can be related to fire detection and protection systems. Some

insurers have more stringent requirements than others; this may increase costs. If the insurer is not

known, the installation should be designed to National Fire Protection Association (NFPA)

requirements, specifically the latest edition of NFPA 59A, and local requirements.

2.9 Reliability/Availability

The berthing facilities shall provide for industry standard hard unloading arms, expansion drums,

purging facility and lifting equipment, and independent power supply etc. The mooring facilities

including breasting and mooring dolphins shall be of a design and placement consistent with best

industry practices. The target overall terminal availability shall be 99.5% per annum excluding

weather events as described in subsequent paragraphs. The terminal shall be designed with a

sparing philosophy that can accommodate the target availability (this shall be demonstrated by a

terminal RAM analysis conducted by the Contractor). LNG vessels shall not be required or permitted

to perform vessel-to-vessel transfers through flexible hoses.

The facility shall be able to provide a constant flow of natural gas all year round at base plate capacity

of the regasification facility, with the exception that during times of hurricane that come within 200-nm

of the facility the natural gas flow is interrupted. During this time the FSRU or FSU shall be able to

disconnect. The FSRU or FSU shall be able to re-connect and re-gasify at boiler plate capacity within

48-hours after the hurricane event. The interruption of natural gas supply during hurricanes shall be

kept at a minimum and shall not exceed a total duration of 4-days per event. Excluding hurricane



Page 9

events the terminal availability i.e. constant natural gas flow shall be better than 99.5% per annum

over the twenty (20) year design life.

The target Wait on Weather (WOW) figure shall be defined by logistics/offloading studies; LNGC lay-

days and WOW for offloading shall on average be less than [TBABC 3] days per offloading.

The order of design emphasis for major reliability/availability factors shall be as follows:

a) Simple process (facilities);

b) Flexible process;

c) Proven, reliable equipment and components: taking advantage of experience of other projects.

Selection shall be based on whole lifecycle costing;

d) Availability of technical/support personnel and overhaul facilities in the region to minimise

downtime;

e) Simple, non-dedicated utility facilities;

f) Provision of installed standby equipment where economically justified: based on whole lifecycle

costing;

g) Automation.

Improvements in availability shall be assisted by good design practice in terms of ensuring:

a) Access and lifting provisions for maintenance operations, to minimise repair times;

b) Operating flexibility in terms of being able to continue production whilst equipment has failed or

is degraded awaiting repair (e.g. by provision of bypasses etc.).

2.10 Gas Export Capacity

2.10.1 Gas Flow Rate

At start-up end-users of sales gas supplied by the Jamaica LNG Project will come from the power and

bauxite industries. Power industry users, located in the vicinity of Old Harbour, will comprise both

existing, liquid fuel-driven facilities converted for gas fuel consumption (Jamaica Energy Partners,

JEP) and new-build plants (Independent Power Projects, IPP). The bauxite industry user, Jamalco,

has an existing facility in the vicinity of Rocky Point and is actively pursuing natural gas supply for use

in its operations.

The IPP facility will be developed via an initial phase (Q1, 2014) and subsequent expansion phase

(Q4, 2016), henceforth described as Phases 1 & 2 respectively. The Jamaica LNG Project is to be

designed for the maximum capacity shown in Table 2.1 below. The initial volumes at start-up in 2014

are shown as Phase 1. Phase 1 & 2 sales gas shall be supplied to the ORF at Old Harbour via

subsea pipeline. The CONTRACTOR shall advise the turn-down rate indicatively this shall be 30% of

the normal gas sales rate. Turn-down rate to be approved by COMPANY.

Given the local natural gas market is expected to expand significantly once the supply infrastructure is

available, the regasification system design should be such that it enables expansion to meet

estimated future demand requirements, in particular with regard to provisions of tie-ins and

contingency plot area.



Page 10

The gas supply rate requirements are presented in Table 2.1.

Table 2.1: Gas Supply Requirements [4]

Phase 1 (Q1, 2014) 2 (Q4, 2016) Future

Normal Gas to Sales

Rate

0.83-mmtpa

110-mmscfd

1.10-mmtpa

150-mmscfd

2.50-mmtpa

320-mmscfd

Peak Gas to Sales

Rate

1.10-mmtpa

150-mmscfd

1.30-mmtpa

170-mmscfd

3.20-mmtpa

420-mmscfd

The Old Harbour ORF ramp-up and ramp-down from minimum to peak production rates shall follow

the diurnal power consumption pattern of the Kingston region. Rate increases from minimum to peak

and vice versa shall occur over 8-hour periods. Further, the pipeline shall provide for a minimum 1-

hour line packing at peak capacity.

The following ramp-up and ramp-down rates shall apply:

a) Ramp-up ............................................. [TBABC 11]

b) Ramp-down ......................................... [TBABC 11]

2.10.2 Gas Pressure and Temperature

Vaporised LNG shall be delivered to the inlet the gas export pipeline under pressure and temperature

control.

The inlet operating pressure of the gas export pipeline is dictated by the end-user supply pressure

requirements. The desired operating pressure requirement at the delivery point into the pipeline is

between 40 and 95-barg. Given the pressure required at the pipeline inlet is dependent on the gas

export rate, it is advantageous to provide some design margin in the regasification system and export

pipeline pressure rating to enable future operation at higher pressures, thereby enabling supply to

additional users. To this end, the regasification system equipment shall be rated for gas delivery

pressures to the pipeline of up to 100-barg.

The pipeline inlet temperature is required to be greater than 0°C under all operating conditions to

ensure a minimum arrival temperature of 10°C at the ORF.

Pressure and temperature conditions shall be confirmed by the CONTRACTOR subject to finalisation

of the pipeline route during detailed engineering.



Page 11

3 LOCATION DATA

3.1 Portland Bight Protected Area

The proposed project falls within the Portland Bight protected area. The area covers approximately

1,876-km² of terrestrial and marine environment (Figure 3.1) and is co-managed by the Caribbean

Coastal Area Management Foundation (CCAM) and the National Environment and Planning Agency

(NEPA). CCAM is a registered non-governmental organization (NGO) in Jamaica which is active

within the area.

Figure 3.1: Portland Bight Protected Area

3.2 Site Coordinates

The coordinates of key project sites are:

a) SRT ..................................................... 77°06' W, 17°51' N [TBABC 4]

b) ORF at Old Harbour ............................ 77°06' W, 17°54' N [TBABC 4]

c) The coordinate along the pipeline route are available in Appendix 4 Pipeline Route [TBABC 4]

The SRT shall be located in the Portland Bight, in the vicinity of Old Harbour. The final location of the

SRT is to be confirmed by the CONTRACTOR subject to mooring analysis and availability validation

during detailed engineering [TBABC 4].



Page 12

Preliminary data for selection of the SRT location such as LNGC principle dimensions, dredging

requirements, marine, environmental and metocean data are presented in sections 6 to 8.

3.3 Pipeline Shore Crossing and Onshore Receiving Facility Location

It is proposed that the Phase 1 subsea pipeline shall make landfall at Old Harbour, Figure 3.2. The

specific landfall and ORF locations shall be confirmed by the CONTRACTOR during detailed

engineering. Onshore pipeline distribution network(s) are not considered in the scope of this design

basis.

The ORF sites shall be of sufficient area to accommodate the equipment specified in section 13.

Unauthorised access to the ORF sites shall be a prevented by way of suitable fencing. The pipeline

shore crossing is described in section 12.4.

Figure 3.2: ORF Locations at Project Site Location Map

3.4 Reference Coordinates

The following geodetic parameters shall be applied throughout the project. All survey works

performed, all final charts produced and positions quoted in this report are referred to WGS 84

spheroid and datum [TBABC 4].



Page 13

Table 3.1: Satellite Datum and Spheroid WGS 84 Reference Coordinates [TBABC 4]

Location SRT Old Harbour

Datum

Semi major axis, a (m)

Semi minor axis, b (m)

Inverse flattening (1/f)

Eccentricity squared

Projection

Zone

Latitude of origin

Longitude of origin

Scale factor on C.M.

False easting

False northing



Page 14

4 EMISSIONS DATA

4.1 Discharge to Air

The SRT shall comply with NEPA standards for discharge to air [16], which can be found here:

http://www.nepa.gov.jm/regulations/air-ambient-guideline-2006.pdf; NRCA (Air Quality) regulations;

and IMO Tier 3 regulations.

4.2 Discharge to Water

Use of seawater and seawater temperature change should be minimised. The maximum seawater

temperature differential is maximum 5°C above ambient temperature at the edge of the designated

maxing zone, 100 m from the point of discharge, for sea water-based regasification technologies.

4.3 Discharge to Land

The following discharges shall be collected and transported to shore for disposal:

a) Contaminated slops water;

b) Solid waste;

c) Waste oils and lubricants;

d) All waste containing hazardous goods in accordance with IMO regulations;

e) Compliance with MARPOL regulations;

f) Ballast water management:

LNGC‘s are required to exchange ballast water 25-nm offshore or outside the Portland Bight

protected area whichever is greatest.

http://www.nepa.gov.jm/regulations/air-ambient-guideline-2006.pdf



Page 15

5 SOIL AND GEOLOGICAL DATA

5.1 General

No geophysical or geotechnical survey has been conducted for this project; however there is data

available from:

a) Previous proposals and projects in the proposed SRT location , in particular the EIA conducted

for the JEP Power Barge at Old Harbour in 2005 [1], and the Geotechnical Investigation [2] and

EIA [14] carried out for the proposed LNG Import Plant at Port Esquivel in 2006, together with

an EIA for a temporary facility at Rocky Point in 2007 [3].

b) Studies of the general region. Heinemann and Mantel [9] gives an overview of the geology of

the Island with references to the Portland Bight area, there are various references to the

seismicity of the region and these are discussed in section 5.5.

The following sections summarise what data is available, and gives links to references for the source

of that information.

5.2 Onshore Soil Properties

From [9] the area of interest in Portland Bight is part of the Coastal Plain Region in Jamaica (Figure

5.1). Situated in the southern part of the island, this region is shielded from the north-easterly rain-

bearing monsoon winds. It covers the dry, flat to gently undulating coastal plans formed by lacustrine,

marine and river sediments. The major soils of this region are of alluvial origin and have considerable

potential for agriculture. They include cracking clays (Vertisols) and stratified loamy soils with a dark

humic surface horizon (Phaeozems). Saline soils occur near the coast.

This data should be validated by the CONTRACTOR via geotechnical study during detailed

engineering. According to the 2006 LNG Import Plant FEED documents, [2] & [14], the geology of the

area adjacent to the site consists of unconsolidated sands and sandy clays and carbonaceous sandy

clays and clays of Holocene age (last 12,000-years). The present beach sediments consist mainly of

noncarbonated grains.

The project site is located in Portland Bight in south central Jamaica adjacent to the St. Catherine

coastal plain. The coastal plains are comprised of quaternary alluviums of generally moderate

permeability. Coefficient of permeability is expected to be low to very low and should range from 10.5

to 10.1-m/s. The alluvial plain results largely from the build-up of essentially non-limestone deposits

derived by rivers from the largely volcanic rocks of the island‘s interior, and consist of coarse gravel,

sand and clay [3]. Well log data for alluvium in the Dorothy‘s plain indicate that clay, and clay with

variations of sand and gravel are dominant in the upper 23-m [3]. The alluvium varies in thickness

from a few feet near contact with the surrounding limestone hills to several hundred feet on the

central plain area [3]. Three onshore boreholes were made in the 2006 geotechnical appraisal [2]

There is data from some shallow Boreholes (6 to 24-m in depth ) – both onshore and offshore, at

Rocky Point made in 2007 [3].



Page 16

Figure 5.1: Major Physical Regions of Jamaica [9]

5.3 Offshore Soil Properties

The friction coefficients to be considered in the pipeline design are presented in Table 5.1.

Table 5.1: Soil Properties [TBABC 4]

Description Unit Properties

Soil type

Submerged density (wet) kg/m³

Undrained shear strength kPa

Axial friction factor

Longitudinal friction factor

Seabed roughness m

It is noted that there are no marine soil borings available at the project site. The marine geotechnical

investigation work for the 2006 proposed development was cancelled due to the inability of the

geotechnical subcontractor to perform the work within the required time schedule. Three onshore soil

borings at the project site were provided and used for the Mustang marine facilities FEED work [3].

There are also shallow soil borings both onshore and offshore at Rocky Point, but these are

considered to be of limited use to the project. Offshore soil property data should be validated by the

CONTRACTOR via geotechnical study during detailed engineering.



Page 17

5.4 Seabed Conditions

Smith Warner International [14] indicates that the seabed in the project area is comprised of soft mud

and shells. However, it was reported that a recent survey carried out on behalf of WINDALCO

indicated the possibility of hard rock at the end of the approach channel close to the Port Esquivel

facility. This has not yet been confirmed with actual soil data.

5.5 Seismicity

Jamaica lies in the seismically active northern plate boundary zone of the Caribbean Plate and is

therefore susceptible to earthquakes. The island has experienced destructive earthquakes generated

offshore and on land associated with active geological features.

An earthquake density map of the Caribbean (Figure 5.2) reproduced from the USGS website shows

that Jamaica is in a seismically active zone. The Caribbean Disaster Mitigation Project implemented

by the Organization of American States provides 10% probability of exceedance data for a 50 year

return period for both horizontal ground velocity and expected Mercalli Intensity for the proposed site

on their website [10].

More specifically for the site, data cited in [14] and reproduced from that document below, indicates

that, on average Jamaica experiences less than 1 earthquake of magnitude 5 and greater every

decade. There is a moderate potential for the site to experience a ―felt earthquake‖ as described

under the modified Mercalli Intensity scale.

A major earthquake (>5 in magnitude) originating elsewhere in Jamaica or even as far away as the

south coast of Cuba could be felt in Jamaica. For example, the Cabo Cruz earthquake of magnitude

6.9 on the Richter scale, which occurred in May 1992, was felt with intensity 4 in Kingston, Jamaica.

The average seismic activity that has occurred in or has been felt by Jamaica between the years of

1899 and 1998 is approximately 4.21 on the Richter scale. Historically there have been at least 13

damaging earthquakes affecting Jamaica, the most recent of which was the January 13, 1993

Kingston earthquake of magnitude 5.4.

Probabilistic analysis of historic seismic activity in Jamaica has been carried out. The seismic hazard

map of Jamaica (refer to Figure 4.3 in [14]) indicates the number of earthquakes with an intensity of

VI that have occurred throughout the island since 1874. The plant site at Port Esquivel lies in an area

of relatively low activity but is still susceptible to damaging ground shaking from earthquakes

intensities of VI on the Mercalli scale. The probability of an intensity VI event has been calculated at

0.71 for the plant site and to a range of 0.71 to 0.99 for the proposed pipeline route. Onshore

facilities are not likely to be susceptible to tsunami conditions based on envisaged elevation/distance

from the coastline.



Page 18

Figure 5.2: Earthquake Density Map of the Caribbean

From [2], evidence of fault movements affecting the White Limestone bedrock (ten million years and

older) in the Old Harbour Bay region is provided by data from water supply wells and geophysical

studies. In other parts of the island, rocks of the Coastal Group (1 to 5 million years old) are faulted.

However, as noted above, faulting affecting more recent unconsolidated or semi-consolidated

sediments may frequently be difficult to identify, and is not evident in the field at Old Harbour Bay.

The intensity of seismic shaking depends largely on the quality and thickness of the unconsolidated or

semi consolidated sediments overlying the bedrock. Willow (less than 50-m) thicknesses transmit

short period motions to best effect. Longer period motions are transmitted best by thicknesses up to

about 100-m (EIA for Power Barge at Old Harbour Bay, 2005).

Thicknesses of semi-consolidated sediments exceeding 100-m, such as is probably the case here,

tend to suppress the periods of engineering interest. Most of the large earthquakes (magnitude 6.0 or

greater) over the past 100-years have occurred offshore, while the smaller seismic events were

generated beneath the mainland. Modelling of the Crawl River-Rio Minho fault system that passes

within 30-km of the project site has a worst case slip rate of 5-mm per year and a best case rate of 1-

mm per year. For the plant site, ground shaking at the site will likely last between 0.5 and 3.0

seconds. Peak ground acceleration of 0.245g with a 10% probability of exceedance in 50-years was

estimated.

The geological faults local to Portland Bight are also given in section 4 of [3]



Page 19

Figure 5.3: Horizontal Ground Acceleration

Figure 5.4: Expected Maximum Mercalli Intensity



Page 20

Figure 5.5: Horizontal Ground Velocity (cm/sec)

5.6 Earthquake Spectra

CONTRACTOR shall use as a minimum a 500-ARI earthquake spectrum for ultimate survival with

minor damage. This shall be based on actual ground accelerations measurements at the SRT, along

the pipeline and at the ORF location.



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6 VESSEL PARTICULARS

6.1 FSRU Characteristics

To be advised by CONTRACTOR, [TBABC 12].

6.2 Typical LNGC Characteristics

Table 6.1 and Table 6.2 list the principal dimensions of a range of LNG carriers. QFlex vessel

characteristics to be advised by CONTRACTOR [TBABC 13]

Table 6.1: LNG Carrier Characteristics [3]



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Table 6.2: Design Parameters for Marine Facilities [3]

6.3 Tugs

Subject to mooring requirements [TBABC 2] and confirmation by vessel manoeuvre simulations

during the detailed engineering phase, the tugs used to assist the LNG carriers are assumed to be

capable of a combined 150-tonne minimum bollard pull. Each tug will require a 40-tonne bollard pull

capacity. These tugs are anticipated to be approximately 39.6-m long and 12.2-m wide with a

minimum draft of about 6.4-m. The minimum required water depth is approximately 7.0-m.

Tug spread requirements shall be confirmed subject to mooring system design during detailed

engineering.



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7 MARINE OPERATIONS

7.1 Turning Basin and Approach Channel

Portland Bight sits in a fairly enclosed bay, protected by reefs to the south and southeast. The shores

are fringed with islets, cays and reefs. Outside of the reefs in the open bay; the water depth varies

between 10-m and 22-m, as shown in Figure 8.1. The main channel has a depth of at least 12.5-m,

lies between Bare Bush Cay and Morris Shoal on the east and Portland reefs on the west.

Fish pots and turtle nets may be met anywhere near the cays and reefs and on the shoals, but they

are not usually laid in the shipping lanes or inside Portland Bight. They are however difficult to see.

Fishermen from Old Harbour Bay, go to sea at night, returning to Harbour with the morning sea-

breeze. Their boats may be met in large numbers in the area.

Attention is drawn at shoal depths, of about 8 to 9-m, off the western side of the leading line, and

southeast of Portland Reefs. Location 17°42‘N, 77°03‘W [5] on the vessel‘s track indicated the patch

of 12.5- m which need to be dredged to guarantee a smooth access for a LNG Q-Flex vessel, a

LNGC of capacity about 210,000-m³ to 216,000-m³. For standard size LNG vessels, with a maximum

draught of 11.4-m, this patch would cause no problem. The water depths along the channel and

around the pier are too shallow to accommodate a fully laden LNGC (including an allowance for under

keel clearance) without further dredging.

An approach channel to the WINDALCO terminal pier has been dredged between the reefs and leads

directly to the Port Esquivel turning basin. The pier is 200-m long and can accommodate vessels up

to 198-m with a maximum draught of 11.0-m. Both the eastern and western sides of the pier can be

accessible. The channel has been dredged and is approximately 2.5-km long and 120-m wide with a

minimum depth of 12.2-m. The turning basin is approximately 450 to 500-m in diameter.

Inside of the reefs and to the east of the channel, the water depth is relatively shallow; 4 to 8-m with

the 2-m and 5-m contours located 200-m and 600-m off the shoreline respectively.

Assuming the largest LNGC entering the facilities is a Q–Flex sized vessel (L = 345-m, B = 54-m, T =

12-m), the LNGC turning basin and the inner approach channel shall need to be dredged to the

dimensions:

a) LNGC turning basin depth .................. 13.2-m, relative to chart datum

b) LNGC turning basin diameter ............. 690-m

c) Inner approach channel depth ............ 13.8-m, relative to chart datum

d) Inner approach channel width ............. 216-m



Page 24

Figure 7.1: Turning Basin and Approach Channel

7.2 Design Wind Speeds for LNGC Operations

Design wind speeds below are 1-minute mean at 10-m elevation, use API RP 2A WSD for other

elevations or gust durations:

a) Manoeuvring wind velocity .................. 20-m/s, during connection

b) Operating wind velocity ....................... 23-m/s, whilst connected

c) Max design wind velocity .................... 40-m/s, parked and locked

7.3 Underkeel Clearance

The limits on under keel clearance in the Portland Bight shall not be less than:

a) Berth pocket ........................................ 0.5-m

b) Inner harbour channels ....................... 1.2-m

c) Swing basin ......................................... 1.2-m

d) Outer port channel .............................. 1.8-m

7.4 Navigational Aids

The following navigational aide shall be established:



Page 25

a) Buoys to mark the width of navigable channels should be placed at suitable intervals.

b) Leading marks or lit beacons, to mark channel centrelines and to facilitate rounding channel

bends, should be appropriately placed.

c) Electronic navigational aids, to support navigation under adverse weather conditions should be

provided.

d) Lit navigational aids should be provided to allow ship movements at night.

7.5 Security and Safety Exclusion Zones

Safety shall be of primary importance in the design of all systems associated with the SRT. For the

purposes of this study the following parameters have been assumed:

a) 500-m ahead, and 200-m abeam and astern of a transiting LNG carrier as it moves along

shipping channels (permission for transiting two-way traffic in appropriate width channels in the

opposite direction to be at the discretion of the Port Authority Chief Harbour Master on a case

by case basis).

b) 250-m safety zone around the load out berth when unoccupied by a carrier or FSRU.

c) 1,000-m public exclusion safety zone around the berth when loading operations are occurring

and when the FSRU is regasifying.

d) 250-m commercial shipping safety zone around the load out berth when loading operations are

occurring.

e) 50-m each side of the cryogenic jetty pipeline.

f) 500-m public safety zone from the SRT to the site perimeter boundary.

g) 250-m clearance zone to other hazardous industry inventory from the LNG processing plant

Notwithstanding the above figures adopted for the purposes of this study, a detailed risk assessment

approach should be adopted with the operating parties/owners, regulators and the port authority

actively participating in that process. Such risk assessments should include all aspects of the facility

including plant and shipping operations.

7.6 Jetty Procedures

a) On shore jetty safety zones should be effectively policed while the ship and/or FSRU is

alongside thus providing control over visitors and vehicles.

b) Offshore safety zones should be effectively policed by a guard boat to limit the approach of

small craft.

c) Passing ships, close to the jetty, should have their speed controlled by the harbour VTS

system.

d) Communications procedures should be well established and tested.

e) Contingency plans should be available in written form.

f) Operating procedures should be available in written form.



Page 26

g) A Port Information/Regulation Booklet should be provided for passing operational advice to the

ship.



Page 27

8 METOCEAN DATA

8.1 General

Jamaica has a maritime climate that is largely controlled by warm equatorial ocean currents creating

a hot and humid climate. For most of the year, the daily wind pattern of Jamaica is dominated by the

north east Trade winds. By day along the south coast the sea breeze combines with the Trades to

give an east-south-easterly wind with an average speed of 18-knots.

Apart from approximately the 1-year of wind data at Old Harbour [14], and a few weeks of local

current data at the Old Harbour [1] and Port Esquivel sites [14], there is no available ambient wind,

wave or current data available for the Portland Bight.

However, the National Meteorological Service at the Norman Manley International Airport (NMIA) has

extensive records, and these have been used by most metocean studies in the area. Portland Bight

is the next major inlet along the coast from, and is located approximately 35-km west southwest of,

the Norman Manley International Airport (NMIA), which also located in an exposed site on the

southern coastline. Therefore it is considered reasonable to base the meteorological data for the

Project on NMIA meteorological data, and the following wind data used is from that source.

In addition, the OAS General Secretariat – Unit for Sustainable Development and Environment has

prepared wind wave and storm surge data based on hurricane data for Kingston and this data is

available on their website [15].

8.2 Water Depth

The water depth in Portland Bight is quite well documented in British Admiralty Charts 257 and 457,

and from a survey carried out as part of [14]. Detailed site specific data at the SRT location is

approximately [TBABC 4] to LAT. Preliminary bathymetric data around the mooring centre and along

the pipeline route is available in BAC 257 and 457. The CONTRACTOR shall supply detailed

bathymetric data for the mooring location and pipeline route(s) during detailed engineering.



Page 28

Figure 8.1: Offshore and Near Shore Bathymetry

8.3 Design Metocean Conditions

The design conditions to be used for the mooring system of the SRT, on bottom stability of the

pipeline, and design of the ORF are shown below. No site specific metocean study inside Portland

Bight has been carried out for this project; although some 100-year return period wave and storm

surge data is available from [14].

Table 8.1: 1-YRP Meteorological Conditions [TBABC 9]

Units All N NE E SE S SW W NM

Hmax m

Hs m

Tp sec

U10 m/s

Vc m/s



Page 29



Hmax m

Hs m

Tp sec

U10 m/s

Vc m/s



Hmax m

Hs m

Tp sec

U10 m/s

Vc m/s



Hmax m

Hs m

Tp sec

U10 m/s

Vc m/s

8.4 Hurricanes

Hurricane tracks in the North Atlantic basin can more or less be described as a parabolic sweep.

They form between latitudes 5° and 25° north of the equator. Those formed at the lower latitudes are

usually pushed on a westerly track by the north-east Trade winds whereas those of the higher

latitudes track more to the north and north-west [14].

Offshore hurricane storm wave data and transformed shallow-water wave data is sourced from ―Final

Draft Report: Environmental Impact Assessment of the Proposed 49.6 Megawatt Power Barge at Old



Page 30

Harbour Bay in the Parish of St. Catherine, Jamaica‖ [1] by CL Environmental, dated April, 2005. The

Power Barge Project site is about 2-miles away to the northeast of the proposed LNG terminal site.

Table 8.5 provides the extreme wave statistics offshore approaching Portland Bight from the east,

southeast, south, and south-westerly sectors to determine the return values of hurricane significant

wave heights(Hs), peak wave period (Tp) and wind speeds (Vm) in deep water (water depths greater

than approximately 200-m). It shows a summary of deep water wave conditions for various return

periods.

The waves coming from the east had the greatest wave heights for all return periods. It must be

noted that the values for the wave heights shown in Table 8.5 represent conditions in deep water,

before the effects of wave refraction, shoaling and wave breaking occur in near shore areas.

Standard coastal design practice for the Caribbean suggests that the 1-in-100 year return period

wave condition be used for the design of coastal structures that have an extended design life.

Refer also to Appendix 6 Near-shore Storm Modelling for SWAN study extreme wave data [14].

Table 8.5: Return Periods of Hurricane Wave Analysis, Jamaica

Table 8.6 depicts the number of storm events within a 300-km radius that have affected the project

site at Port Esquivel. It is recognized that a total of 96 storm events within this area since year 1900.

The breakdown of the number of storm events falling within each category, according to the Saffir

Simpson Hurricane Scale (SSHS) is given in Table 8.6 below.



Page 31

Table 8.6: Summary of Tropical Cyclone Events within 300-km of Port Esquivel over the past 100 years [14]

On this data in Table 8.6, it can be expected that a tropical storm event or greater can be expected to

come within 300-km of the Portland Bight on average of once a year.

Figure 8.2 shows the hurricane tracks classified as category 3 and greater on the SSHS. The most

severe hurricanes come from location 77° 05‘W, 17° 50‘ N and start in the east and track west.

.

Figure 8.2: Hurricane Tracks Passing Within 300-km of the Port Esquivel (Category 3 and above) [14]

8.5 Current Profile

To be advised by CONTRACTOR [TBABC 9]



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8.6 Winds

Figure 8.3 presents the monthly wind rose diagram for NMIA from January 1998 to December 2009.

The annual wind rose diagram is given in Figure 8.4, the most frequent wind directions are coming

from the north and the southeast with average wind speed of 4.3-m/s (8.3-knots).

January

February

March

April

May

June

Figure 8.3: Monthly Wind Rose for NMIA, Jamaica (1998-2009), in knots



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July

August

September

October

November

December

Figure 8.3: Monthly Wind Rose for NMIA, Jamaica (1998-2009), in knots, cont.



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Figure 8.4: Annual Wind Rose for NMIA, Jamaica, in knots (1998-2009)

8.7 Tide Conditions

The tidal variations at the mooring location are given in Table 8.7; it shall be assumed that the tidal

variations over the pipeline route are the same.

Table 8.7: Tidal Variation [TBABC 9]

Tide Value

Highest Astronomical Tide (HAT)

Mean Highest High Water (MHHW)

Mean Sea Level (MSL)

Mean Lowest Low Water (MLLW)

Lowest Astronomical Tide (LAT)

Chart Datum (CD)

Definitions:

a) Mean Higher High Water:

The height of mean higher high water is the mean of the higher of the two daily high waters

over a long period of time. When only one high water occurs on a day this is taken as the

higher high water.

b) Mean Lower Low Water:

The height of mean lower low water is the mean of the lower of the two daily low waters over a



Page 35

long period of time. When only one low water occurs on a day this is taken as the lower low

water.

c) LAT and HAT:

Lowest and Highest Astronomical Tide which is achieved over an 18.6-year cycle.

d) Chart Datum:

The datum soundings are charted below on nautical charts as it represents minimum depth.

8.8 Storm Surge

Data for Kingston is given in [15] for various return period storms. In [14], storm surge for various

return period storms is given for offshore Jamaica; in addition, the Portland Bight bathymetry has

been modeled and the storm surge from 100-year return period storms from the east, south-east,

south and south–west storms have been modeled throughout the Bight with particular focus on the

Port Esquivel sector. Extracts from [14] are given in Appendix 6 Near-shore Storm Modelling.

8.9 Squalls

Squalls are local events of wind shear, often associated with thunderstorms, in which the wind can

suddenly change direction by up to 180°, together with a large change in speed. Squalls can occur

without warning and can cause particular problems during berthing/unmooring of the LNGCs. A good

indication of squall occurrence can be obtained by the records by metrological stations of thunder

activity by month of the year. Refer to Figure 8.5 for this data for NMIA.

Figure 8.5: Monthly Mean of Thunder at NMIA (1992-2001) [8]

8.10 Marine Growth

The SRT shall be located in tropical waters where sea characteristics will be suitable for growth of

marine fouling. Assuming that no anti-fouling measures are adopted, it is predicted that marine

fouling at the site will occur as noted in Table 8.8 below.



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Table 8.8: Marine Growth Profile [TBABC 9]

Depth, below MSL [m]

Thickness [mm]

Density [kg/m³]

8.11 Seawater Temperature

The sea surface temperatures range from 25°C to 28°C [TBC by CONTRACTOR].

Table 8.9: Seawater Temperature Profile [TBABC 9]

Depth, below MSL [m]

Minimum [°C]

Maximum [°C]

Mean [°C]

10% Exceedance [°C]

8.12 Air Temperature

Minimum and maximum air temperature and humidity data (at 07:00 and 13:00) at Norman Manley

International Airport (1992-2001) is provided in below.

The temperature variations in Jamaica are minor. The annual mean daily temperature is 28.2 °C.

The annual monthly temperatures are lowest in January and February and highest in August and

September.

Relative humidity is lower in the afternoon and higher in the evening.

Table 8.10: Air Temperature & Relative Humidity at NMIA (1992-2001) [8]

Month Air Temperature [°C] % Relative Humidity

Minimum Maximum 07:00:00 13:00:00

January 22.6 31.0 81 63

February 22.6 30.9 81 64

March 23.1 31.1 80 63

April 23.9 31.7 77 63

May 24.9 32.0 76 67

June 26.0 32.8 76 65

July 25.8 33.4 75 63

August 25.6 33.0 77 67



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Month Air Temperature [°C] % Relative Humidity

Minimum Maximum 07:00:00 13:00:00

September 25.5 32.8 79 68

October 25.0 32.4 80 68

November 24.2 32.0 81 66

December 23.2 31.4 82 63

Annual Mean 24.4 32.0 78.8 65

8.13 Rainfall

Figure 8.6 depicts the monthly mean rainfall (for years 1992 to 2001) at Norman Manley International

Airport which is in Portland Bight. Portland Bight includes two rainy seasons (May-June and

September-November). The rainfall pattern is typical of the south coast, with peaks in May and

September.

The annual mean rainfall is 61.1-mm. The driest period is usually December to March. Most of the

rainfall during this period is associated with cold fronts migrating from North America. Whether during

the dry or rainy season, however, other rain-producing systems are influenced by the sea breeze and

orographic effects, which tend to produce short-duration showers, mainly during mid-afternoon.

Storms and floods are most likely to occur from April to October, with hurricanes most frequent in July

to October. Droughts (and associated fires) can occur at any time of year.

Figure 8.6: Monthly Mean Rainfall at Norman Manley International Airport (1992-2001)



Page 38

8.14 Tsunami Potential

Based on the information provided in [3], most of the large earthquakes (magnitude 6.0 or greater) in

Jamaica over the past 100-years have occurred offshore, while the smaller seismic events were

generated beneath the mainland. For the project site, the estimated worst ground shaking will likely

last between 0.5 and 3.0 seconds. The estimated peak ground acceleration shall be 0.245g with a

10% probability of exceedance in 50-years.

The information contained within [5] provided a brief history of tsunamis in the Caribbean Sea. It

reported that, in 1907, an earthquake ruined most of Kingston, Jamaica, and damaged much of the

surrounding area, including a suspension bridge at Port Maria. A large tsunami pounded the northern

coast with waves of 2.5-m. Seiches of 2.5-m were set up in Kingston Harbour.

8.15 Seawater Properties Table 8.11: Seawater Properties


Density @ 15°C kg/m³ 1,025

Kinematic viscosity m².s-1

9.6 x 10-7

Resistivity Ohm.m 0.19

8.16 Splash Zone Elevation

Splash zone is defined from 4-m below still water level to 5-m above still water level.



Page 39

9 LNG AND GAS SPECIFICATION/COMPOSITION

The typical compositional range of LNG offloaded to the SRT and into the pipeline is summarised in

Table 9.1. The Jamaica LNG SRT shall therefore be designed to accommodate storage and

regasification of LNG for the entire range of supply fluid properties.

LNG in the storage tanks has following characteristics:

a) Pressure .............................................. 108-kPa absolute.(to high)

b) Temperature........................................ -161.4°C.

c) Viscosity .............................................. 0.112-cP.

d) Mass density ....................................... 424-kg/m³.

Table 9.1: LNG Composition [3]

Composition Light LNG (mol %) Design LNG (mol %) Heavy LNG (mol %)

CH4 96.10 96.27 88.40

C2H6 3.43 3.17 6.65

C3H8 0.39 0.42 3.15

i-C4H10 0.04 0.05 0.54

n-C4H10 0.03 0.04 0.74

i-C5H12 0.00 0.01 0.24

n-C5H12 0.00 0.00 0.00

N2 0.01 0.04 0.24

Total 100.00 100.00 99.96

M.W 16.67 16.65 18.56

G.H.V (BTU/scf) 1036/1000 1045.80 1133/930

Density (kg/m³) 432.5 433.6 466.1



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10 SRT

10.1 General

The SRT facility shall be designed with the minimum technical complexity, which shall be increased

only where justified to achieve the required standards of safety, facility availability and to meet

permitting requirements.

The full list of regulations, standards and codes can be found in Appendix 1 Codes and Standards.

10.2 Storage

The LNG receiving terminal will be capable of storing 125,000-m³ to 180,000-m³ with a working

capacity of 98.5% of the gross storage capacity; the exact size will depend on the solution provided

by the CONTRACTOR. The storage shall be able to receive and send out LNG simultaneously to

provide a constant flow LNG to the regasfication facility. Design solutions that provide storage of

greater than 150,000-m³ of LNG will be considered favourably.

10.3 Flag State

There is no preference given to any flag state.

10.4 Classification

The SRT facility shall be designed, constructed, installed and surveyed in compliance with the DNV

―Rules for Classification of LNG/LPG Floating Production and Storage Units or Installations‖, DNV-

OSS-103 or equivalent.

a) The candidate vessel for conversion must have been built to an IACS members rules for

vessels intended to carry Liquefied Gases in Bulk and to IMO International Code for the

Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (IGC Code)

requirements.

b) The new build FSRU shall be built to an IACS members rules for vessels intended to carry

Liquefied Gases in Bulk and to IMO International Code for the Construction and Equipment of

Ships Carrying Liquefied Gases in Bulk (IGC Code) requirements.

In addition to the certification required for the vessel to operate as a specialized fully refrigerated gas

carrier for hull, machinery and cargo systems, the facility shall typically have the following DNV main

Classification Society notation, or equivalent IACS Classification Society notation1:

() Floating Offshore LNG Re-gasification and Storage Terminal COAT-2 ECO BIS CSA-2 CRANE

POSMOOR

In addition, the following symbols shall be placed after the above main Classification Society notion:

1 The alternative classification society shall be selected depending on the current Classification

Society classing the LNGC vessel and selected by CONTRACTOR to class the FSRU.



Page 41

a) DNV CSA-FLS (Spectral Fatigue Analysis based on 60 year, or IACS equivalent;

b) DNV CAP 1 (Condition Assessment Program Level 1, for structural, Machinery and Cargo

Systems), or ABS equivalent.

The SRT shall perform ―In service‖ continuous hull and machinery surveys after installation and

commissioning, as required for the maintenance of Classification Society.

Surveys Schedule shall be based on DNV, or IACS Classification Society equivalent Preventive

Planned Maintenance and Continuous Machinery and Hull Survey programs to maintain the above

Classification designation.

During the CAP-1 (condition assessment program) evaluation, CONTRACTOR shall use the same

reference standards for the assessment of the cargo piping condition (corrosion allowances,

scantlings etc.) as the ones in effect for the structural part.

CONTRACTOR shall obtain a statement from Classification Society endorsing the condition of the

SRT at the start of the operations on site as adequate for extended operations for the design life

without dry-docking.

10.5 Design Life

The SRT and gas export system shall be designed for a minimum 20-year service life.

a) Minimum 20-years at site without dry-docking and subject only to in-water surveys;

b) An additional 20-years design life extension shall be applicable for new build options,

incorporating 40-years total after a single dry-docking & refurbishment after the first 20-years.

Subject only to in water surveys in the 20-year extension.

10.6 Design Conditions

The SRT and its associated systems shall be designed for the following conditions:

a) Survival - the 100-year return period storm during which the process facilities will be shutdown;

b) Operational – the 10-year return period storm condition during which the process is required to

be operational and the vessel remain at site.

10.7 Fire Safety and Hazards Control

10.7.1 Primary Protection System

The measures that shall be considered to protect against the hazard risks are as follows:

a) Primary and secondary containments shall be provided to prevent hydrocarbon liquid or gas

escaping. The potential for LNG leakage needs to be reduced by minimising, by design, the

number of leak points and the selection of reliable equipment minimising intervention (such as

selection of ring type joints, seal-less pumps, instrument hook up, avoidance of flange

connections where practical). In addition, facilities shall be incorporated to facilitate the

removal of spilled LNG to help protect it from low temperature embrittlement, and to help

protect equipment from escalation events;



Page 42

b) Provide fixed fire and gas detection systems comprising two different types of elements which

shall activate an audible alarm at a manned control stations to alert operators to a loss of

containment incident;

c) A low temperature detection system shall be provided around the facility to alert personnel in

the event of a liquid or vapour leak;

d) Maintain integrity of the containment boundary at all times to reduce the possibility of an

uncontrolled discharge of LNG or LNG vapour;

e) Maintain a positive but practical separation between process or storage areas and areas

containing sources of ignition.

10.7.2 Secondary Protection Systems

The secondary systems employed to prevent the spread of the hazard risks shall include:

a) Firewater based fire protection system (e.g. deluge and sprinkler systems);

b) A dry powder extinguishing/high expansion foam system

c) Gaseous fire suppression system;

d) Personnel protection and life-saving appliances;

e) Passive fire protection (PFP).

10.8 Escape, Muster, Evacuation and Rescue

Diverse means of escape shall be provided. The philosophy to be adopted for evacuating the facility

is to safely and efficiently distance all personnel from any hazardous event that could render the

facility unsafe.

10.9 Personal Safety and Live Savings Appliances

The principal requirements for all types of safety equipment are to be specified including installation

and storage locations. Items to be specified shall include:

a) Personal Protective Equipment (PPE)

b) Self-Contained Breathing Apparatus (SCBA)

c) First aid equipment

d) Emergency safety showers and eye wash stations

e) Safety sign and notices

f) Cold impact protection

g) Fire blankets

h) Life jackets

i) Escape vessel



Page 43

10.10 Future Expansion

The facilities shall initially be designed for a normal supply of 1.10-mmtpa (150-mmscfd) LNG.

Allowance shall be made for future expansion to supply up to 2.5-mmtpa (320-mmscfd) LNG to

enable additional users to be added to the distribution network.

10.11 Design Loads and Excursions

10.11.1 Mooring Analysis

Motion responses of the FSRU during the sailing and operating phases shall be analyzed using a 3D

diffraction theory. Critical environmental induced loads and motions of the vessel moored against the

jetty shall also be analysed to confirm the adequacy of the hull, fender and mooring line loads.

FSRU motions shall be analysed to confirm the adequacy of the FSRU design connected to the

mooring system to perform safely and efficiently loading operations of LNG. Analysis based on the

proposed vessel hull form shall be conducted to determine the following:

a) Motion characteristics;

b) Mooring system performance in various operating and fatigue design conditions;

c) Loads in the mooring lines;

d) Hull pressure in way of fenders;

e) Rolling reduction requirements;

f) Operating limits for jetty mooring and offloading operations, including permissible excursion

envelopes of the loading arms;

g) Extent of green water during sailing conditions;

h) Hydrodynamic slam forces during sailing conditions; and

i) Underkeel clearance in operating conditions.

10.11.2 Design Loads

The FSRU equipment, equipment foundations and sea fastenings are to withstand the minimum peak

accelerations along the length of the FSRU beam (either portside or starboard side). CONTRACTOR

is required to calculate the accelerations to be used in their calculations with reference to section

10.11.1.

10.11.3 Fender Loads

Maximum contact pressure of the FSRU hull is [TBABC 2] tonnes/m²

10.11.4 Trim

It is expected that the FSRU shall be operated on even trim or trimmed. Operational trim shall be not

more than 3° and maximum trim excursion shall be limited to 5-m. CONTRACTOR shall consider the

trim conditions in all two-phase system to ensure that liquids do not collect in headers and that vapour

locks do not occur.



Page 44

10.12 Emergency Shutdown Valves

Shutdown valves shall be provided to facilitate safe shutdown/inventory isolation such that the risk of

escalation is minimised in the event of an emergency. Refer to FSRU Functional Specifications [12]

for further details.

10.13 Remote Telemetry System

A remote telemetry device or devices shall be provided to facilitate interfacing between process

control (inc. inventory and send-out volumes), process safety and fire and gas systems on the SRT,

mooring system, pipeline and ORFs. See the FSRU Functional Specifications [12] for further details.

10.14 Power Generation System

The jetty power generation system shall be an independent power supply and provide power to the

entire FSRU including regasification plant, storage and cargo system, accommodation, control,

marine systems and the mooring system under all normal operating circumstances. The minimum

power generation requirements are as follows:

a) Main generator (steam or LNG and/or MDO):

i) Number of generator units ........ [TBABC 10];

ii) Rating........................................ [TBABC 10] kWe;

iii) Power factor .............................. [TBABC 10];

iv) Voltage and frequency .............. [TBABC 10];

v) Type .......................................... Brushless, synchronous;

vi) Insulation .................................. Class-F.

b) The emergency generator (MDO only) details are:

i) Rated capacity .......................... [TBABC 10] kW;

ii) Voltage ...................................... [TBABC 10] V;

iii) Frequency ................................. [TBABC 10] Hz.

10.15 Cargo Tank Operations

The cargo tanks operations design condition shall be:

a) Cool down operations for all tanks shall not exceed 30-hours;

b) Warm up operations for all tanks shall not exceed 30-hours. The warm up operation is to be

considered completed when the tank walls are approximately 5°C;

c) The cargo tank and system inerting shall take less than 20-hours to complete;

d) The cargo tank and system aerating shall take less than 20-hours to complete;

e) Firewall and overpressure requirements shall be designated based on the outcomes of

consequence analysis and in accordance with recognized international codes and standards;



Page 45

f) The cargo pump system shall include one duty and one standby submersible cryogenic pump

for each storage tank.

g) Purge piping is provided behind the primary barrier to detect leakage and to maintain a non-

flammable atmosphere within the insulation.

10.16 Ballast System

For a new build FSRU the ballast system shall be designed as follows:

a) A port and starboard ring line ballast system, servicing all ballast tanks, with branch lines to the

individual tanks shall be provided;

b) One sea chest shall be arranged on each side of the vessel;

c) The ballast system capacity shall be not less than 5,000-m³/hr.

10.17 Accommodation

The accommodation shall be optimized for the normal operation POB. Berths, catering facilities,

escape facilities, utility systems and sanitary facilities must be designed for the maximum

complement.

The accommodation block shall be laid out with permanent beds to accommodate a complement or

POB of 44-men maximum with a total of 20-men per shift. Where the minimum cabins requirements

as follows:

a) 1 berth cabins x 10

b) 2 berth cabins x 13

c) 4 berth cabins x 2

Accommodation area shall be protected by sprinkler system designed in accordance with NFPA 13.

Should the SRT consist of a permanently moored barge, bridge linked to shore then only emergency

accommodation is required.

10.18 Noise and Vibration Levels

Noise and vibration levels in all crew spaces (accommodation and work areas) are to comply with ISO

9654:2000 and IMO Resolution a.468. The noise level limits shall not exceed the limits given as in

Table 10.1 during normal FSRU operating conditions.

Table 10.1: Noise Level Limits

Noise Level Limits dB(A)

Continually Manned Machinery Space 85

Non-Continually Manned Machinery Space 108

Machinery Control Rooms 75

Offloading Areas Duty Station 80



Page 46


Regasification Plant 75

Control Room 65

Offices 65

Hospital 60

Crew Public Spaces 65

Crew Cabins 60

The vibration peak limits shall not exceed the values as given as in Table 10.2 during normal FSRU

operating conditions.

Table 10.2: Vibration Level Limits

Vibration Level Limits 1 to 5-Hz 5 to 100-Hz

Upper Levels 214-mm/s² 6-mm/s²

10.19 Corrosion Protection

The FSRU corrosion protection and cathodic protection shall be designed in accordance with DNV-

RP-B101 and DNV-RP-B401.

The mooring system corrosion protection and cathodic protection shall be designed in accordance

with DNV-OS-C101, DNV-RP-B101 and DNV-RP-B401. The lifetime of the corrosion protection

system for the FSRU shall be consistent with the hull.

a) The FSRU hull corrosion protection system shall include an Impressed Current Cathodic

Protection (ICCP) system;

b) ICCP system shall be designed such that potentials at the edge of the dielectric shields will not

be more negative than -1.2-V (Ag/AgCl Seawater) at any time during the service life;

c) Ballast tank shall be fitted with zinc sacrificial anodes for corrosion protection;

d) The material protection/cathodic protection system used on the FSRU must be compatible with

the MS cathodic protection system; and

e) The ICCP system shall be integrated with the jetty ICCP system.

10.20 Boil-off Gas

The maximum boil-off rate from the storage tanks shall be less than 0.18% per day.



Page 47

10.21 Overpressure Protection

All equipment and piping systems shall be protected when the internal or external pressure exceeds

the design condition of the system due to an emergency, upset condition, operational error,

instrument malfunction or fire:

a) All design shall be in accordance with the latest editions of API RP 520 and 521;

b) An on-board flare system is the preferred method to dispose of process vent gases on the

FSRU. However, if cold venting is proposed then CONTRACTOR shall undertake dispersion

modeling of the vent gases to verify that the system shall meet all safety requirements. The

location and length of the vent shall take into account the hydrocarbon LEL limits acceptable on

the facility in the event of venting and or relief cases and the resultant heat radiation in the

event of inadvertent ignition of vent gases. Dispersion analysis for the vent shall be performed

to check HC gas LEL concentration. The radiation study shall also be performed in case the

vents catch fire due to lightning. In order to minimize ingress of air, the vent tip shall be

equipped with a fluidic seal. CO2 snuffing system shall be provided to extinguish the flame in

the event of gas ignition.



Page 48

11 JETTY

11.1 Mooring Equipment

The jetty shall be equipped with sufficient mooring equipment to allow mooring of the SRT and a

range of LNGC‘s.

a) The mooring hooks shall be equipped with load monitoring equipment which shall provide

continuous mooring line load monitoring in the central control room;

b) The quick release hooks shall have a SWL not less than the 180-tonne;

c) All mooring fittings are to comply with appropriate OCIMF recommendations.

11.2 Loading Arms

The LNG loading arms shall be designed to the following conditions:

a) A minimum of four standard 16-inch LNG loading arms, two for LNG, one for vapour return and

one spare (hybrid) shall be installed on the jetty;

b) Each loading arm flow rate shall not be less than 6,000-m³/hr;

c) The bearings and seals in the arms shall be designed for continuous oscillating motions;

d) The arms shall be equipped with double ball valve/powered emergency release couplers and

hydraulic type normal connect/disconnect;

e) The arms shall be supplied with a comprehensive operating, control and alarm system

integrated with the SRT cargo handling and shutdown systems;

f) A one day turn around is assumed for common LNG carriers while at the SRT. Hence the

system must be designed to transfer a nominal 157,000-m³ cargo in 16-hours of cargo pumping

time;

g) The loading arms shall be operational for all differential draft conditions;

h) The loading arm operational motion envelope shall be at least ±2.5-m in all directions;

i) The actual motion envelope is to be assessed based on the range of LNGCs likely to offload at

the SRT;

j) Loading arms shall be designed for cryogenic service; and

k) Two standard 16-inch, 90-bar, natural gas loading arms for the FSRU.



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12 SUBSEA EXPORT PIPELINE

12.1 Pipeline Throughput Capacity

The pipeline from SRT to ORF, at Old Harbour, shall be sized for a throughput capacity of 320-

mmscfd, based on receiving pressure of 80-barg at inlet to ORF and a temperature of 10°C.

12.2 Design Life

The subsea export pipeline shall be designed for a minimum 40-year service life.

12.3 Pipeline Route Selection

The pipeline route shall be selected based on the survey data, satisfying the following criteria:

a) Minimise pipeline route length while containing the route within the survey corridor to the extent

possible;

b) Provide approximately 500-m straight length prior to initiating any horizontal curvature;

c) Provide adequate horizontal bend radius;

d) Avoid highly undulating seabed features wherever possible and minimize pre-lay seabed

intervention works;

e) Minimise pipeline/cable crossings, if any;

f) Avoid undesirable seabed features and obstructions;

g) Where the pipeline is installed adjacent/parallel to an existing pipeline a minimum separation of

20-m shall be maintained, except at the SRT approach;

h) Avoid anchorage areas;

i) Minimum pipe bend radius is 10D (for intelligent pigging);

12.4 Shore Approach Design

a) The shore approach design shall be done based on the following assumptions:

i) Shore crossing shall be done by means of HDD and the exit point of HDD section shall

be at water depth of 10-m with respect to LAT.

ii) After HDD exit point, the rest of pipeline route shall be buried with 1-m cover above the

top of the pipeline (excluding expansion piece); alternate forms of pipeline protection

channel shall be considered near shipping.

b) The following exercises shall be performed:

i) Review of geophysics and geotechnical survey data.

ii) Review suitability of the proposed shore approach location.

iii) Review options and methods available for shore approach installation.



Page 50

iv) Recommend and justify the most suitable installation option for the project.

v) Perform shore approach assessment/design calculations.

12.5 End Expansion and Thermal Offset Design

Pipeline end expansion shall be performed to evaluate the magnitude of the displacement as well as

the length of the unrestrained portion of the pipeline, which is subjected to thermal expansion and

pressure expansion forces. The dimensions for expansion offsets shall be investigated to absorb the

displacement.

Pipeline expansion spool analyses and design shall take into account earthquake loads as

appropriate based on the relevant zone specified in IS Code IS 1893:2002 Criteria for Earthquake

Resistant Design of Structure.

12.6 Fluid Categorization and Safety Classes

As per DNV-OS-F101 section 2 C200 and C400:

Table 12.1: Fluid and Safety Categorization

Description Data

Fluid Category E

Safety Class

Installation/Hydrotest Low (Zone 1) Low (Zone 2)

Operational Normal (Zone 1) High (Zone 2)

12.7 Offshore Pipe Wall Thickness Selection

The pipe wall thickness selection shall be performed primarily as per DNV-OS-F101 design criteria.

DNV proprietary spreadsheet shall be used for the design calculation.

a) Pressure Containment (Bursting)

Pressure containment check shall fulfil the criteria of DNV-OS-F101 section 5 D200:

b) Local Buckling-External Over pressure Only (System Collapse)

External collapse pressure resistance shall be as per section 5 D400 of DNV-OS-F101.

c) Propagation Buckling

Section 5 D500 of DNV-OS-F101 implies that a buckle cannot be initiated within a portion of

the pipe where the maximum external pressure (Pe) is less than the collapse pressure. If

buckle occurs and Pe exceeds Initiation Pressure (Pinit) which is subject to size of the initial

buckle, propagating buckle shall be started and continue whenever the external pressure is

higher than Propagating Pressure (Ppr), unless the external pressure is lesser than it.

d) Combined Loading – Load Controlled Condition

Pipe members subjected to bending moment, effective axial force and internal overpressure

shall be designed to satisfy the condition at all cross sections as per section 5 D600 of DNV-

OS-F101.



Page 51

12.8 Pipeline On-Bottom Stability

Stability design shall demonstrate that the pipeline is stable under the installed condition in both

horizontal and vertical direction as per DNV RP E305 (1988). Conservatively, it is considered that the

pipeline would be buried by the post jetting method. Therefore, pipeline lateral stability shall be

checked considering one year environmental condition. Since the pipeline is buried, no lateral

stability analysis needs to be carried out for the operating condition.

The following criteria shall be considered:

a) Minimum stability factor as per DNV RP E305 shall be satisfied under installation condition,

considering 1-year environmental conditions.

b) Minimum water depth with respect to LAT shall be used.

12.9 Concrete Coating If concrete coating is required for on-bottom stability, it shall comply with the properties as listed

below:

Table 12.2: Concrete Properties


Density kg/m³ 3,040

Thermal Conductivity W/m°C 2.1

Heat Capacity W.s/kg°C 880

12.10 Hydrodynamic Coefficients

Hydrodynamic Coefficients to be considered in the pipeline design are (Clause 5.38 of DNV RP

E305):

a) Drag coefficient (Cd) ........................... 0.7

b) Lift coefficient (Cl) ............................... 0.9

c) Inertia coefficient (Cm) ........................ 3.29

12.11 Pipeline External Anti-Corrosion Protection

12.11.1 External Anti -Corrosion Coating

Anti-corrosion coatings shall provide the primary preventative measure against external corrosion. A

cathodic protection system shall be provided as a secondary measure in the event of coating

damage. Corrosion coating materials selected shall be suitable for installation technique and marine

environmental conditions and selection shall be a function of the design temperature of the pipeline.

The pipeline shall have a conventional asphalt enamel coat/wrap system with outer concrete coating.

Sections of pipeline without concrete coating shall be coated with fusion bonded epoxy (FBE).



Page 52

All field joint coatings shall be compatible with the main pipeline coating and pipeline operating

temperature and shall be evaluated based on technical and commercial attractiveness.

Monolithic isolating joint shall be installed to electrically isolate the offshore pipeline with topside

piping.

Coating requirements shall be confirmed following generation of the pipeline external coating

selection report by the CONTRACTOR during detailed engineering.

12.11.2 Cathodic Protection

The subsea pipeline shall utilise cathodic protection by sacrificial anodes (bracelet half-shell type)

designed in accordance with DNV-RP-F103 as per the following requirements:-

a) Current output of the sacrificial anodes shall be greater than the required protection current at

all locations and at all times throughout the system design life

b) Net mass of anode assembles shall be sufficient to last the system design life.

12.12 Pipeline Inspection Requirements

It is expected that the Regulating Authorities will require internal inspection of the pipeline. Internal

inspection shall be performed by ―intelligent pigging‖ from the SRT to the ORF.

Return-pigging from the ORF to the SRT and then back to the ORF has not been considered as it

impacts on the availability of the SRT as well as requiring flaring of export gas at the SRT during the

pigging process.

The mooring system shall be fitted with a pig launcher, vertical or horizontal, that can accommodate

the appropriate diameter intelligent pig.

In addition, all pipeline bends shall have a bend radius of at least 10D to allow the intelligent pig to

pass.

The ORF shall to be capable of receiving the intelligent pig in a horizontal pig receiver (trap).

12.13 Pipeline Commissioning

Due to the local environment, it may be required to clean the pipeline internally prior to commencing

production to reduce the dust load on the ORF inlet filters. The pipeline design and installation

contractors shall review this requirement and provide the appropriate facilities at the SRT and the

ORF.



Page 53

13 ONSHORE RECEIVING FACILITIES

13.1 Overview

During initial Project Phase 1, the FSRU production will be 0.83-mmtpa expandable to 2.5-mmtpa for

additional supply to Phase 2 users. The Phase 1 user and demand information is summarised as

follows:

a) Jamalco (~320,000-tpa);

b) Old Harbour power station (~370,000-tpa);

c) JEP (~140,000-tpa).

The incoming gas is received from the pipeline at the Old Harbour Onshore Receiving Facilities

(ORF). The ORFs shall incorporate block valves to allow isolation and pressure letdown facilities to

enable supply gas to end-users at pressures as follows:

a) 30-barg [TBABC 1] for Phase 1 users;

b) [TBABC 1] barg for Phase 2 users.

The ORFs consist of the following major pieces of equipment:

a) Pig receiver (refer also to sections 12.12 and 12.13);

b) Pipeline filters;

c) Pressure letdown system;

d) Indirect fired water bath heater;

e) Metering skid;

f) Cold vent;

g) Instrument air compressor and dryer;

h) Utility water storage tank;

i) Fire water system; and

j) Diesel generator (as required, refer to section 13.9.4).

13.2 Noise

The onshore noise emission levels during the day time (07:00 to 22:00) and night time (22:00 to

07:00) that the ORF‘s are to comply with NEPA guidelines.

13.3 Pig Receiver

The pig receiver shall be provided to allow pigging of the pipeline. As the export gas is non-corrosive

and does not contain liquids, it is expected that pigging shall only be required on initial commissioning

and afterwards only for intelligent pig surveys as required by the Regulatory Authority.



Page 54

Table 13.1: Pig Receiver Design Data

Parameter Unit Value

Quantity - Fully spared

Pressure:

Design

Operating

barg

barg

[TBABC 1]

[TBABC 1]

Temperature:

Design

Operating

°C

°C

[TBABC 1]

[TBABC 1]

Material: Carbon steel

13.4 Filter

The incoming gas shall be filtered to remove particles which may damage the flow meters. There are

two filters with a maximum capacity of [TBABC 1]-mmscfd each, one duty and the other one as

standby. Each filter shall be equipped with a pressure differential gauge to allow for online filter

monitoring. A differential pressure transmitter shall initiate an alarm to alert operator to changeover to

the other filter. This will be a manual operation.

A pressure safety valve (PSV) is installed at filter outlet to protect the filter from overpressure; the

relief pressure being set at [TBABC 1] barg.

The filters shall be vertical basket type with a quick opening closure for basket change out, with

[TBABC 1] mesh lining. The baskets shall be cleanable and reusable. Design data for the filters are

noted in Table 13.2

Table 13.2: Filter Design Data



Pressure:

Design

Operating

barg

barg

[TBABC 1]

[TBABC 1]

Temperature:

Design

Operating

°C

°C

[TBABC 1]

[TBABC 1]

Maximum capacity (per filter) mmscfd [TBABC 1]



Page 55


Degree of filtration Mesh [TBABC 1]

Material:

Shell

Filter element

-

-

SA 516 Gr 70 N

SS 316

As previously noted, the filters shall operate in dry service and are therefore intended for removal of

solid particulate material only i.e. design provision for liquids handling is not required. On this basis,

any cleaning/pressure testing or other commissioning activities shall be carried out with a view to

returning piping and equipment to service in a dry condition.

13.5 Pressure Letdown Station

The pressure letdown station is provided to regulate the gas pressure supplied to end-users.

Pressure-reducing equipment design shall be developed as end-user demand data is made available.

13.6 Fiscal Metering Skids

The fiscal metering skid is provided to measure gas supplied to end-users. The function of the

metering system is to measure the total volumetric throughput of gas, calculate the heating value and

Wobbe index from the gas chromatograph.

2 ultrasonic flow metering lines shall be provided each of 160-mmscfd, with provision to add another

two identical metering lines to have total metering capacity of 320-mmscfd in future.

The design condition of the metering skid is summarised in Table 13.3.

Table 13.3: Gas Metering Skid



Pressure:

Design

Operating

barg

barg

[TBABC 1]

[TBABC 1]

Temperature:

Design

Operating

°C

°C

[TBABC 1]

[TBABC 1]

Maximum gas flow mmscfd 160



Page 56

13.7 Indirect Fired Water Bath Heater

The indirect fired water bath heater is provided to preheat the gas temperature from [TBABC 1] to

[TBABC 1] before reducing the gas pressure from [TBABC 1] barg to 30 barg [TBABC 1] through the

pressure letdown station such that the minimum delivery temperature of [TBABC 1] to end-users is

met. In addition, heating the gas before pressure reduction shall prevent potential icing on the control

valves due to ambient air condensation as the gas pressure is letdown.

The design condition of the heater is as follows:

Table 13.4: Indirect Fired Water Bath Heater


Quantity - Note 1

Pressure:

Design

Operating

barg

barg

[TBABC 1]

[TBABC 1]

Temperature:

Design

Operating

°C

°C

[TBABC 1]

[TBABC 1]

Maximum gas flow mmscfd [TBABC 1]

Material - Carbon steel

Notes:

Quantity to be confirmed by CONTRACTOR subject to availability requirements. RAM study shall be

completed to validate claimed availability.

13.8 Cold Vent

A cold vent [TBABC 6] is provided to safely dispose hydrocarbon to atmosphere under maintenance

or emergency relief. The location and length of the vent shall take into account the hydrocarbon LEL

limits acceptable on the facility in the event of venting and or relief cases and the resultant heat

radiation in the event of inadvertent ignition of vent gases. Dispersion analysis for the vent shall be

performed to check HC gas LEL concentration. The radiation study shall also be performed in case

the vents catch fire due to lightning. In order to minimize ingress of air, the vent tip shall be equipped

with a fluidic seal. CO2 snuffing system shall be provided to extinguish the flame in the event of gas

ignition.

The cold vent system design is governed by the control valve failure. The vent system capacity shall

be confirmed during the detailed engineering phase.



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13.9 Utility Systems

13.9.1 Instrument Air

An instrument air system consisting of the following components shall be installed on the ORF:

a) 2 x 100% electric motor driven rotary screw compressors

b) 2 x 100% dual air dryer package (heatless type)

c) Pre & post filters

d) Instrument air receiver

The system shall be a skid mounted package, with the exception of the receiver vessel. The

operating philosophy of air compressor unit shall be one running and one standby.

The design requirement instrument air shall be based on maximum demand as required for process

control purposes. The instrument air receiver shall be provided with a minimum capacity to hold 15

minutes of the design instrument air demand.

a) The operating and design condition of air compressor system [TBABC 5] is as follows:

i) Capacity .................................... CONTRACTOR to confirm

ii) Maximum pressure ................... 10-barg.

iii) Design pressure ........................ 12-barg.

iv) Design temperature .................. 65°C

v) Material of construction ............. C.S for equipment/Galvanized C.S for piping

b) The specification of instrument air dryer is as follows:

i) Capacity .................................... CONTRACTOR to confirm

ii) Dew point .................................. -10°C minimum (water dew point)

iii) Oil/Liquid content ...................... < 0.01-ppm by wt.

iv) Dust particles ............................ < 2 microns in size, if present.

c) The operating and design condition of instrument air receiver is as follows:

i) Size ........................................... CONTRACTOR to confirm

ii) Operating pressure ................... 8 to 9-barg

iii) Operating temperature .............. Ambient to 50°C

iv) Design pressure ........................ 12-barg

v) Design temperature .................. 65°C

The PCS shall monitor the instrument air pressure via a pressure transmitter installed on the

Instrument air header. The PCS shall be configured with alarm set points to alert operators of falling

instrument air header pressure prior to further executive action.

It is noted that instrument gas may be considered in place of instrument air based on CONTRACTOR

cost-benefit analysis.



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13.9.2 Util ity Water

Two utility water storage tanks shall be provided to store water for personnel usage, wash down and

water make-up for the indirect fired water bath heater. The storage tank located on the ground shall

be designed with two compartments to facilitate cleaning of one tank. The other water tank shall be

located at elevated place to enable gravity flow to delivery points. The water transfer from the ground

storage tank to the elevated tank shall be achieved via fully spared potable water pumps.

The ground storage tank is sized to provide 7-days storage for 5-persons with 150-litre/day personnel

consumption while the elevated tank is sized to provide 3-days storage. The ground storage tank is

provided with a filling line with a quick connection coupling. It is envisaged that the water supply will

be delivered by the water supply truck.

a) The ground water storage tank design condition is as follows:

The CONTRACTOR shall confirm tank capacity and dimensions during detailed engineering.

i) Operating pressure ................... Atmospheric

ii) Operating temperature .............. Ambient

iii) Design pressure ........................ Full of water


b) The elevated water storage tank design condition is as follows:

The CONTRACTOR shall confirm tank capacity and dimensions during detailed engineering.

i) Operating pressure ................... Atmospheric

ii) Operating temperature .............. Ambient

iii) Design pressure ........................ Full of water


c) The potable water pump design condition is as follows:

The CONTRACTOR shall confirm pump capacity and differential head requirements during

detailed engineering.

i) Capacity .................................... [TBABC 5] m³/hr each

ii) Differential head ........................ [TBABC 5] m

13.9.3 Firewater System

ORF shall be provided with active fire fighting equipment i.e. fire hydrant, fire monitor and fire hose.

Provision of firewater storage tank and firewater pumps to supply firewater requirements shall be

developed by the CONTRACTOR in compliance with International standards.

13.9.4 Electrical Power System

The ORF shall receive 400-V, 50-Hz, 3 Phase electrical power. Four wires will be received from the

Power Grid LV Switchboard via one feeder of adequate rating. The switchboard shall be provided

with two incomers, one for the PG incoming supply and the other for supply from a (permanent or

temporary) diesel generator (DG) back-up. Requirements for a permanent DG back-up power supply



Page 59

shall be determined by the CONTRACTOR based on Jamaican power grid reliability data such that

facility availability demands can be guaranteed.

The back-up (permanent or temporary) DG shall be feed loads only in the case of PG mains power

failure. The loads shall be retransferred manually once the PG incomer is healthy. The PG incoming

feeder shall be properly laid in PVC pipe encased in concrete. Power supply from the PG and DG

shall not be run in parallel.

13.9.5 Nitrogen

Nitrogen is not required for the normal operation of the ORF. Nitrogen in compressed form shall be

provided on an as-needed basis via bottle packs.

13.9.6 SCADA

The ORF shall be provided with remote monitoring capability such that safety and operability can be

assured. It is envisaged that signalling from the ORF shall be linked to the FSRU via telemetry;

however this shall be confirmed by the CONTRACTOR.



Page 60

14 REFERENCES

[1] ‗JEP Power Barge Final EIA‘ by CL Environmental Co. Ltd. dated April 2005

[2] Ref: 2006/585/A ‗Mustang Engineering LNG Import Plant Port Esquivel, St. Catherine-

Geotechnical Investigation‘ by Jentech Consultants Ltd. dated 2006

[3] Document CD*PRJ 1032/05 ‗EIA for the Construction and Operation of a Temporary Barge

Unloading Facility at Rocky Point, Clarendon by Jamalco‗, Conrad Douglas and Associates,

Ltd., dated January 2007

[4] ‗Jamaica Road Show Presentation‘ dated March 2011

[5] WGS 84 Positions - ‗West Indies Jamaica- South Coast, Portland Bight Location Map‘, 2nd

Edition, dated 29th August 2004

[6] ‗Current Status, LNG Supply RFP, Re-Tender of the LNG Infrastructure‘ dated 27th June

2011

[7] 402010-00260-GE-RFQ-0002: ‗Jamaica LNG Project, Request for Quotation – Form of Bid:

Technical Proposal‘,

[8] Meteorological Data obtained from Norman Manley International Airport, Jamaica

Meteorological Station

[9] Hennemann, G.R. and Mantel, S. 1995. Jamaica: A Reference Soil of the Limestone

Region. Soil Brief Jamaica 1. Ministry of Agriculture, Kingston and International Soil

Reference and Information Centre, Wageningen pp19.

[10] Caribbean Disaster Mitigation Project – Seismic Hazards maps: Jamaica

http://www.oas.org/CDMP/Document/seismap/jamaica.htm

[11] WorleyParsons, ―Jamaican LNG FSRU, LNG FSRU Functional Specification‖, 402010-

00260-00-MA-SPC-0002.

[12] WorleyParsons, ―Jamaican LNG FSRU, Jetty Moored FSRU Functional Specification‖,

402010-00260-00-MA-SPC-0005.

[13] WorleyParsons, ―Jamaican LNG FSRU, FSRU Operating Philosophy‖ 402010-00260-MA-

00-PHL-0001.

[14] ‗LNG- MUSTANG FEED Environmental Impact Assessment‘ by Smith Warner International

Ltd. dated January 2007.

[15] CDMA KMA Coastal Hazard Assessment Final Report

http://www.oas.org/cdmp/document/kma/coastal/coastrep.htm

[16] Natural Resources Conservation Authority, ―Ambient Air Quality, Guideline Document‖,

prepared for National Environment & Planning Agency by Claude Davis & Associates, ©

November 2006.

http://www.oas.org/CDMP/Document/seismap/jamaica.htm

http://www.oas.org/cdmp/document/kma/coastal/coastrep.htm



c:\users\ernie laptop\documents\jamaica lng\worleyparsons\word documents\402010-00260-00-ge-bod-0001 (basis of design).doc

Appendix 402010-00260 : 00-GE-BOD-0001 Rev 3 : 26 August 2011\

Appendix 1 Codes and Standards




Page 1 402010-00260 : 00-GE-BOD-0001 Rev 3 : 26 August 2011

Table Appendix 1.1: Summary of Applicable Standards/Codes for Health &Safety

Code No. Title

DNV-OS-A101 Safety Principals and Arrangement

DNV OS-D301 Fire Protection

DNV-OS-E201 Hydrocarbon Production Plant (pressure relief)

API RP 521 Guide for Pressure-Relieving and Depressuring Systems

API RP 14C Recommended Practice for Analysis, Design, Installation, and Testing

of Basic Surface Safety Systems for Offshore Production Platforms

API RP 70 Security for Offshore Oil and Natural Gas Operations

NFPA 59A Standard for the Production, Storage and Handling of LNG (see

section F.2 for details of partial and supplemented application)

EEMUA Engineering Equipment and Material Users Association Guide No.

140: Noise Procedure Specification

ISO International Standards Organization, all relevant standards

Table Appendix 1.2: Summary of Applicable Standards/Codes for Environmental

Code No. Title

ISO 14001 International Standards Association – Environmental Management

System

MARPOL International Convention for the Prevention of Pollution from ships

1973

Table Appendix 1.3: Summary of Applicable Standards/Codes for Quality Assurance

Code No. Title

ISO 9001 International Standards Association – Quality Management System

DNV-OSS-309 DNV Verification, Certification and Classification of Gas Export and

Receiving Terminals (FSRU classification)

DNV-OSS-300 Risk Based Verification (refs: OSS-301 (pipelines), OSS-302 (risers),

etc)

DNV-RP-G101 Risk Based Inspection –Offshore Topsides Mechanical Equipment

(supplemental to OSS-309)



Page 2

Code No. Title

ASME B 31.8S Pipeline Integrity Management System (supplemental to DNV-OSS-

301)

Table Appendix 1.4: Summary of Applicable Standards/Codes for IMR

Code No. Title




etc)




301)

API 510 Pressure Vessel Inspection Code: maintenance, inspection, rating,

repair and alteration.

API 570 Piping Inspection Code: Inspection, Repair, Alteration and re-rating

on in-service piping systems

API RP 574 Inspection Practices for piping system components

API 1104 Welding of Pipelines and related facilities (inspection of welds)

Table Appendix 1.5: Applicable Standards/Codes for the FSRU

Code No. Title

DNV-OSS-309 DNV‘s Verification, Certification and Classification of Gas Export and

Receiving Terminals.

DNV-OSS-103 Rules for Classification of LNG Floating Production and Storage Units

or Installations

API RP 2C/D Offshore cranes/operation and maintenance

API RP 2A-WSD Planning, Designing and Constructing Fixed Offshore Platforms

Working Stress Design (for topside structures, including flare tower)

IGC International Code for the Construction and Equipment of Ships

Carrying Liquefied Gases in Bulk

DNV PT.5 Chapter 5 DNV Rules for Ships, Part 5, Chapter 5, Liquefied Gas Carriers



Page 3

Code No. Title

DNV-OS-C101

Design of Offshore Steel Structures, General (LRFD method) (for

topside structures, including flare tower), supplementing API RP 2A to

account for vessel motions, etc.

DNV-RP-C102 Structural Design of Offshore Ships

AISC-WSD AISC WSD Manual of Steel Construction (for topside structures,

including flare tower)

CN30.7 DNV Classification Note No. 30.7 Fatigue Assessment of Ship

Structures, February 2003

CN33.1 Classification Note No. 33.1 Corrosion Prevention of Tanks and

Holds, July 1999

DNV-RP-B401 Cathodic Protection Design

DNV-RP-B101 Corrosion Protection of Floating Production and Storage Units

DNV-RP-C201 Buckling Strength of Plated Structures

SIGTTO/ICS/OCIMF 1995 Ship to Ship Transfer Guide (Liquefied Natural Gas),

IGTTO/ICS/OCIMF

COLREG International Regulations for Preventing Collisions at Sea

USCGD FRSU and LNGC Exclusion and Safety Zones

NVIC 05-05 Waterway Suitability Assessment (WSA)

DNV-OS-D101 HVAC Standards

IMO Res A.468(XII) Code of Noise Levels on Board Ships

ISO 6954 :1984 Mechanical vibration and shock—Guidelines for the overall evaluation

of vibration in merchant ships.



ISO 4867 Code for the measurement and reporting of shipboard vibration data

ISO 4868 Code for the measurement and reporting of local vibration data of

ship structures and equipment.

ISO 2041 Vibration and shock— Vocabulary

ISO 2631 Guide for the evaluation of human exposure to whole-body vibration.

ISO 2923



Page 4

Code No. Title

UL595 - Marine Type Electric Lighting Fixtures

SIGGTO Manning Qualification Requirements

ILO International Labour Organisation - Maritime Labour Convention

IACS No 47 Shipbuilding & Repair Quality Standard

TSCF Guidelines for Ballast Tank Coating System and Surface Preparation

Table Appendix 1.6: Applicable Standards/Codes for Fendering & Mooring

Code No. Title

SIGTTO/ICS/OCIMF Ship to Ship Transfer Guide (liquefied Natural Gas)

OCIMF Mooring equipment Guidelines

OCIMF Prediction of Wind and Current Loads on VLCCs,

OCIMF Guidelines and Recommendations for the safety mooring of large

ships at piers and Sea Islands

DNV-OS-E301 POSMOOR

Table Appendix 1.7: Applicable Standards/Codes for Mechanical Systems

Code No. Title

DNV-OS-D101 Marine and Machinery Systems

Recognised codes for piping systems

ASME B31.3 Process piping

API RP 14 E Design and Installation of Offshore Production Platform Piping

Systems

Recognised codes for unfired pressure vessels

ASME section VIII Boilers and Pressure Vessel Code

Rules for Classification of

Ships Pt.4 Ch.7

Boilers, pressure vessels, thermal-oil installations and incinerators

Recognised codes for boilers

API Std 530 Calculation of Heater Tube Thickness in Petroleum Refineries

ASME section I Power Boilers



Page 5

Code No. Title

ASME section IV Heating Boilers

NFPA 8502 Standard for the Prevention of Furnace Explosions/Implosions in

Multiple Burner Boilers


Ships Pt.4 Ch.7


ISO/R 831 Rules for construction of stationary boilers

TBK-1-2 General Rules for Pressure Vessels

Recognised codes for atmospheric vessels

API Spec 12 F Shop Welded Tanks for Storage of Production Liquids.

API 2000 Venting Atmospheric Storage Tanks

API Std 650 Welded Steel Tanks for Oil Storage.

DIN 4119 Tank installation of metallic materials

Recognised codes for heat exchangers

API Std 661 Air Cooled Heat Exchanger for General Refinery Services


Ships Pt.4 Ch.7


TEMA R Heat Exchanger Tubing

Recognised codes for pumps

ANSI 73.1/2 Centrifugal Pumps

API Std 610 Centrifugal Pumps for Petroleum, Heavy Duty Chemical and Gas

Industry Services

API Std 674 Positive Displacement Pumps - Reciprocating

API Std 675 Positive Displacement Pumps - Controlled Volume

API Std 676 Positive Displacement Pumps - Rotary


Ships Pt.4 Ch.1

Machinery System, General

Recognised codes for compressors

API Std 617 Centrifugal Compressors for Petroleum, Chemical and Gas Industry

Services.



Page 6

Code No. Title

API Std 618 Reciprocating Compressors for Petroleum, Chemical and Gas

Industry Services

API Std 619 Rotary Type Positive Displacement Compressors for Petroleum,

Chemical, and Gas Industry Services

API Std 672 Packaged, Integrally Geared Centrifugal Air Compressors for

Petroleum, Chemical, and Gas Industry Services


Ships Pt.4 Ch.5

Rotating Machinery, Driven Units

ISO 13707 Reciprocating compressors

Recognized codes for combustion engines

ISO 3046/1 Reciprocating Internal Combustion Engines

NFPA No 37 Stationary Combustion Engines and Gas Turbines


Ships Pt.4 Ch.3

Rotating Machinery, Drivers

EEMUA publication 107 Recommendations for the protection of diesel engines for use in zone

2 hazardous areas

Recognised codes for gas turbines

API Std 616 Gas Turbines for Petroleum, Chemical, and Gas Industry Services

ANSI B133.4 Gas Turbine Control and Protection Systems

ISO 2314 Gas Turbine Acceptance Tests

ASME PTC 22 Gas Turbine Power Plants

NFPA No 371975 Stationary Combustion Engines and Gas Turbines.


Ships Pt.4 Ch.3


Recognised codes for shafting


Ships Pt.4 Ch.4

Rotating Machinery, Power Transmissions

Recognised codes for gears

AGMA 218/219 Gear Rating

API Std 631 Special Purpose Gear Units for Refinery Service



Page 7

Code No. Title

DNV Classification Note

41.2

Calculation of gear rating for marine transmissions


Ships Pt.4 Ch.4


ISO 6336 Pt. 1-5 Gears

Recognised codes for couplings


Ships Pt.4 Ch.4

Rotating Machinery, Power Transmission

API Std 671 Special Purpose Couplings for Petroleum, Chemical, and Gas

Industry Services.

Recognised codes for lubrication and sealing

API Std 614 Lubrication, Shaft-Sealing and Control-Oil Systems and Auxiliaries for


Table Appendix 1.8: Applicable Standards/Codes for Fire Fighting

Code No. Title

DNV-OS-D301 Fire Protection


API RP 14G Recommended Practice for Fire Prevention and Control on Open

Type Offshore Production Platforms

NFPA 1 Fire Protection Code

ISO 13702 Control and Mitigation of Fires and Explosions on Offshore

Installations.

SOLAS International Convention of the Safety of Life at Sea

Table Appendix 1.9: Recognised Codes for Pumps

Code No. Title

NFPA 20 Stationary Fire Pumps for Fire Protection



Industry Services



Page 8

Code No. Title





Ships Pt.4 Ch.1


Table Appendix 1.10: Recognised Codes for Lifting

Code No. Title

API 2C Specification for Offshore Cranes

DNV Rules DNV Rules for Lifting Appliance

Table Appendix 1.11: Applicable Standards/Codes for Process Systems

Code No. Title

NFPA 59A Standard for the Production, Storage, and Handling of Liquefied

Natural Gas

DNV OS A101 Safety and Arrangement

DNV OS E201 Hydrocarbon Production Plant

API RP 14C Analysis, Design, Installation and Testing of Basic Surface Safety

Systems for Offshore Production Platforms

Process Plant Equipment

TEMA Tubular Exchanger Manufacturers Association

NFPA 37 Standard for the Installation and Use of Stationary Combustion

Engines and Gas Turbines

ASME VIII Boiler and Pressure Vessel Code

API RP 520 Sizing, Selection and Installation of Pressure Relieving Devices in

Refineries

API RP 521 Guide for Pressure Relieving and Depressurising Systems

API Std 537 Flare Details for General Refinery and Petrochemical Service


Industry Services



Page 9

Code No. Title

API Std 6D Specification for Pipeline Valves

API Std 617 Axial and Centrifugal Compressors and Expander Compressors for

Petroleum, Chemical and Gas Industry Services


Industry Services


Chemical and Gas Industry Services

Process Piping

ASME B31.3 Pressure Piping

API 14E Design and Installation of offshore production platform piping systems

ASME B31.8 Gas Transmission and Distributing Piping Systems ASME Code for

Pressure Piping

Fuel Gas System

IGC Code International Code for the Construction and Equipment of Ships


DNV OD D101 Marine and Machinery Systems and Equipment

Table Appendix 1.12: Applicable Standards/Codes for LNG Tanks

Code No. Title


Carrying Liquefied Gases in Bulk (IGC Code)

Class Rules DNV Rules for Liquefied Gas Carriers, Pt. 5 Ch. 5

Supplemental text In-service inspection and monitoring to be allowed.


Natural Gas (LNG)

33 CFR Part 127 Waterfront facilities handling liquefied natural gas and liquefied

hazardous gas.

Table Appendix 1.13: Applicable Standards/Codes for Loading Arms

Code No. Title

NFPA 59A (Chap 8) Standard for Production, Storage and handling of Liquefied Natural



Page 10

Code No. Title

Gas

OCIMF Design and Construction Specification for Marine Loading Arms

SIGTTO/ICS/OCIMF Ship to Ship Transfer Guide (Liquefied Gas)

ICS Tanker Safety Guide (Liquefied Gas)

SIGTTO Liquefied Gas Handling Principles on Ships and in Terminals

OCIMF Mooring Equipment Guidelines

Table Appendix 1.14: Applicable Standards/Codes for Re-Gasification System (Cargo Pump System)

Code No. Title

NFPA 59A Standard for Production, Storage and handling of Liquefied Natural

Gas

API RP 14C Recommended Practice for the Analysis, Design Installation and

Testing of Basic Surface Safety Systems for Offshore Production

Platforms

API RP 520 Sizing, Selection, and Installation of Pressure Relieving Devises in

Refineries.

ASME B31.3 Process Piping

Table Appendix 1.15: Applicable Standards/Codes for Electrical & Instrumentation

Code No. Title

46 CFR 110-113 Subchapter J-electrical engineering

DNV-OS-A101 Safety principles and arrangements

DNV-OS-D201 Electrical installations

DNV-OS-D202 Instrumentation and telecommunications systems

IEC 60092-502 Tankers – Special features

API RP 14C Recommended practice for analysis, design, installation, and testing of

basic surface systems for offshore production platforms

API RP 14F Recommended Practice for Design and Installation of Electrical

Systems for Fixed and Floating Offshore Petroleum Facilities for

Unclassified and Class I, Division 1 and Division 2 Locations



Page 11

Code No. Title

API RP 14FZ Design and Installation of Electrical Systems for Fixed & Floating

Offshore Petroleum Facilities for Unclassified and Class I, Zone 0,

Zone 1 and Zone 2 Locations

API 500 Recommended Practice for Classification of Locations for Electrical

Installations at Petroleum Facilities


Installations at Petroleum Facilities Classified as Class I, Zone 0, Zone

1 and Zone 2


Natural Gas (LNG)

NFPA 70 National Electrical Code (Onshore parts of project, offshore only article

505)

IEC 61508 Functional safety of electrical/electronic/programmable safety-related

systems (ESD, PSD, F&G etc – Effects hardware selection – vendor

requirements)

IEC 61511 Functional safety – Safety instrumented systems for the process

industry sector (ESD, PSD, F&G etc – System user & designer

considerations)

IEC 50091 Uninterruptible Power Supply Systems

IEC 60034 Rotating Electrical Machines

IEC 60038 IEC Standard Voltage

IEC 60050 International Electrotechnical Vocabulary

IEC 60056 High-voltage alternating-current circuit-breakers

IEC 60076 Power Transformers

IEC 60079 Electrical Apparatus for explosive gas atmospheres

IEC 60099 Surge arrestors

IEC 60146 Semiconductor converters

IEC 60269/BS 88 Low Voltage Fuses

IEC 60287 Electric cables –Calculations of the current ratings

IEC 60298 AC metal-enclosed switchgear and control gear for rated voltages

above 1-kV and up to and including 52-kV



Page 12

Code No. Title

IEC 60309 Plugs socket outlets and couplers for industrial and explosive gas

atmospheres

IEC 60331 Fire Resisting Characteristics of Electrical Cables

IEC 60332 Test on Electrical Cables under Fire Conditions

IEC 60354 Loading guide for power transformers

IEC 60439 Low-voltage switchgear and control gear assemblies

IEC 60502 Extruded solid dielectric insulated power cables for rated voltages from

1-kV up to 30-kV.

IEC 60529 Degrees of protection provided by enclosures

IEC 60598 Luminaires

IEC 60617 Graphical Symbols

IEC 60909 Short circuit calculations in 3-phase AC systems

IEC 61000 Electromagnetic compatibility (EMC)

ISO 1461 Hot Dip Galvanized Coatings on Fabricated Iron and Steel Articles –

Spec Test Methods

ATEX Manufacturer's Directive 94/9/EC (ATEX 100a/95)

ATEX User Directive 99/92/EC (ATEX 137)

EMC Directive 89/336/EEC (including Directive 91/263/EEC)

AGA Report No. 3 Orifice Metering of Natural Gas and Other Related Hydrocarbon

Fluids, Part 2, Specification and Installation Requirements

AGA Report No. 5 Fuel Gas Energy Metering

AGA Report No. 8 Compressibility Factor of Natural Gas and Related Hydrocarbon

Gases

AGA Report No. 9 Measurement of Gas by Multi-path Ultrasonic Meters

ANSI/FCI 70.2 Control Valve Seat Leakage

ISA S5.1 Instrumentation Symbols and Identification

ANSI/ISA 51.1 Process Instrumentation Terminology

ISA 18.1 Annunciation Sequences & Specifications



Page 13

Code No. Title

ANSI/IEEE C37.1 Specification used for Supervisory Control, Data Acquisition & Control

ANSI/ISA 75.01.01 (IEC

60534-2Mod)

Flow Equations for Sizing Control Valves

ANSI/ISA 75.08.01 Face-to-Face Dimensions for Integral Flanged Globe-Style Control

Valve Bodies (ANSI Classes 125, 150, 250, 300, & 600)

ANSI/ISA 75.08.06 Face-to-Face Dimensions for Flanged Globe-Style Control Valve

Bodies (ANSI Classes 900, 1500, & 600)

ANSI/ISA 75.22 Face-to-Centreline Dimensions for Flanged Globe-Style Angle Control

Valve Bodies (ANSI Classes 150, 300)

API SPEC 6D Specification for Pipeline Valves (Gate, Plug, Ball, and Check Valves)

API SPEC 6FA Specification for Fire Tests for Valves



API RP 520, Part l Sizing, Selection and Installation of Pressure Relieving Systems in

Refineries, Sizing and Selection

API RP 520, Part ll Sizing, Selection and Installation of Pressure Relieving Systems in

Refineries, Installation

API STD 526 Flanged Pressure Relief Valves

API STD 527 Commercial Seat Tightness of Pressure Relief Valves with Metal to

Metal Seats

API RP 551 Process Measurement Instrumentation

API RP 552 Transmission Systems

API RP 554 Process Instrumentation and Control

API RP 555 Process Analyzers

API STD 598 Valve Inspection & Testing

API STD 600 Bolted Bonnet Steel Gate Valves for Petroleum & Natural Gas

Industries

API STD 609 Butterfly Valves Double Flanged, Lug & Wafer Type.

API STD 670 Machinery Protection Systems

API STD 2000 Venting Atmospheric & Low-Pressure Storage Tanks – Non-



Page 14

Code No. Title

refrigerated & Refrigerated

ASME B16.5 Pipe Flanges and Flanged Fittings

ASME B16.10 Face-to-Face & End-to-End Dimensions of Valves

ASME B46.1 Surface Texture, Surface Roughness, Waviness, & Lay

ASME B1.20.1 Pipe Threads, General Purpose


ASME PTC 19.3 Temperature Measurement

ASTM A269-04 Standard Specification for Seamless & Welded Austenitic Stainless

Steel Tubing for General Service

ASTM D 1250-4 Standard Guide for Use of the Petroleum Measurement Tables

EEMUA Publication 140 Noise Procedure Specification Guidelines

EEMUA Publication 191 Alarm Systems – A Guide to Design Management & Procurement

EEMUA Publication 201 Process Plant Control Desks Utilizing Human-Computer Interfaces – A

Guide to Design, Operational and Human Interface Issues

EIA/TIA (RS) 232 Data Communication Interface Standard



EN 10204 Metallic Products – Types of Inspection Documents

EN 50081 Electromagnetic Compatibility: Generic Emission Standard

EN 50082 Electromagnetic Compatibility: Generic Immunity Standard

EN 50170 General purpose field communication system

GPA Standard 2145-03 Table of Physical Constants for Hydrocarbons and Other Components

of Interest to the Natural Gas Industry

GPA Standard 2261-00 Analysis for Natural Gas and Similar Gaseous Mixtures by Gas

Chromatography

IEC 60079-0 Electrical Apparatus for Explosive Gas Atmospheres, Part 0: General

Requirements

IEC 60079-1 Electrical Apparatus for Explosive Gas Atmospheres, Part 1:

Flameproof enclosures ―d‖



Page 15

Code No. Title


Pressurized enclosures ―p‖


Increased Safety ‗e‘

IEC 60079-11 Electrical Apparatus for Explosive Gas Atmospheres, Part 11: Intrinsic

Safety ―i‖


Encapsulation ―m‖

IEC 60189 Low-frequency cables and wired with PVC insulation and PVC Sheath

IEC 60227 Polyvinylchloride insulated cables of rated voltages up to and including

450/750 V

IEC 60269 Low Voltage Fuse with High Breaking Capacity



IEC 60529 Degrees of Protection Provided by Enclosures (IP Code)

IEC 60584-3 Thermocouples. Part 3: Extension and compensating cables –

Tolerances and identification system

IEC 60708 Low-frequency cables with polyolefin insulation and moisture barrier

polyolefin sheath

IEC 60751 Industrial Platinum Resistance Thermometer Sensors

IEC 60947-5-6 Low-voltage switchgear and control gear – Part 5-6: Control circuit

devices and switching elements – DC interface for proximity sensors

and switching amplifiers (NAMUR)

IEC 61000 Electromagnetic Compatibility

IEC 61131-3 Programmable controllers – Part 3: Programming languages

IEC 61158 Digital data communications for measurement and control – Fieldbus

for use in industrial control systems

IEC 61508 Functional Safety of Electrical/Electronic/Programmable Electronic

Safety Related Systems

IEC 61511 Functional Safety – Safety instrumented systems for process industry

sector



Page 16

Code No. Title

JIS C3410 JIS marine cable

IEEE 802.1 Overview of Local Area Network Standards

IEEE 802.3 Carrier Sense Multiple Access with Collision Detection (CSMA/CD)

IEEE 802.4 Token-passing bus access method and physical layer specification

ISO 1000 SI units and recommendations for use of their multiples and of certain

other units

ISO 5167 Measurement of Fluid Flow by means of Pressure Differential Devices

inserted in Circular Cross-Section Conduits Running Full. Parts 1 to 4.

ISO 5168 Measurement of Fluid Flow – Evaluation of Uncertainties

ISO 5208 Industrial Valves – Pressure Testing of Valves

ISO 5209 General purpose industrial valves – marking

ISO 5210 Industrial Valves – Multi-turn Valve Actuator Attachments

ISO 5211 Industrial Valves – Part-turn Actuator Attachment

ISO 6551 Petroleum Liquids and Gases – Fidelity and Security of Dynamic

Measurement – Cabled Transmission of Electric and/or Electric Pulsed

Data

ISO 6976 Natural Gas – Calculation of Calorific Value, Density and Relative

Density & Wobbe index from composition

ISO/CD 10715 Natural Gas, Sampling Guidelines

ISO 7278-3 Liquid Hydrocarbons – Dynamic measurement - Proving systems for

volumetric meters Part 3 – Pulse Interpolation Techniques

ISO 9000 -9004 Quality Management Systems

ISO 10790 Measurement of fluid in closed conduits: Guidance to the selection,

installation and the use of Coriolis Meters.

MSS SP-67 Butterfly Valves

MSS SP-68 High Pressure – Offset Seat Butterfly Valves

MSS SP-112 Quality Standard for Evaluation of Cast Surface Finishes – Visual &

Tactile Method

MSS SP-25 Standard Marking System for Valves Fittings, Flanges and Unions



Page 17

Code No. Title

NFPA 72E – 4 Automatic Fire Detectors

NFPA 85 Boiler and Combustion Systems Hazards Code

NACE MR-01-75 Sulfide Stress Cracking Resistant Materials for Oil Field Equipment

Table Appendix 1.16: Applicable Standards/Codes for Life Saving Appliances

Code No. Title

LSA Code International Life-Saving Appliance Code (Res. MSC.48(&&)) and

Testing and Evaluation of Life-Saving Appliances (Res. MSC.81(70))

SOLAS Ch. 3, reg. 31 (for the free fall life boat)

Safety Case A TEMPSC (temporary refuge) review shall be part of safety case.

Table Appendix 1.17: Applicable Standards/Codes for Mooring

Code No. Title

API RP 2SK Recommended Practice for Design and Analysis of Station keeping

Systems for Floating Structures

API RP 2FP1 Recommended Practice for Analysis, & Maintenance of Catenary

Moorings for Floating Production Facilities

DNV-OS-E301 Offshore Standard, Position Mooring (DNV POSMOOR use of fatigue

T-N fatigue curves on stud-less chain as supplement for API RP

2SK)

Cert Note 2.5 DNV Certification Note for Offshore Mooring Steel Wire Ropes

Cert Note 2.6 DNV Certification Note for Offshore Mooring Chain

API RP 2A Recommended Practice for Planning, Designing and Constructing

Fixed Offshore Platforms

DNV-RP-C203 Fatigue Strength Analysis of Offshore Steel Structures

Table Appendix 1.18: Applicable Standards/Codes for PLEMs

Code No. Title


Fixed Offshore Platforms (structural design)

ASME Boiler and Pressure Vessel Code Section VIII &IX and B 31.8



Page 18

Code No. Title


NACE RP 01-76- 94 Cathodic Protection. (Supplement by DNV- RP-F103 for sacrificial

anode design)

AISC Manual of Steel Construction (for PLEM frame)

DNV CN 30.4 Foundations (for geotechnical design of PLET)

Other codes Piping, valves and electric are to be the same as topside plant

(subsea valve specification per API 6D and ASME B16.34. Electrical

and control specifications are located in their respective section.)

API Spec 5L Line Pipe Specification

API Spec 6AF Fire Test for valves

API Spec 6A Specification for Wellhead and Christmas Tree Equipment

API Spec 6H Specification for End Closures, Connectors, and Swivels

API RP 17A Recommended Practice for Design and Operation of Subsea

Production Systems

API Spec17D Subsea Wellhead and Christmas Tree Equipment (use as

supplement as needed for overpressure protection)

API Std 1104 Welding of Pipelines and Related Facilities

API RP 1110 Pressure Testing of Liquid Petroleum Pipelines

API RP 1111 Design, Construction, Operation and Maintenance of Offshore

Hydrocarbon Pipelines

AWS D1.1 American Welding Society, Structural Welding Code

DNV RP-F103 Cathodic Protection Design

ISO 13628 Part 8 Design and Operation of ROV Interfaces on Subsea Production

Systems

NACE MR-01-75 Sulfide Stress Cracking Resistant Metallic Materials for Oilfield

Equipment

NAS 1638 Cleanliness Requirements for Components used in Hydraulic

Systems

Table Appendix 1.19: Applicable Standards/Codes for Offshore Pipelines

Code No. Title



Page 19

Code No. Title

API Spec 5L Specification for Line Pipe

API 1104 Standard for Welding Pipelines and Related Facilities

API RP 5L1 Recommended Practice for Railroad Transportation of Line Pipe

API RP 5LW Recommended Practice for Transportation of Line Pipe on Barges

and Marine Vessels

API 17D Appendix D, Procedure for the Application of a Coating System


of Basic Surface Safety System

ASTM E3 Standard Methods of Preparation of Metallographic Specimens

ASTM E142 Method for Controlling Quality of Radiographic Testing

ASTM E146 Practice for Ultrasonic Contact Examinations of Weldments

ASTM A370 Standard Methods for Testing Metallic Material

ASTM E747 Test Method for Controlling Quality of Radiographic Testing Using

Wire Penetrometers

ASTM E94 Radiographic Testing (welding NDE)

ASTM D 3748 Practice for Evaluating High-Density Rigid Cellular Thermoplastics

(FBE)

ASTM D 4417 Test Method for Field Measurement of Surface Profile of Blast

Cleaned Steel (FBE)

SSPC-SP-1 Solvent Cleaning (coating prep)

SSPC-SP-10 Near-White Blast Cleaning (coating prep)

SSPC-Vis 1-89 Pictorial Surface Preparation Standard (coating prep)

NACE RP 490 Holiday Detection of Fusion Bonded Epoxy External Pipeline

Coatings of 10 to 30 mils (0.25 to 0.76 mm)

NACE RP 394 Recommended Practice for Application, Performance and Quality

Control of Plant-Applied Fusion-Bonded Epoxy External Pipe Coating

NACE RP 287 Recommended Practice for Field Measurement of Surface Profile of

Abrasive Blast Cleaned Steel Surfaces Using a Replica Tape

ASME B16.5 Flanges (direct reference by CFR 192)



Page 20

Code No. Title

ASME B31.8 Gas Transmission and Distribution Piping Systems ASME Code for

Pressure Piping

DNV OS-F201 Dynamic Risers (i.e. API 17B, J, etc are in base listing)

DNV-OS-F101 Submarine Pipeline Systems (limit state design option to B31.8/ API

5L)

DNV RP E305 On-Bottom Stability Design of Submarine Pipelines

IS 1893:2002 Criteria for Earthquake resistant Design of Structure

DNV-RP-F102 Field Joints Coating System

DNV-RP-F106 Anti-Corrosion Coating System

DNV-CN-30.5 Environmental Conditions and. Environmental Loads

API RP 1110 Pressure Testing of Liquid Petroleum Pipelines

API RP 1111 Design, Construction, Operation and Maintenance of Offshore

Hydrocarbon Pipelines (limit state design option to B31.8)

API 1104 Welding of Pipelines and Related Facilities Qualification of welders

and welding procedures Inspection and testing of welds Procedures

for non-destructive testing Acceptance standards for NDT

NACE RP-0675 Control of External Corrosion on Offshore Steel Pipelines

ASNT SNT-TC-1A Recommended Practice, Personnel Qualification and Certification in

Nondestructive Testing

API 5L Specification for Line Pipe

ASCE Guidelines for the Design of Buried steel Pipe, July 2001

UBC/IBC Uniform Building Code/International Building Code

Table Appendix 1.20: Applicable Standards/Codes for Installation

Code No. Title

API RP 2FPS Recommended Practice for Planning, design and Construction

Floating Production Systems

API RP 2RD Design of Risers for Floating Production Systems

DNV Rules for Planning and Execution of Marine operations, January 2000



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Table Appendix 1.21: Applicable Standards/Codes for In-service Operations

Code No. Title


Other codes SIGTTO, ICS, API RP70 (Security) are covered in their respective

section.

Table Appendix 1.22: General Mechanical (see sections for base listing)

Reference Title/Comments

API RP 5LW Recommended Practice for Transportation of Line Pipe on Barge and

Marine Vessels

ASME B31.5 Refrigeration Piping and Heat Transfer Components

ASME IX Qualification standard for welding and brazing procedures, welders,

brazers, and welding and brazing operators

ASME V Non Destructive Examination



Table Appendix 1.23: General Structural (see sections for base listing)

Reference Title

AWS D1.1 Structural Welding Code

AWS A5.1-23 AWS Filler Metal Specifications



ASNT CP-189 Qualification and Certification of Nondestructive Testing Personnel

Table Appendix 1.24: Painting and Corrosion Protection

Reference Title

OSHA-2206 General Industry Safety and Health Standards

ISO 8501 Preparation of steel substrates before application of paints and related

products -- Visual assessment of surface cleanliness

SSPC-SP1 Solvent Cleaning

SSPC-SP2 Hand Tool Cleaning



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SSPC-SP3 Power Tool Cleaning

SSPC-SP5 White Metal Blast Cleaning

SSPC-SP6 Commercial Blast Cleaning

SSPC-SP7 Brush-Off Blast Cleaning

SSPC-SP8 Surface Preparation Spec. No.8, Pickling

SSPC-SP10 Near-White Blast Cleaning

SSPC-SP11 Power Tool Cleaning to Bare Metal

SSPC-PA-1 Shop, Field & Maintenance Painting

SSPC-PA-2 Measurement of Dry Coating Thickness with Magnetic Gauges

SSPC-PA-3 Paint Application No.3, A Guide to Safety

SSPC-Guide to VIS-1-89 Visual Blast Standards/Pictorial Surface Preparation

SSPC-Guide to VIS-2 Standard Method of Evaluation of Rust

ASTM A123 Zinc (Hot Galvanized) Coatings on Products Fabricated from Rolled,

Pressed and Forged Steel Shapes, Plates, Bars, and Strip

ASTM D 3363 Film Hardness by Pencil Test

ASTM D 714 Method for Evaluating Degree of Blistering of Paint

ANSI 253.1 Safety Color Code for Marking Physical Hazards

ASTM A143 Safeguarding Against Embrittlement of Hot-Dip, Galvanized Structural

Steel Products

ASTM A153 Zinc Coating (Hot Dip) on Iron and Steel Hardware

NACE RP-0176 Corrosion Control of Steel, Fixed Offshore Platforms Associated with

Petroleum Production





Appendix 2 Meteorological Data





Not yet available





Appendix 3 Field Layout Drawing

Attachment 03 - SRT Scope of Work


Jamaica LNG Project SRT Scope of Work

402010-00260 – 00-GE-SOW-0004

26 August 2011

GOVERNMENT OF JAMAICA: OFFICE OF THE CABINET JAMAICA LNG PROJECT SRT SCOPE OF WORK

Page ii

CONTENTS

1 INTRODUCTION ................................................................................................................ 2

1.1 Background ......................................................................................................................... 2

1.2 Document Overview ........................................................................................................... 2

1.3 Nomenclature ...................................................................................................................... 2

1.4 Definitions ........................................................................................................................... 4

2 PROJECT OVERVIEW AND MAIN FEATURES ................................................................ 6

3 COMPANY’S ROLE AND RESPONSIBILITIES ................................................................. 7

3.1 General ............................................................................................................................... 7

3.2 Personnel ............................................................................................................................ 7

3.3 Representative .................................................................................................................... 7

4 CONTRACTOR’S ROLE AND RESPONSIBILITIES .......................................................... 8

4.1 General ............................................................................................................................... 8

4.2 Endorsement of COMPANY Supplied Information ............................................................. 9

4.3 Pre-Engineering Surveys .................................................................................................. 10

4.4 Metocean Data .................................................................................................................. 10

4.5 Geotechnical and Geophysical Data ................................................................................ 11

4.6 Facility Uptime Assessment .............................................................................................. 11

4.7 Construction and Commissioning Scope Interfaces ......................................................... 14

4.8 Conformance of the Work ................................................................................................. 14

5 HSE MANAGEMENT ........................................................................................................ 16

6 ENVIRONMENTAL DESIGN PHILOSOPHY ................................................................... 17

6.1 General ............................................................................................................................. 17

6.2 Environmental Management ............................................................................................. 17

6.3 Community Engagement and Interface Management ...................................................... 17

7 MANAGEMENT AND ADMINISTRATION........................................................................ 19

7.1 General ............................................................................................................................. 19

7.2 Project Management ......................................................................................................... 19

7.2.1 General ................................................................................................................ 19


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7.2.2 Project Execution Plan ......................................................................................... 20

7.2.3 Communication Plan ............................................................................................ 20

7.2.4 Engineering Management .................................................................................... 20

7.2.5 Fabrication Management ..................................................................................... 21

7.2.6 Mechanical Completion and Commissioning Management ................................. 22

7.2.7 Installation Management ...................................................................................... 22

7.2.8 Information Management ..................................................................................... 24

7.2.9 Interface Management ......................................................................................... 24

7.2.10 External Interface Responsibilities ....................................................................... 25

7.2.11 Operations Readiness Management ................................................................... 25

7.2.12 Operator Training ................................................................................................. 26

7.3 Quality Assurance and Quality Control ............................................................................. 26

7.3.1 General ................................................................................................................ 26

7.3.2 Quality Actions Prior to Commencement of the Work ......................................... 27

7.3.3 Quality Plan for the Entire Work ........................................................................... 27

7.3.4 Testing Equipment ............................................................................................... 28

7.3.5 Auditing ................................................................................................................ 28

7.4 Codes and Standards ....................................................................................................... 29

7.5 Office Facilities for Company’s Personnel at the Sites(s) ................................................. 29

7.6 Errors & Omissions ........................................................................................................... 29

7.7 Hierarchy of Technical Documents ................................................................................... 29

8 ENGINEERING ................................................................................................................. 30

8.1 General ............................................................................................................................. 30

8.2 Detailed Design & Engineering ......................................................................................... 30

8.3 Engineering Design Codes ............................................................................................... 31

8.4 Operations Involvement .................................................................................................... 31

8.5 Safety Engineering............................................................................................................ 31

8.5.1 Design Safety Assessment .................................................................................. 32

8.5.2 HAZOP for SRT ................................................................................................... 33

8.5.3 Waterway Suitability Assessment ........................................................................ 34


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8.6 Classification, Certification & Registration ........................................................................ 34

8.6.1 General ................................................................................................................ 34

8.6.2 Classification Society and Certification ................................................................ 36

8.6.3 Certification .......................................................................................................... 36

8.6.4 Government Certification and Permits ................................................................. 37

8.6.5 Registration .......................................................................................................... 37

8.7 Hull Structure Analysis ...................................................................................................... 37

8.7.1 General ................................................................................................................ 38

8.7.2 Mooring Analysis .................................................................................................. 38

8.7.3 Model Testing....................................................................................................... 39

8.7.4 Trim and Stability ................................................................................................. 40

8.8 Materials and Workmanship ............................................................................................. 40

8.9 Maintenance Philosophy ................................................................................................... 41

8.10 Sparing and Obsolescence .......................................................................................... 41

8.11 Documentation, Measuring Units and Language ......................................................... 42

8.11.1 Drawings and Documents for Approval ............................................................... 42

8.11.2 Measurement Unit and Language........................................................................ 46

8.12 As-Built Documentation ................................................................................................ 46

8.12.1 General ................................................................................................................ 46

8.12.2 As-built Procedures .............................................................................................. 46

8.12.3 As-built Registers ................................................................................................. 47

8.12.4 Schedule .............................................................................................................. 47

8.12.5 Vendor Data ......................................................................................................... 47

8.12.6 Final Documentation ............................................................................................ 47

9 PROCUREMENT AND EQUIPMENT HANDLING ........................................................... 49

9.1 Procedures ........................................................................................................................ 49

9.2 Procurement Plan ............................................................................................................. 49

9.3 Procurement Master Schedule ......................................................................................... 49

9.4 Materials Management ..................................................................................................... 50

9.5 Subcontractors and Vendors ............................................................................................ 50


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9.6 Import/Export .................................................................................................................... 50

10 MECHANICAL COMPLETION, TESTING AND TRIALS ................................................. 52

10.1 General ......................................................................................................................... 52

10.2 Hull and Deck ............................................................................................................... 53

10.3 Machinery and Cargo Systems .................................................................................... 53

11 SRT TRANSPORTATION, INSTALLATION, HOOKUP, TESTING, COMMISSIONING AND OPERATION .................................................................................................................................... 55

11.1 Transportation .............................................................................................................. 55

11.2 Installation .................................................................................................................... 55

11.2.1 General ................................................................................................................ 55

11.2.2 Installation Requirements .................................................................................... 55

11.3 Performance Testing .................................................................................................... 56

11.4 Commissioning ............................................................................................................. 56

11.5 As-Built Survey ............................................................................................................. 57

11.6 Operation of SRT ......................................................................................................... 57

12 REFERENCES ................................................................................................................. 58


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1 INTRODUCTION

1.1 Background

In order to improve its international competitiveness and reduce its dependence on imported petroleum, the Government of Jamaica (GOJ) has implemented a strategy to diversify its energy supply. The strategy aims at introducing imported natural gas into Jamaica’s energy supply mix to obtain security of supplies and achieve long-term stability in energy prices and environmental sustainability in energy provision.

Under this strategy, it is proposed to import liquefied natural gas (LNG) to Jamaica under long-term contractual arrangements and re-gasify it to initially meet the needs of power generation and bauxite/alumina production. The initial estimate of demand in these sectors is equivalent to about 0.8 million tonnes of LNG per year, with the expansion of the bauxite/alumina sector and construction of new IPPs likely to raise the base LNG demand to around 2.5 million tonnes per year. It is expected that the importation of LNG will help to spur additional industrial and commercial growth that would benefit from the availability of natural gas and lower energy prices.

The Government of Jamaica, acting on behalf of the Jamaica Gas Trust (‘the COMPANY’) is seeking to develop a Liquefied Natural Gas (LNG) Storage and Regasification Terminal (SRT) and natural gas export system in Jamaica (‘the PROJECT’) on a Build-Own- Operate-Transfer (BOOT) basis.

1.2 Document Overview

The Jamaica LNG Project facilities comprise:

a) Storage and Regasification Terminal (SRT);

b) Gas Transmission Pipeline;

c) Onshore Receiving Facility (ORF).

This document addresses only the SRT Scope of Work. It is intended to be reviewed in conjunction with the Basis of Design [1] documentation and relevant specifications. Bidders shall strictly follow the Basis of Design requirements. Any deviations to the BOD shall be clearly spelt out in the Technical Bids.

1.3 Nomenclature

To ensure consistency, the following nomenclature has been used where applicable throughout this document and other parts of the Contract Documents. All other abbreviations will in the first occurrence include a full description.



AFC Approved for Construction


Page 3


ALARP As Low As Reasonably Practicable



ASTM American Society for Testing Materials

BOD Basis of Design

BOOT Build-Own-Operate-Transfer

DBB Double Block & Bleed

C&E Cause & Effect

CP Cathodic Protection

DCS Distributed Control System


ECS Engineering Consultant Services

EIA Environmental Impact Assessment

EMMP Environmental Monitoring and Management Plan

ESD Emergency Shutdown

FAT Factory Acceptance Test

F&G Fire & Gas


GOJ Government of Jamaica

GSA Gas Sales Agreement

HAZID Hazard Identification

HAZOP Hazard and Operability

HIPPS High Integrity Pressure Protection System

HSE Health Safety Environment

HVAC Heating Ventilation Air Conditioning

HX Heat Exchanger

ISO International Organisation for Standards

ITP Inspection and Test Plan


Page 4


km kilometre


m metre

MAOP Maximum Allowable Operating Pressure

MMscfd MM (=106) Standard Cubic Feet per Day

MR Material Requisition

MSS Manufacturers Standardisation Society

MTPA Millions of Tonnes per Annum

MTO Material Take-Off


P&ID Piping and Instrument Diagram


PDMS Plant Design Management System

PFD Process Flow Diagram

PHA Process Hazard Analysis

PL Pressure Letdown

PMC Project Management Consultant

ppm Parts Per Million

PSC Production Sharing Company

psig pounds per square inch (gauge pressure)

RFQ Request For Quotation

RTU Remote Transmission Unit

SIMOPS Simultaneous Operations

UPS Uninterruptable Power Supply

VDU Visual Display Unit

1.4 Definitions



Page 5






The words “will”, “may”, “should”, “shall” and “must” have specific meaning as follows:-

“Will” is used normally in connection with an action by the COMPANY rather than by CONTRACTOR.

“May” is used where alternatives are equally acceptable.

“Should” is used where a provision is preferred.

“Shall” is used where a provision is mandatory.


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2 PROJECT OVERVIEW AND MAIN FEATURES

The COMPANY has completed concept engineering for the SRT, Pipeline and ORF, and on this basis intends to precede with the bidding process for the facility Build-Own-Operate-Transfer (BOOT) Contracts.

This document outlines the scope of work and requirements for the SRT BOOT Contract, hereinafter referred to as “the WORKS”.

The base design case for the SRT is an FSRU moored at a near shore, dual-berth jetty. The CONTRACTOR may choose to consider alternative mooring arrangement/terminal designs subject to compliance with design requirements detailed in this document and positive cost-benefit analysis relative to the base option. In the event an alternative mooring arrangement is proposed, the CONTRACTOR must demonstrate that the LNG supplier ‘super-majors’, particularly those active in the region these being BP, BG and Shell, will submit to mooring their LNGC vessels at the facility.

Refer to BOD [1] and relevant functional specifications and philosophies for details.


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3 COMPANY’S ROLE AND RESPONSIBILITIES

3.1 General

Involvement by COMPANY personnel is principally to monitor compliance with the requirements of the Contract, supervise fabrication and installation activities, and to verify the overall quality of the Work being provided.

Furthermore, COMPANY pursues the highest standards of safety and environmental practices and can offer guidance to CONTRACTOR in these areas.

3.2 Personnel

COMPANY will assign relevant personnel to monitor that the CONTRACTOR has completed all required activities prior to the relevant to construction, and until CONTRACTOR has fulfilled the Provisional Acceptance requirements (i.e. design, fabrication, transportation, installation, and commissioning). COMPANY will develop a program of formal assessment for onsite inspections to ensure that there is full compliance with its requirements. .

3.3 Representative

Throughout the Project execution, COMPANY will have representatives at the fabrication yards, onboard installation spread and onsite for installation. These representatives will act as the contact point for CONTRACTOR in all matters relating to the fabrication and preparation for onshore and offshore activities.


Page 8

4 CONTRACTOR’S ROLE AND RESPONSIBILITIES

4.1 General

CONTRACTOR shall manage and execute all activities to ensure satisfactory performance and completion of the WORK in all respects in accordance with the provisions of the Contract and in good offshore oil & gas industry practice. CONTRACTOR shall ensure that COMPANY is fully informed regarding the planned and actual status of all work activities at all times. CONTRACTOR shall promptly take pre-emptive and corrective actions required correcting or avoiding actual and potential deviations from the Contract requirements and objectives.

CONTRACTOR shall have an efficient management organization, fully supported by effective systems and procedures, to ensure all WORK is performed to fully meet the quality, schedule, safety, environmental and other requirements of the Contract. During the WORK, CONTRACTOR shall prepare the SRT for service as described in this scope of works and in accordance with the Contract Master Schedule, and the provisions of the Contract.

Sixty (60) days prior to Provisional Acceptance, CONTRACTOR shall submit a copy of the Operating Manual for the SRT to COMPANY for approval.

CONTRACTOR shall provide all labour, equipment, materials and consumables required for the detailed engineering, procurement, construction, mechanical completion, transportation, installation, hook-up, testing, commissioning, performance testing and operation of the SRT. The SRT shall be capable of pre-commissioning and commissioning independently in the fabrication yard prior to mobilisation to the site location.

Activities shall include, but not be limited to:

a) Receipt and Technical Review of COMPANY Furnished Material and COMPANY Supplied Data;

b) Engineering (all disciplines);

c) Procurement of all materials and equipment for the Work;

d) Collection and transportation of regasification plant from their fabrication locations to the fabrication yard;

e) Fabrication and/or conversion/upgrade and work, mechanical completion and testing;

f) Quality assurance;

g) Quality control;

h) Co-ordination with supplier’s representatives;

i) Interface and co-ordination with other COMPANY’s contractors;

j) Onshore testing, inspection and pre-commissioning;

k) Gas trials at full capacity in accordance with SIGTTO guidelines;


Page 9

l) Transportation of the SRT to the installation site;

m) Provision of commissioning and operating manuals;

n) Provision of inspection, maintenance and repair manuals;

o) Provision of Marine Insurance Surveyor work;

p) Provision of Authority and Regulator’s approvals;

q) Provision of certification dossiers;

r) Manning, operation and maintenance of facilities in accordance with applicable Jamaican & international regulatory/permitting requirements, COMPANY approved operating procedures and within the terms of end-user supply agreements;

s) Training of COMPANY operations’ personnel prior to facility transfer.

CONTRACTOR shall, for the duration of the WORK, assign qualified and experienced personnel, facilities, equipment, supervision, tools and all materials, supplies, and other resources required to progress the WORK in accordance with the Contract Schedule and to the quality defined in this Contract.

CONTRACTOR shall also obtain all Classification Society certificates and permits required by Jamaican Governmental Authorities that can be obtained in the name of CONTRACTOR, and assist COMPANY to obtain such licenses and permits that are only obtainable in the name of COMPANY. Calibration certificates shall be obtained in accordance with Jamaican regulations.

CONTRACTOR shall be responsible for employing services from qualified inspectors and consultants necessary for obtaining certificates and permits from the Classification Society. All material and equipment supply, fabrication and installation activities shall be in accordance with drawings, specifications, reports and procedures issued by CONTRACTOR and approved by COMPANY. No deviations to COMPANY Supplied Data or CONTRACTOR issued engineering data approved by COMPANY are to be made by CONTRACTOR without prior written approval from COMPANY.

Any documentation not provided by COMPANY that is manifestly necessary for the full performance of the WORK, shall be provided and incorporated into the Work at the expense of CONTRACTOR to the same extent as if both were indicated and specified.

4.2 Endorsement of COMPANY Supplied Information

COMPANY has supplied a preliminary package for the facilities within the tender document.

These documents identify the concept and approach required on these facilities. CONTRACTOR shall be responsible for verification of all information and data, and resolution of any conflict or omission in the information and data that has been supplied by COMPANY. CONTRACTOR shall accept full responsibility for the content and correctness of the preliminary package at the time of submission of his bid.

Changes required after Contract award, resulting solely from the identification of errors or omissions or from failure by CONTRACTOR to perform sufficient analysis or review of supplied information shall not constitute reason for a change to the Contract Price.


Page 10

4.3 Pre-Engineering Surveys

CONTRACTOR shall supply qualified surveyors (who shall be APPROVED by COMPANY) to complete a pre-engineering survey of the SRT project location. The survey shall be completed and results supplied to COMPANY at least one hundred and eighty (180) DAYS prior to commencement of INSTALLATION activities. The pre-engineering survey shall confirm the proposed SRT project location and the following information at a minimum:

a) Absence of shallow gas, seabed subsidence and other relevant geophysical survey results;

b) The presence of faults, debris, boulders, ship wrecks, existing facilities, existing cables, unexploded ordinance etc;

c) Seabed profile; and

d) Geotechnical data, including but not limited to:

i) Two (2) continuous cone penetration tests with piezocone pressure measurement (PCPT) until the required depth as CONTRACTOR’s detail design for the suitable mooring system.

ii) Two (2) box core samples.

Two (2) piston sampling boreholes until the required depth as CONTRACTOR’s detail design for the suitable mooring system.

CONTRACTOR shall also perform all necessary laboratory testing on samples collected during the marine survey. The soil boring samples will form the basis for the design information. CONTRACTOR shall coordinate and liaise with Vendor representatives including arranging required site visits to SRT project location as required.

4.4 Metocean Data

CONTRACTOR shall use Metocean Data available in the BOD [1] as preliminary data. However CONTRACTOR shall engage a reputable metocean data company to obtain detailed metocean data for the project location. CONTRACTOR shall obtain as a minimum the following data:

a) Windsea and swell hind cast data for the SRT location;

b) Cross correlation between wind sea and swell and the persistence of these;

c) Annual wind, wave (wind sea, storm surge and swell) and current distribution;

d) 1 year return condition, wind, wave and current;

e) 10 year return condition, wind, wave and current;

f) 100 year return condition, wind, wave and current;

g) Hs vs. Tp;

h) Hs vs. direction;

i) Wind vs. direction;


Page 11

j) Current vs. direction;

k) Cross correlation between the wind and seas and the persistence of these;

l) Cross correlation between the current and seas and the persistence of these;

m) Tidal;

n) Wave spectral analysis;

o) Rainfall historical data and analysis;

p) Squall winds.

The data shall be of sufficient detail to enable fatigue assessment and the annual mooring and offloading availability analysis.

4.5 Geotechnical and Geophysical Data

CONTRACTOR shall use the Geotechnical and Geophysical Data provided in the BOD [1]. However CONTRACTOR shall engage a reputable Geotechnical and Geophysical data company to obtain detailed data for the project locations, this includes but is not limited to the following:

Shallow seismic and bathymetry at the SRT berth/mooring location, along the pipeline route and all areas designated for turning basins and shipping channels.

Soil Core Samples, of adequate depth to design piles or other sea bed anchoring systems and along the pipeline route, at ORF location and pipeline shore crossing.

The CONTRACTOR shall measure seismic ground acceleration at the vicinity of the SRT and use this data to establish or validate earth quake design spectra.

4.6 Facility Uptime Assessment

CONTRACTOR shall perform a facility uptime assessment to confirm design compliance with availability requirements methodology outlined below.

The facility uptime is defined as the percentage of time at which the facility is able to deliver natural gas, and shall consider – as a minimum – the following operations:

a) Marine operations associated with berthing an LNG carrier alongside the terminal to offload LNG, such operations shall consider limitations/operability envelopes associated with:

i) Mooring/fendering systems between LNG carrier and terminal

ii) LNG offloading mechanisms

iii) Tug boat(s) assist operations for the berthing of the LNG carrier

iv) The affect of inspection of tanks (including warm-up and cool-down times)

v) Planned maintenance of SRT, mooring, loading arms, jetty equipment and pipeline (including possible pigging of pipelines).


Page 12

b) In addition, depending on the CONTRACTOR proposed terminal design/concept, the following operations shall also be included in the uptime assessment:

i) Where the terminal design/concept is based on jetty solution with the use of FSU for LNG storage (regasification unit located on the jetty) marine operations shall consider the limitations/operability envelopes associated with:

− Mooring/fendering systems between the FSU and jetty

− LNG offloading mechanisms (for supply of LNG from FSU to regasification unit onboard jetty)

− Tug boat(s) assist operations for the connection/removal of FSU from the jetty as required

ii) Where the terminal design/concept is based on jetty solution with the use of an FSRU (regasification unit located on the FSRU) marine operations shall consider the limitations/operability envelopes associated with:

− Mooring/fendering systems between the FSRU and jetty

− Natural gas offloading mechanisms from FSRU to jetty

− Tug boat(s) assist operations for the connection/removal of FSRU from the jetty as required

The uptime assessment shall be based on historical (hindcast) sea-state data over a considerable duration, generally minimum 5-years of data is to be used. The historical sea-state data shall include 3-hourly sea-states of:

• Wind speed and direction

• Significant wave heights, wave periods and direction

• Current speed and direction

Operability envelopes for mooring/fendering systems, LNG offloading mechanisms and tug boat(s) assist operations shall be developed in consultation with equipment vendors and tug masters, and these operability envelopes shall be clearly stated and included within the uptime assessment. The operability envelopes shall be considered in conjunction with the duration associated with each operation, including:

• LNG carrier berthing operations (for connection to terminal to offload LNG)

• LNG offloading operation duration (LNG carrier connected to terminal)

• LNG carrier unberthing operations (for disconnection from terminal at completion of LNG offloading)

The uptime assessment methodology shall be developed by CONTRACTOR and presented to client for approval, which shall be based on simulation of the operations of the terminal over the period covered by the historical hindcast data.

For general guidance, the following procedure may be adopted for the uptime assessment:


Page 13

a) Commencing on the first sea-state provided within the historical sea-state data set, assume terminal to be fully loaded with LNG;

b) LNG volume at the terminal will be decreased – for each 3-hourly interval – in accordance with the regasification rate and gas consumed for power generation and other usage requirements associated with the terminal design/concept;

c) Step b) is to be repeated until such time where there is sufficient storage volume available to accept a parcel of LNG from LNG carrier (full parcel sizes to be used in the evaluation only, minimum LNGC capacity is 127,000-m³, less than volume required for heel and cold tanks);

d) With the assumption that an LNG carrier is available on site ready to berth against terminal for offloading, the first suitable weather window is to be found that would allow LNG carrier to berth alongside the terminal (note: suitable weather window corresponds to a period whereby the sea-states within the period do not exceed the marine operations limitations/operability envelopes associated with the mooring/fendering systems, offloading mechanisms and tug boat(s) assist operations which would allow LNG to be offloaded onto the terminal). Where such weather window is:

i) Immediately available: the LNG carrier is to connect to the terminal to commence LNG offloading. Natural gas production will continue uninterrupted;

ii) Not immediately available: the LNG volume at the terminal will be continuously decreased in accordance with the regasification rate and other gas consumption requirements, until such time where the minimum LNG volume at the terminal is reached. At this point, where such weather window is still not available, then production of natural gas will stop until such time when LNG can be loaded onto the terminal;

e) Steps a) to d) above are to be repeated over the entire historical hindcast data. The uptime of the terminal is then calculated by: Uptime [%] = 1 – (total number of hours where production of natural gas needs to stop)/(total number of hours in historical hindcast dataset)

In addition to the above, where CONTRACTOR proposed terminal design/concept is based on jetty mooring (either via the use of FSU or FSRU moored to jetty), the uptime will be affected by the operation limitations/envelopes between the FSU/FSRU against the jetty. Where disconnection of the FSU/FSRU to the jetty is required, production of natural gas will stop. The total number of hours where the FSU/FSRU is disconnected from the jetty – inclusive of the time required for reconnection and production startup – is to be counted as production downtime, and these hours are to be included in the uptime calculation in step e) above.

Sensitivity analysis shall also be considered to assess effect on uptime based on variations to the historical hindcast sea-state data. These sensitivities include – but are not limited to:

a) 20% increase in wind speed;

b) 20% increase in current speed;

c) 20% increase in significant wave heights.


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As part of this assessment, CONTRACTOR is too clearly state all parameters used in the simulation, including but not limited to:

a) Terminal LNG storage volume

b) LNG carrier sizes

c) Power consumption profile, including various operational modes of the terminal such as:

i) Regasification + LNG carrier unloading

ii) Regasification without LNG carrier unloading

iii) Production down (i.e. regasification unit off)

Any uptime analysis shall take into consideration, the multi-body coupled hydrodynamics of the FSRU on its own, with the LNGC moored in side-by-side configuration and tugs (during berthing), considering 1st and 2nd order wave motions, current and wind and shallow water effects, diffraction and dispersion. The CONTRACTOR shall advise limiting sea states and wind and current for berthing.

If the CONTRACTOR proposes to utilise membrane tank systems or other tank systems that have partial filling limitations, the CONTRACTOR shall demonstrate that the FSRU will not have to disconnect from the jetty in hurricane conditions with partial filled LNG tanks with filling levels that are not permissible by the FSRU’s classification society. CONTRACTOR shall demonstrate compliance of this requirement by providing the associated operational procedure, any time required associated with cargo management shall be included in the uptime assessment.

4.7 Construction and Commissioning Scope Interfaces

The SRT CONTRACTOR and pipeline & ORF CONTRACTOR shall be jointly responsible for interface management during all phases of the WORKS, inclusive of design, construction, commissioning and operating activities. Scheduling of key activities shall be optimised across the contract interface to avoid Project delays.

4.8 Conformance of the Work

All Engineering, Procurement, Surveys, Construction, Fabrication, Installation Pipe laying, HDD works and tie-in, Pre-Commissioning, and Commissioning Work shall conform to the highest standards expected of international contractors engaged in the oil and gas industry, and the specific requirements of this Contract, and with the COMPANY-approved drawings, specifications, reports and procedures issued by CONTRACTOR.

All materials and equipment supplied to COMPANY by CONTRACTOR shall be new and in accordance with this Scope of Work, and with drawings, specifications, reports and procedures issued by CONTRACTOR and/or other contractors and approved by COMPANY.

The Work and all components thereof shall be engineered and designed for a seaside, marine environment.


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No deviations from the COMPANY Supplied Data or CONTRACTOR issued engineering data approved by COMPANY are to be made by CONTRACTOR without prior written approval from COMPANY.


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5 HSE MANAGEMENT

Safety, health and environmental protection are core values of COMPANY. Without exception, CONTRACTOR shall pay the highest regard to health, safety, and environmental protection, in design and in performance of each phase of the Work, and shall conform to all HSE-related items of Company supplied documents.

CONTRACTOR shall have the objective to complete the Work without accident or incident and is solely responsible for:

a) Providing a safe and healthy working environment;

b) The safe performance of the Work by all personnel, and;

c) Ensuring that awareness of the importance of safety is actively promoted and monitored with adequate training given to all personnel (including authorized visitors entering any of CONTRACTOR’s Sites);

d) Ensuring that all CONTRACTOR personnel, subcontractor personnel and any vendor representatives and the like travelling to and working on the SRT are provided the necessary safety training and PPE; this shall be included in CONTRACTOR’s Contract Price;

e) CONTRACTOR shall ensure through the proper application of its environment protection procedures that the Work are:

i) Managed, planned and engineered to minimize any impact upon the environment;

ii) Performed and completed without incidents detrimental to the environment, and;

iii) Performed in full compliance with the Contract environmental policy objectives.

CONTRACTOR is expected to strictly follow COMPANY-approved Health, Safety and Environmental Requirements.


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6 ENVIRONMENTAL DESIGN PHILOSOPHY

6.1 General

CONTRACTOR will conduct its business with respect and care for the environment in which it operates and will comply with COMPANY-approved Safety, Health, and Environmental standards.

In carrying out our environmental policy, CONTRACTOR will adhere to the following application principles:

a) Comply with all applicable Jamaican regulations.

b) Conduct operations as a Reasonable & Prudent Operator (RPO) by ensuring no adverse impact to the area’s air and water qualities.

c) Maintain overall quality of the facility that is equal to or better than the industry norm in the area with respect to environmental issues.

6.2 Environmental Management

CONTRACTOR shall pay the highest regard to protection of the environment and shall conform to COMPANY’s Health, Safety and Environmental Policies and other COMPANY Supplied Data.

CONTRACTOR shall carry out environmental management to ensure that the Work is executed in such a way as to protect the environment to comply with all requirements of the Contract.

CONTRACTOR’s objectives are to ensure, through the proper application of its environment protection procedures that the Work is:

a) Managed, planned and engineered to minimize any impact upon the environment,

b) Performed and completed without incidents detrimental to the environment, and

c) Performed in full compliance with the environmental policy objectives and the Contract requirements.

COMPANY, at its sole discretion, may audit CONTRACTOR’s performance of the Work to ensure that the Contract requirements for environmental management are being satisfied in all respects. Any audits that take place shall be based upon CONTRACTOR's own environmental management manual(s), procedures, and environmental management plan. CONTRACTOR shall take immediate action to correct any non-conformances identified.

Not less than ninety (90) days prior to the Commencement Date, CONTRACTOR shall advise COMPANY on all types of waste and the anticipated quantities that shall be generated during operations and on their recommended disposal procedures and their frequency.

6.3 Community Engagement and Interface Management

In executing the Work, the CONTRACTOR shall comply with the design and construction obligations placed on COMPANY in accordance with the Project EIA stipulations and ensure that no activities


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associated with the Work are undertaken in a manner so as to compromise the standing and reputation of COMPANY with the local community and stakeholders. The CONTRACTOR shall take all actions necessary to ensure the CONTRACTOR's personnel reflect the CONTRACTOR's obligation in this regard.

The CONTRACTOR shall endeavor to maximize the use of local labour where practicable.


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7 MANAGEMENT AND ADMINISTRATION

7.1 General

CONTRACTOR shall manage and execute all activities to ensure satisfactory performance and completion of the Work in all respects in accordance with the provisions of the Contract.

CONTRACTOR shall ensure that it is fully informed regarding the planned and actual status of all Work activities at all times. It shall promptly take pre-emptive and corrective actions required correcting or avoiding actual and potential deviations from the Contract requirements and objectives.

7.2 Project Management

7.2.1 General

CONTRACTOR shall have an efficient management organization, fully supported by effective systems and procedures as to ensure that all Work is performed to meet fully the quality, schedule, safety, environmental, price and other requirements of the Contract.

a) CONTRACTOR shall provide:

i) Sufficient numbers of suitably qualified and skilled personnel with relevant experience;

ii) Suitable facilities;

iii) A project management system with all necessary systems and procedures needed for the proper control and management of the Work;

iv) All other resources whatsoever required for the proper performance and completion of the Work;

b) CONTRACTOR’s project management responsibilities include:

i) Overall management of the Work

ii) Interface management

iii) Quality management

iv) Safety management

v) Environmental management

vi) Engineering management

vii) Procurement management and materials management

viii) Transportation, care and custody of COMPANY provided equipment for the duration of the Work.

ix) Fabrication management

x) Installation management


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xi) Compliance with the Contract Schedule

xii) Financial management

xiii) Information management

xiv) Regulations, certification, classification and permitting

CONTRACTOR is responsible for the proper management and execution of the Work, wherever performed, and it shall have appropriate representation at all site(s) to ensure the safe and timely performance of all elements of the Work in accordance with the quality standards and other requirements set out in the Contract. CONTRACTOR shall keep COMPANY fully informed at all times of progress and areas of concern.

COMPANY shall assist and advise CONTRACTOR as COMPANY, in its sole judgment, considers appropriate in relation to CONTRACTOR’s performance of the Work without this relieving CONTRACTOR in any way of its responsibilities, duties and obligations under the Contract.

7.2.2 Project Execution Plan

CONTRACTOR shall prepare a Project Execution Plan (PEP) for the Work, for COMPANY approval. This shall include the progressive development, for COMPANY’s acceptance of the various lower-level plans and other documents that are described in the execution plan and which address specific topics in greater detail. Such plans and other documents shall cumulatively set out all CONTRACTOR’s management, planning and scheduling, internal control, quality, safety and other systems and processes required to ensure the proper performance and completion of the Work in accordance with the Contract.

CONTRACTOR shall update the execution plan as necessary during the performance of the Work securing COMPANY’s acceptance of any proposed deviations prior to their implementation. A deviation will only be applicable where proposed actions fall outside the boundaries described in the execution plan. CONTRACTOR deciding, with COMPANY’s agreement, between alternative courses of action that are described in the execution plan along with full details of the basis on which the decision would be made in accordance with the agreed Contract Schedule, will not be considered as a deviation requiring updating of the execution plan.

CONTRACTOR shall carry out the entire Work in accordance with this execution plan.

7.2.3 Communication Plan

CONTRACTOR shall develop a communication plan, including lines of communication to resolve contractual issues. This plan shall be issued for approval to COMPANY.

7.2.4 Engineering Management

CONTRACTOR shall manage all engineering in relation to the Work, giving particular consideration to all requirements and interfaces of engineering, procurement, fabrication, installation, commissioning and start-up and performance testing.

As a requirement in the bidding process CONTRACTOR shall submit an Engineering Management and Engineering Execution Plan for COMPANY approval.


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CONTRACTOR is responsible for the implementation of the requirements contained in COMPANY Supplied Data, and for all engineering required to fully satisfy its obligations under the Contract. CONTRACTOR shall not deviate from the COMPANY Supplied Data unless it has obtained COMPANY’s prior written acceptance of the proposed deviation in each case.

CONTRACTOR shall ensure that all engineering is performed fully in accordance with the Contract Schedule. CONTRACTOR shall perform general engineering and ensure all interfaces are properly identified and managed.

CONTRACTOR shall designate engineering personnel who will have specific and continuous responsibility for engineering throughout all phases of the Work. Such personnel shall:

a) Be assigned to the Work from the effective date or such other date early in the engineering phase as COMPANY may agree in writing for each position;

b) Give input to and review CONTRACTOR’s engineering to ensure that this is carried out to secure the most efficient possible performance of the Work within their respective areas of responsibility;

c) Be the designated key personnel.

Reassignment of key personnel without COMPANY’s express permission shall be subject to financial sanction.

CONTRACTOR shall also include in its organization adequate level of supervision at fabrication/conversion sites and provide appropriate personnel from its engineering organisation to ensure the proper implementation of the design intent throughout the Work. Such personnel shall participate actively in the development of detailed procedures for, and in the execution of, all fabrication, pre-commissioning, start-up, and performance testing activities.

CONTRACTOR shall ensure that there are always sufficient suitably qualified and experienced engineering personnel, acceptable to COMPANY, assigned to the Work to fulfill properly the responsibilities described above.

Concurrent with progressive completion of engineering required for procurement, fabrication, installation, transportation, testing, commissioning, and start-up, CONTRACTOR shall commence preparation of its close-out report for each phase. The objective is timely completion and issue of the close-out report together with CONTRACTOR’s as-built reporting.

CONTRACTOR shall ensure that all engineering in relation to the Work conforms to all requirements of the Contract, including particularly those of the Marine Insurance Surveyor and Classification Society.

7.2.5 Fabrication Management

CONTRACTOR is fully responsible for the fabrication/conversion and the management of all fabrication/conversion and integration activities in relation to the Work.

CONTRACTOR’s project management organization shall include an experienced fabrication/conversion manager in place from the Effective Date. CONTRACTOR shall be specifically responsible for:


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a) The approval of all fabrication procedures;

b) The safe and timely performance of fabrication/conversion activities at all site(s);

c) The care and custody of all goods and materials at each site;

d) Safe working practices at all site(s).

CONTRACTOR shall ensure safe and timely performance of all fabrication/conversion in strict compliance with the Contract.

At each site, CONTRACTOR shall have a management team fully capable of directing and supervising fabrication activities in order to achieve satisfactory completion in accordance with the Contract Schedule, and in accordance with safety, quality, and technical requirements.

At each site, CONTRACTOR shall ensure:

a) A safe working environment for all personnel;

b) All facilities and equipment required for the Work are fit for purpose and carry appropriate certificates for use;

c) Proper security against theft and unauthorized visitors;

d) The quality of all Work meets the Contract requirements.

7.2.6 Mechanical Completion and Commissioning Management

CONTRACTOR is fully responsible for the Mechanical Completion and Commissioning activities in relation to the Work.

CONTRACTOR’s project management organization shall include an experienced commissioning manager in place from the Effective Date. CONTRACTOR Commissioning Manager shall be specifically responsible to define and organize Commissioning Work responsibilities and instructions for execution, administration, monitoring and recording of data throughout the implementation and certification of Commissioning activities up to handover to Operations.

CONTRACTOR shall form a Commissioning Group under the direct direction and supervision of the Commissioning Manager [designated key personnel] that shall operate as an integrated part of CONTRACTOR’s team and whose responsibilities include the execution of Pre-Commissioning and Commissioning of Dynamic Systems. CONTRACTOR shall submit a SRT Commissioning Plan and Mechanical Completion and Commissioning Plan to COMPANY for approval prior to commencement of any commissioning or mechanical completion activities.

CONTRACTOR shall provide labour, equipment, materials, supplies and utilities, including but not limited to temporary electrical power, diesel fuel, instrument air, potable water, etc. as necessary to perform all commissioning activities.

7.2.7 Installation Management

CONTRACTOR shall plan all details of its marine operations for the installation of the SRT to ensure they are carried out safely, efficiently, and in accordance with the Contract Schedule. CONTRACTOR’s detailed plans will be subject to COMPANY’s acceptance.


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CONTRACTOR shall coordinate its marine operations with those of COMPANY’s field operations. The overall objective is to complete all operations safely in the shortest practicable time and with the most efficient use of vessels and equipment.

CONTRACTOR shall prepare a detailed installation plan and associated schedules. The plan shall outline all installation activities, durations, and shall include task sheets detailing all required vessels, materials, equipment and personnel needed to carry out the complete offshore installation and related operations. As a minimum, the installation plan shall detail the following information:

a) Plan for mobilization and demobilization of all marine equipment, marine vessels, equipment, personnel and materials required to perform the Work in accordance with the specifications, drawings and Contract Schedule;

b) Plan for pre-surveys;

c) Plan for transport of the SRT from the fabrication yard to project location;

d) Detailed marine operations schedule covering all vessel movements and marine activities.

CONTRACTOR’s installation plan shall also address the following:

a) Management of interfaces, physical or other, between the Work and field operations;

b) Weather criteria and weather windows for all operations including hurricane weather periods;

c) Details of all spreads and vessels including installation vessel, cargo barge and all vessels for anchor handling, tow, dive support, testing and pre-commissioning;

d) Details of the facilities at the mobilization Site;

e) Consumables and materials logistics;

f) Tow required equipment and navigation aids.

g) Survey and positioning requirements;

h) Inspection requirements;

i) Communications arrangements;

j) Personnel qualifications, certification;

k) Transportation and accommodation of personnel;

l) Quality assurance procedures;

m) As-installed survey procedure and report;

n) HSE procedures;

o) Contingency plans for all installation activities.

The installation plan shall incorporate all recommendations made by the Marine Insurance Surveyor, Classification Society, and COMPANY.

CONTRACTOR’s project management organization shall include an experienced Installation Manager. The installation manager shall be a key person and shall be specifically responsible for:


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a) The development and approval of all mobilization and installation procedures;

b) All mobilization activities;

c) The safe and timely performance of all offshore installation activities;

d) All marine activities.

CONTRACTOR shall prepare contingency procedures to ensure, in the event of any unforeseen circumstance or occurrence that the mobilization and installation shall precede without risk to personnel, CONTRACTOR’s Spread, existing structures and facilities in the field, and the SRT CONTRACTOR’s equipment and operations.

Each installation phase shall be subject to HAZID and HAZOP review as part of the procedure preparation, the results of which shall be incorporated into the procedures. CONTRACTOR shall conduct the HAZID and HAZOP reviews with participation from Classification Society, and Marine Insurance Surveyor, as appropriate. COMPANY, at its sole discretion, shall participate in the reviews.

CONTRACTOR shall ensure that all mobilization, installation and contingency procedures are submitted simultaneously to COMPANY and to the Marine Insurance Surveyor for approval.

CONTRACTOR shall make due allowance of the time necessary for the various reviews of mobilization, installation and contingency procedures leading to approval by the Marine Insurance Surveyor, Classification Society, and COMPANY. CONTRACTOR shall fully test the critical equipment and demonstrate to COMPANY that all are well functional before demobilization.

CONTRACTOR shall ensure that CONTRACTOR’s spread:

a) Complies with the requirements of the Marine Insurance Surveyor;

b) Is properly crewed and manned, equipped, provisioned and bunkered;

c) Is properly certified and fit for purpose.

For all works adjacent to offshore facilities, CONTRACTOR shall ensure the documented Contract specific management system and safety plan complies with all relevant Health, Safety and Environment requirements, Permit to Work requirements and Emergency response/accident reporting requirements. CONTRACTOR shall cover all aspects of Work relating to HSE procedures in the simultaneous operations (SIMOP) procedure.

7.2.8 Information Management

CONTRACTOR shall establish a secure, Contract-specific, document and information management system. The information management system shall be capable of efficient distribution/dissemination, handling, filing and retrieval of all data and documentation in relation to the Work.

7.2.9 Interface Management

CONTRACTOR shall manage and coordinate Work-related interfaces, including all interfaces with COMPANY, and among CONTRACTOR Group. CONTRACTOR shall carry out all required interface activities to assure the successful execution of the Work and all interfacing work performed by other entities.


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CONTRACTOR shall ensure that components at each physical interface are fully compatible in all respects, including but not limited to:

a) Engineering;

b) Materials and equipment supplied;

c) COMPANY provided Equipment;

d) Dimensions;

e) Fabrication;

f) Installation;

g) Pre-Commissioning.

CONTRACTOR shall manage the interfaces at the point of connection between the gas export pipeline and the SRT.

CONTRACTOR shall keep COMPANY fully informed at all times regarding its proposed schedule of interface meetings, and shall amend the schedule as necessary to take account of COMPANY’s comments. CONTRACTOR shall give COMPANY timely notice of all unplanned interface meetings.

COMPANY shall attend interface meetings at its discretion, but in any event CONTRACTOR shall keep COMPANY fully informed regarding the results of all meetings. CONTRACTOR shall include all Contract Group within interface meetings, as appropriate for the specific pipeline and riser components.

7.2.10 External Interface Responsibilit ies

An external interface register shall be submitted to COMPANY within twenty (20) business days from the BOOT Contract award, for COMPANY’s review and approval. Upon COMPANY’s approval, CONTRACTOR shall issue the external interface register to all persons to whom CONTRACTOR has an interface obligation, or who have an interface obligation to CONTRACTOR.

The register shall identify the person (CONTRACTOR Group, COMPANY, or one of COMPANY’s other contractors) that has the primary responsibility for the management of individual interface items. All needed dates for information from one person to another, or for delivery of physical items, shall be agreed between CONTRACTOR Group, COMPANY and COMPANY’s other contractors.

7.2.11 Operations Readiness Management

As soon as possible after the effective date, CONTRACTOR shall engage with COMPANY Operations personnel to assess the requirements to merge CONTRACTOR’s Operations and Safety Management and Operations and Safety Management of the COMPANY.

CONTRACTOR shall present an Operation Preparedness Activities document to COMPANY for approval ninety days (90) prior to installation of the SRT.

Sixty days (60) prior to the installation of the SRT in project location, COMPANY’s Corporate Operations shall audit CONTRACTOR’s Operations and Safety Management to assess its readiness and preparedness for operations.


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CONTRACTOR shall achieve successful result of the audit program as a requirement to connect the SRT to the onshore gas network.

7.2.12 Operator Training

CONTRACTOR shall advise of crewing requirements for the operation of the SRT and shall prepare an operator training plan 2-years in advance of the transfer of ownership/lease expiry date which is to be confirmed by the CONTRACTOR. The CONTRACTOR shall undertake operator training, in line with SIGTTO competency standards.

7.3 Quality Assurance and Quality Control

7.3.1 General

The CONTRACTOR shall be responsible for overall Quality Assurance and Quality Control (QA/QC) for all aspects of the WORK in accordance with the CONTRACTOR supplied QA/QC Plan and documents, this plan requires approval prior project start by COMPANY, COMPANY reserves the right to mandate quality assurance processes without no additional cost to the COMPANY. CONTRACTOR is responsible to eliminate all defects, non-conformances identified by the QA/QC process and is also responsible for all remedial work required.

CONTRACTOR shall perform the Work in full compliance with its quality assurance and safety management systems and provide COMPANY with adequate documentation in verification thereof.

CONTRACTOR shall have a well established and widely utilized throughout its organization Quality Management System for use during the design engineering and construction of the SRT.

This System shall be acceptable to COMPANY and conform to the ISO 9000 series of standards or an equivalent internationally recognized standard to ensure that the SRT design, engineering and fabrication is properly managed and controlled.

CONTRACTOR shall provide a Quality Management System customized for the SRT design, engineering and construction that shall:

a) Set down the Quality Policy and objectives for the SRT design, engineering and fabrication.

b) Identify all relevant procedures, work instructions and the like to be applied and used by CONTRACTOR and main subcontractors during the project. COMPANY shall have the option to review and comment on any such procedures, work instructions and the like. The procedures shall, be made available for COMPANY audit and/or review at all times. CONTRACTOR shall supplement existing procedures or develop additional procedures, as may be necessary where COMPANY considers existing procedures are inadequate.

c) Provide a Project Quality Management Plan (PQMP), which shall show in logical sequence all of the activities required for the SRT design, engineering and fabrication. The activities shall be in clearly identifiable elements that allow ready determination of the inspection requirements for CONTRACTOR, and third parties as may be required. The PQMP will be a comprehensive management document detailing for each discipline the activities, codes, rules and regulations applicable to the Work, and shall include at the most detailed level the tools, equipment and materials required to enable the activities to be performed correctly and accurately. The PQMP


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shall specify or refer to a procedure that sets how to manage the interfaces within CONTRACTOR’s organization and with all other parties.

d) Set out a process whereby auditable records of compliance with the Quality Management System are maintained. CONTRACTOR shall define and operate a procedure for formally documenting any deficiencies in its quality system and for corrective actions and closure of such deficiencies. COMPANY reserves the right to suspend any or all of the work affected by a deficiency and/ or to reject any of the work so affected.

CONTRACTOR shall define and operate a formal procedure for documenting, registering and rejecting/approving any request for a deviation from the agreed technical specifications, materials or goods made either by CONTRACTOR or subcontractors. Repair, refurbishment or acceptance of non-conforming materials shall be treated as a concession. Concessions shall be requested separately from and not through the technical query system. COMPANY shall be advised of all concession requests and the subsequent conclusions.

CONTRACTOR shall ensure compliance with the PQMP through conducting a predetermined series of internal and external audits. Each audit shall be recorded in an audit report comprising a checklist, associated findings and non-compliances (if any), with references to timing for re-audit of non–compliances after corrective actions. COMPANY shall have access to all such reports, and shall have the opportunity to participate in technical audits/ reviews during performance of the Work.

7.3.2 Quality Actions Prior to Commencement of the Work

Prior to the commencement of Work at each Site, CONTRACTOR shall ensure through its quality system that:

a) All applicable systems, procedures and documentation are in place, and all personnel are fully familiar and complying with them;

b) All project document registers are established and maintained which list all of the relevant project documents comprising the Project Quality System and indicating their current status;

c) All correct engineering data is available including the latest revision of applicable drawings, specifications and other pertinent documentation;

d) All required testing and qualification of personnel and work processes, and all other prerequisites for Work to be allowed to start have been duly carried out;

e) Applicable engineering data and procedures have achieved AFC status;

f) The correct materials and all required resources are available;

g) All plant, equipment, facilities, and vessels are fit for purpose, certified, and suitable in every respect for the safe and satisfactory performance of the Work.

7.3.3 Quality Plan for the Entire Work

Within twenty (20) days of the Effective Date, CONTRACTOR shall submit its proposed quality plan for the entire Work to COMPANY. COMPANY shall review the plan and give its comments to CONTRACTOR within ten (10) Business Days from receipt.


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Thereafter, CONTRACTOR shall:

a) Revise the quality plan to take due account of COMPANY’s comments;

b) Issue the COMPANY-accepted quality plan to COMPANY for immediate implementation after the Effective Date.

During the period between the Effective Date and finalization of the quality plan, CONTRACTOR shall manage and perform all aspects of the Work in compliance with COMPANY specifications and any COMPANY approved documents that CONTRACTOR progressively develops.

The objective of the plan is to ensure the Work is performed and completed fully in compliance with the Contract requirements. CONTRACTOR shall plan and carry out a systematic program of audits and verification activities in support of the quality objective. Such program shall be subject to COMPANY’s approval.

CONTRACTOR shall manage the quality of the Work and shall adhere to and enforce its quality plan. CONTRACTOR shall take timely action to identify and correct deficiencies in CONTRACTOR’s quality system in order to avoid potential non-conformances, and correct actual non-conformances. CONTRACTOR shall at all times comply with its quality management system.

7.3.4 Testing Equipment

CONTRACTOR shall establish and maintain documented procedures to control, calibrate and maintain inspection, measuring and test equipment (including test software) used by CONTRACTOR to assure the safety or health of personnel, or monitoring of the environment. CONTRACTOR’s procedures shall comply with ISO 9001 and Contract requirements.

7.3.5 Auditing

CONTRACTOR shall provide reasonable support and access during review and audits conducted in association with the Work, as may be undertaken by COMPANY and/or its representatives. Such reviews and audits may be directed at any part of the Work, including but not limited to performance and competency of personnel, management systems (including procedures and processes), HSE and quality matters, and records.

CONTRACTOR shall establish a schedule for audit of its own processes, procedures and personnel as may be related to the Work. CONTRACTOR shall seek concurrence from COMPANY of its audit schedule and CONTRACTOR shall provide COMPANY with a copy of all audit schedules in a timely manner. Furthermore, CONTRACTOR shall conduct audits on key subcontractors/suppliers and any such audits shall be included in the audit schedule.

COMPANY shall have the option to participate in any such internal audits, excluding any audit or part of audit that may be of a proprietary nature to CONTRACTOR. COMPANY shall be promptly issued with a copy of all audits reports produced from such audits. Any non-conformance and corrective action identified from any review audit or as may otherwise be identified shall be promptly rectified by CONTRACTOR and/or subcontractors/suppliers.


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7.4 Codes and Standards

The relevant codes and standards are provided in the project BOD [1], specifications and philosophies.

7.5 Office Facilities for Company’s Personnel at the Sites(s)

CONTRACTOR shall provide eight (8) workstations (desks, chairs) equipped with phone line (local and international), broadband internet access, PCs (loaded with Microsoft Windows and Office standard software packages) and independent A3/A4 colour printer and domestic power supply for the use of COMPANY personnel for the duration of the construction and commissioning phases of the WORKS.

7.6 Errors & Omissions

CONTRACTOR shall understand that the COMPANY-supplied specifications and design reports represent a preliminary design only, and as such are not intended for use in detailed design.

It is an obligation of CONTRACTOR to check the CONTRACT documents & specifications, and satisfy itself that it has sufficient information to plan and execute the WORK to the satisfaction of COMPANY. CONTRACTOR shall review the COMPANY supplied preliminary design and specifications and identify any shortcomings that would adversely affect the WORK or the smooth progress of same. CONTRACTOR shall give COMPANY notice in writing of such shortcomings and advise COMPANY of proposed actions to rectify the same.

It will be the CONTRACTOR’s responsibility to identify any conflicts in the documentation. Should any error, omission or discrepancy appear in the drawings, specifications, instructions, or in other WORK done by others, CONTRACTOR shall notify COMPANY at once, and advise COMPANY of proposed actions to rectify same.

7.7 Hierarchy of Technical Documents

In the event of any technical conflicts between the various documents contained within the CONTRACT, the ranking of precedence for technical documents shall be:

a) Basis of Design;

b) Scope of Work;

c) Project Specifications;

CONTRACTOR shall advise COMPANY of all conflicts and COMPANY shall decide resolution of same.


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8 ENGINEERING

8.1 General

CONTRACTOR shall use the services of a reputable and experienced engineering firm, acceptable to COMPANY and the Classification Society for the performance of the initial condition assessment and the design and engineering of the up-grades/modifications, if/as required. Considerations include prior experience in performing such analyses, including the ability to apply Classification Society approved computer software and verify the design with previously validated data.

CONTRACTOR shall conduct adequate inspections of primary and secondary SRT structures in order to demonstrate to the Classification Society that it will meet the operational requirements at the offshore location for the project design life as stated in the BOD [1]. This evaluation shall result in the basic requirements for the design of the conversion/modification structural repairs work, CONTRACTOR shall obtain a CAP 1 level rating for the structural, machinery and cargo systems of the SRT.

At the very early stages of the engineering, CONTRACTOR shall ensure that the design of the primary and secondary structures of the candidate vessel for Conversion are fully evaluated including fatigue analysis, to demonstrate to the Classification Society that it will meet the operational requirements at the site for the project design life as stated in the BOD [1].

8.2 Detailed Design & Engineering

CONTRACTOR shall perform detailed design and engineering activities as required to design the FACILITIES including, but not limited to, the following:

a) CONTRACTOR shall prepare all necessary, Approved for Construction (AFC) status, drawings, specifications, data sheets and any other necessary documentation required to fully describe and define all components of the WORK. CONTRACTOR shall propose a numbering system for all documentation this shall be approved by COMPANY. All design calculations, drawings, specifications and other documents prepared by CONTRACTOR shall be fit for their intended purpose.

b) CONTRACTOR shall include all provision as required in these CONTRACT documents, standard industry codes, or as required by “good engineering practice”. The level of detail shall be sufficient to completely cover all requirements needed for a floating facility of this type.

c) The CONTRACTOR shall provide all documentation, in editable electronic format; reports and calculations shall be issued to the COMPANY in MICROSOFT Office format. Drawings shall be provided in 2D AUTOCAD format (DWG or DXF)

d) The CONTRCATOR shall maintain and provide a complete documents INDEX, inclusive of all revisions and dates.


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8.3 Engineering Design Codes

The design, the construction documents, the execution and the completed Works shall comply with any and all applicable specifications, technical standards, building, construction and environmental codes specified by COMPANY or defined by any applicable Jamaican Laws and Regulations.

A list of different design codes, specification and design manuals, which will be referenced to, but shall not necessarily be limited to, is presented in the Basis of Design [1].

8.4 Operations Involvement

CONTRACTOR shall include relevant operations personnel in the review of drawings at conceptual and detailed design phases.

Senior operations personnel shall also be involved in HAZOPs, HAZAN, HAZIDs and similar safety reviews associated with the preparation of the Safety Assessment Analysis. Operations personnel shall be involved as far as practicable in fabrication/conversion activities.

CONTRACTOR’s Operations personnel shall participate in mechanical completion and commissioning activities. CONTRACTOR shall designate operations personnel to “sign off” the documentation associated to the mechanical completion, pre-commissioning and commissioning dossiers. The CONTRACTOR’s operations personnel shall consist of key personnel and well experienced personnel for LNG commissioning and operations.

8.5 Safety Engineering

During the engineering and design of the Work, CONTRACTOR shall ensure, using a formal and well structured process (Design Safety Assessment analysis), that all major hazards are identified and their risks assessed. The hazards will either be eliminated by design, or associated risks will be controlled by reducing the likelihood of occurrence, mitigating the consequences, or a combination of the two.

In judging risks that decide when changes are required, a three band risk approach will be adopted. This will ensure:

a) No individual is exposed to risks above a maximum tolerable level;

b) Risks that are below a minimum level may be accepted; and

c) Risks will be reduced to a level that is as low as reasonably practicable (ALARP) in the intermediate band. ALARP means that the time, trouble, effort and cost of reducing the risk further is not justifiable in terms of risk reduction benefit. The standard for determining ALARP shall be agreed with COMPANY and shall be based on best operating practice for similar operations.

CONTRACTOR shall ensure that safety-critical elements are identified and a verification scheme implemented during the design and construction phases.

CONTRACTOR shall prepare foundation designs suitable for equipment, pipe racks, buildings, structures, and miscellaneous supports. All foundations for major equipment and other major loads subject to settlement shall be piled. As a minimum, all major vessels, towers, packaged equipment,


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flare/ Vent tower and communication, storage tanks and buildings, shall be piled. Piling is also required for all pipe supports between the pipe racks and equipment. If spread footing and piling type foundation is used for other items, fill and compaction shall be done to suitable levels to support intended load.

CONTRACTOR shall consider the requirement for piles for smaller loads based on the soil test data and provide pile foundation as required, based on meeting acceptable minimum long term settlement requirements.

CONTRACTOR to consider that all load bearing supports will be piled.

8.5.1 Design Safety Assessment

CONTRACTOR shall obtain the services of a reputable sub-contractor acceptable to COMPANY for the Design Safety Assessment (DSA) analysis.

The DSA shall cover the safety requirements of all the phases of the Work, including design, fabrication, transportation, installation, testing and commissioning. Upon completion of the design phase and in preparation for the fabrication phase the safety assessment subcontractor shall issue a Safety Report which shall summarize the results and findings of the various analyses conducted for the DSA and their implementation into the engineering and fabrication/conversion as well as their interface with the operations safety assessment.

At its own cost, CONTRACTOR shall obtain approval for the DSA from the applicable IACS Classification Society, prior to the completion of the design and engineering of the SRT.

All relevant findings shall be included to the design and engineering work prior to the start of the fabrication phase. CONTRACTOR may defer implementation of a limited number of findings of the DSA to a time suitable with fabrication plans while keeping deliverables and objectives in place and solely upon acceptance by applicable Classification Society and COMPANY.

Modifications to the design as a result of findings or recommendations of the DSA shall be implemented at CONTRACTOR’s expense and as early as possible during SRT’s engineering design/prior to fabrication.

The formal Safety Assessment shall consist, as minimum, but not be limited to the following:

a) Hazard identification (HAZID);

b) Non-flammable hazard assessment;

c) Smoke and gas ingress analysis;

d) Emergency Systems Survivability Assessment;

e) Escape, Temporary Refuge, Evacuation, and Rescue Analysis;

f) Quantitative Risk Assessment;

g) As Low As Reasonably Practicable Assessment;

h) Hazard Analysis Study (HAZAN);

i) Hazard and Operability Study (HAZOP);


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j) Fire and Explosion Risk Analysis (FERA);

k) Dropped Object Study;

l) Cold Vent vs Hot Flare Study (CONTRACTOR to determine suitable design philosophy);

m) Gas Release and Dispersion Analysis;

n) Safety Integrity Level (SIL) Evaluation;

o) Hazardous area Classification Assessment;

p) Hazard Identification Risk Assessment (HIRA);

q) RAM Analysis to confirm uptime availability per annum;

8.5.2 HAZOP for SRT

A HAZOP shall be performed after first draft of all major P&IDs is available and at a date agreed to with the CONTRACTOR and COMPANY.

The HAZOP study shall be completed by CONTRACTOR as soon as detailed engineering has been achieved and early enough to have the findings and recommendations included to the fabrication/conversion scope of work and delivery schedule. CONTRACTOR shall make arrangements to acquire the services of a specialized CONTRACTOR acceptable to COMPANY to provide guidance and assistance to perform the analysis, CONTRACTOR shall also provide marine operations and specialized engineering (Electrical, Instrumentation, other) input and SRT operations specialist support to actively participate in the HAZOP analysis.

CONTRACTOR shall seek guidance from applicable IACS Classification Society to determine what systems and equipment shall be the subject of a HAZOP analysis.

As a minimum the following systems shall be analyzed:

a) LNG products import system.

b) Cargo handling system (refrigeration, regasification, storage).

c) Cargo tanks and cargo handling safety relief and vent system.

d) Regasification system

e) Safety protection systems (gas and fire detection, fire protection and fire-fighting,

f) Lifesaving systems, escape routes, temporary refuge, evacuation system, etc.)

g) Marine and auxiliary support systems.

h) Major maintenance work.

i) Accommodation, HVAC and ventilation systems.

j) Vessel control and communication systems.

Identified design changes/modifications from the HAZOP study shall be incorporated to the SRT design at CONTRACTOR’s expense as early as possible. Mooring and interim SRT items that


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resulted from mooring and interim SRT HAZOP and engineering design assessment work shall be reviewed for incorporation to the SRT HAZOP analysis.

CONTRACTOR shall demonstrate that there is adequate funding for safety engineering, including the Safety Assessment and the fabrication/conversion/upgrade of the safety systems, including the implementation of the findings and recommendation of the Safety Assessment. CONTRACTOR shall be prepared to provide COMPANY with detailed information in support to the budget allocated for Safety Engineering.

8.5.3 Waterway Suitabil ity Assessment

The CONTRACTOR shall conduct Waterway Suitability Assessment (WSA) in accordance with the navigation and vessel inspection circular NVIC 05-05.

When conducting a WSA of SRT, the assessment shall include:

a) LNGC type;

b) The SRT location;

c) The navigational path, and;

d) The nearest neighbours along the navigational path and at the terminal.

There are four classes of attributes that affect overall risks. These attributes are:

a) The context of the SRT – location, site specific conditions;

b) Potential targets and threats – potential accidental events, credible intentional events, and ship or infrastructure optimums;

c) Risk management goals – identification of levels of consequences to be avoided, such as injuries and property damage, LNG supply reliability required; and

d) Protection system capabilities – Safety and security measures, early warning, and emergency response/recovery measures.

These attributes must be evaluated to determine if the protection systems in place can effectively meet the risk management goals identified for a specific terminal. If the initial risk assessment determines that the identified risk management goals are not met, then potential modifications in location and site conditions, import operations, safety and security measures, or hazardous marine export operations, are reviewed to assess the ability to meet the objectives. Changes in factors including the context of the SRT, threats or threat-levels, risk management goals, or risk management and safety systems could impact the basis for the original evaluation, making a reassessment of the risks necessary.

8.6 Classification, Certification & Registration

8.6.1 General

CONTRACTOR shall be wholly responsible for obtaining all certificates and documentation relating to compliance with the Classification Society, Jamaican Governmental Authority requirements, laws and


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regulations to execute the work under the Contract, except where such certification and regulatory compliance is the responsibility of COMPANY.

CONTRACTOR shall complete mechanical engineering work needed to design, procure, fabricate, and install equipment required for the facilities.

CONTRACTOR shall comply with the COMPANY supplied BOD [1] to develop complete engineering, design, installation and test requirements, and detailed equipment specifications for all facility mechanical, safety, and special piping equipment. The information developed by CONTRACTOR shall be used for procurement of all such equipment. CONTRACTOR shall incorporate all supplier data into the design as such data becomes available.

CONTRACTOR shall ensure to meet requirements stipulated in the governing Specifications and Documents concerning Design, Construction, Manufacturing, Assembly, Testing, Supply, Erection, and Commissioning, and proving performance guarantee of the Equipment covered under the various units.

All the equipment shall meet the acceptance criteria stipulated in the governing specifications, with regard to proven design, trouble-free operation, and performance at site. The reference list meeting the above shall be obtained from each equipment supplier for COMPANY’s approval by the CONTRACTOR.

Updating of COMPANY supplied specifications and design philosophies:

a) While specific guidelines pertaining to individual equipment and packages are given in the general equipment specifications, following general considerations shall be kept in view for all items while formulating their specifications and also in subsequent procurement and engineering activities:

b) Reliability in service (assessed from OEM’s relevant Track Record and improved by incorporating certain minimum design features or requirements in the specifications).

c) Compliance with applicable national or international codes (or equivalent codes of other countries) and standards as well as any statutory regulation/local regulation in existence for a specific item.

d) Ease of operation and maintenance, including any necessary measures for ensuring safety of personnel and equipment, as well as acceptable working environment.

e) Standardization of components.

f) Adherence to any limitations of space available for the equipment and its operation/maintenance.

g) Facility for future expansion/phased construction with a minimum of modifications or shutdown.

h) Equipment shall be designed for the given tropical site conditions.

i) Pressure vessels, pumps, compressors/blowers, and other equipment, piping, instrumentation and electrical works, wherever applicable for the equipment, shall be engineered as per the requirements specified in the respective sections of the tender specifications.


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j) The design pressure, temperature, corrosion-resistance and other conditions of operation should in no case be inferior to the applicable codes and standards.

8.6.2 Classification Society and Certification

The candidate vessel must have been built to the relevant classification society and certification as provided in the BOD [1], specifications and philosophies.

The alternative classification society will be selected depending on the current Classification Society classing the LNGC vessel and selected by CONTRACTOR to class the SRT.

8.6.3 Certification

CONTRACTOR shall perform all activities necessary to obtain all certification required to allow the SRT to operate at the given location including but not limited to, at minimum, the following certificates:

a) Classification Society notation required certificates

b) SOLAS

c) International Loadline

d) International Tonnage

e) Certificate of Fitness

f) International Oil Pollution Prevention

g) International Sewage Pollution Prevention

h) Deadweight

i) Potable water

j) Certification by Classification Society for the manufacturing of individual materials, machinery, equipment and outfitting items

k) Certificates for electrical equipment located in hazardous areas

l) Certification from National Authorities

In addition CONTRACTOR will need to provide cargo tank capacity and tables.

CONTRACTOR shall support COMPANY in obtaining certificates that must be obtained in COMPANY’s name. COMPANY shall not be responsible for any delays in obtaining such certificates that must be obtained by COMPANY, and CONTRACTOR shall anticipate lengthy approval periods.

CONTRACTOR shall be responsible for appointing a certification agency, which must be accredited by Jamaican authorities, and shall act as coordinator towards other government authorities for the issuance of aforementioned government authority’s certificates.

CONTRACTOR shall be responsible for maintaining the certification valid throughout the Contract term.


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During CONTRACTOR contacts with regulatory authorities or their certifying agencies, CONTRACTOR shall not specifically refer to COMPANY or the project without prior approval by COMPANY.

8.6.4 Government Certification and Permits

CONTRACTOR shall be wholly responsible for obtaining all certificates, permits and documentation relating to compliance with Jamaican Governmental Authority requirements to execute the work under the Contract, such as, but not limited to:

a) Cargo Custody Control System;

b) Crane Certificate;

c) Safety Inspection on the vessel at the shipyard prior to Mobilization

d) Monthly (or as required) Inspection visits to site office to update the progress and status of the Project

e) Installation and Construction Permit to enter Jamaican Waters Territory

f) Custom Clearance Inspections to clear the vessel and its crew operating in Jamaica

g) Terminal Permit for Permanent SRT with its location in Portland Bight operated as a terminal (special harbour) exporting the NG.

CONTRACTOR shall be responsible for appointing a certification agency which must be accredited by authorised government body, and shall act as coordinator towards other Governmental authorities for the issuance of any certificate required by applicable Jamaican regulations.

Immediately after completion of the detail engineering work, CONTRACTOR shall appoint a Local Metering Packager approved by Jamaican regulators for the handling and management of all aspects related to the approval and certification of the Cargo Custody Control System. CONTRACTOR shall perform all activities necessary to obtain all certificates, and where required shall support COMPANY in obtaining certificates which must be obtained in COMPANY’s name. COMPANY shall not be responsible for any delays in obtaining such certificates that must be obtained by COMPANY, and CONTRACTOR shall anticipate lengthy approval periods.

During CONTRACTOR contacts with Governmental Authorities or their certifying agencies, CONTRACTOR shall not specifically refer to COMPANY, or the Jamaica LNG Project without prior approval by COMPANY.

8.6.5 Registration

Registration of the SRT shall follow all applicable Jamaican laws and regulations.

8.7 Hull Structure Analysis

CONTRACTOR shall perform the following analysis as applicable to the selected SRT and mooring system design.


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8.7.1 General

The hull, cargo tanks, tank supporting structure, and topsides facilities under static and dynamic and fatigue loading shall be thoroughly analysed to demonstrate the adequacy of the design.

The analyses shall be performed in accordance with Classification Society and Regulatory requirements and the applicable criteria listed below, as minimum. The effects of mooring loads, topsides facilities loads, equipment support and foundation loads and temperature variation induced loads shall be accurately simulated either in the FEM calculations and other supplementary analyses, as appropriate. The FE modelling shall adequately represent the nature of these structural interfaces and the resulting reaction forces.

DNV CSA-FLS DLA (Computational Structure Assessment - Fatigue Load Study – Dynamic Load Analysis), or similar is required. The following structural components shall be included, as minimum in the CSA-FLS:

a) The hull in general;

b) Cargo tanks, any transverse and horizontal rings, ordinary frames, slotted parts, support block parts, top and bottom pitching and rolling chocks, the dome and other parts; the double bottom, side shell, deck, reinforcement for tank supporting blocks and chocks, and the other pertinent parts of the structure.

c) All relevant machinery and equipment supporting structure shall be analysed for stresses and buckling. Thermal analyses shall be as required by the IGC Code.

The above DLA shall include transient and steady state thermal stresses for the normal operational cycle at site conditions. A three-dimensional model for a typical cargo tank, including its supporting and keying system, as well as a reasonable part of the hull, shall be used in the DLA.

Load and structural analysis procedure, and functional criteria used in the analysis shall be approved by the applicable IACS Classification Society.

Fatigue analysis shall be performed on the interface structure which is between the mooring system and the SRT. Further details are available in the functional specification [4].

8.7.2 Mooring Analysis

Motion responses of the FSRU during the operation and sailing phases shall be analysed using a 3D diffraction theory.

FSRU motions shall be analysed to confirm the adequacy of the FSRU design moored against the jetty to perform safely and efficiently loading operations of LNG and to survive extreme design environment condition. Analysis based on the proposed vessel hull form shall be conducted to determine the following:


b) Mooring performance in various operating and fatigue design conditions;

c) Loads on the mooring lines;

d) Loads on mooring system equipment;


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e) Rolling reduction requirements; and

f) Operating limits for mooring and loading operations (including permissible excursion envelopes of the loading arms).

CONTRACTOR shall confirm the design through model test(s).

CONTRACTOR shall conduct model tests to confirm the analytical predictions. The results of model/data comparison shall be used to optimize the mooring arrangements; size mooring and related components; and the need for rolling motion reduction measures; and to define various operating limits for cargo transfer.

8.7.3 Model Testing

CONTRACTOR shall perform analytical studies to confirm the adequacy of the facility design for the intended operations. Model test analysis shall be conducted as early as possible in the engineering design phase and subsequent hydrodynamic model tests.

CONTRACTOR shall engage the services of an experienced, internationally recognized, design engineering company to carry out the analytical Work, acceptable to the Classification Society and to COMPANY, to conduct the tests with the objective to predict and/or verify the following:

a) The SRT motion characteristics while at berth, under the various environmental and draft design conditions;

b) The loads on the mooring lines over a range of operational and a range of operating drafts, including damaged condition with failed mooring components;

c) Relative SRT motions, mooring lines, loading arms and fender loads during cargo transfer to define the system ceiling for the SRT to perform mooring and offloading operations at the facility, including acceleration at the end of the loading arms for the operating conditions;

d) Vessel motion reduction levels in reference to the size and location of the oversized bilge plates (if required) to optimize the performance of side-by-side operations at Portland Bight, year round;

e) To demonstrate that the installation meets the specified mooring and cargo transfer operational requirements using loading arms;

f) The environmental conditions limiting cargo transfer. This activity shall also determine the number and power of tugs boats to be used during berthing and unberthing operations;

g) Establishing of tug operations, i.e. operating on lines only vs. pushing (establishing of sea state limits for push operations)

h) LNGC and FSRU approach to the berth and the ability to navigate the proposed channels, shall be demonstrated by ship simulator analysis, this simulation shall include the LNGC, varying environmental conditions, tugs. The recommendation in relation to approach channel, turning basin and berth pocket size, shall be implemented into the design. The activity shall define limiting wind, current and wave conditions for the safe navigation of the approach channels and the berth


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Analysis and model tests shall use practical data to the extent that it is possible for the definition of the deck mooring arrangements and mooring equipment as per OCIMF Mooring Equipment Guidelines.

Model test plans and test predictions shall be submitted to the Classification Society and COMPANY for review and acceptance prior to any model testing.

The model test results shall be submitted to the Classification Society and COMPANY for review and acceptance.

8.7.4 Trim and Stabil ity

The SRT shall have positive intact stability in all service conditions complying with the requirements of the relevant regulatory bodies.

CONTRACTOR shall carry out the trim and stability and strength analysis for lightship, sailing and operations in ballast and loaded (25%, 50% and 100%) conditions.

Damage stability shall satisfy the requirements of MARPOL/ICLL/IGC and/or other applicable requirements.

As early as possible during the engineering phase, CONTRACTOR shall perform a hydrostatic, hydrodynamic, and stability analysis and modelling for continuous cargo loading and ballasting conditions that simulate the loading and offloading scenarios during continuous operations at the maximum operational rates as described in the BOD [1].

The analysis shall consider all loads that will impact vessel stability design (modifications to the vessel, regasification packages, etc. The results shall identify potential operational restrictions and incorporate recommendations to achieve continuous operations in a safe and efficient manner.

A detailed report together with the analysis shall be submitted to COMPANY for review and approval.

8.8 Materials and Workmanship

The materials used in the design, engineering and construction work shall be specifically elected for operations in marine environment. Materials, material combinations and surface protection system shall be carefully evaluated and upgraded as necessary to avoid corrosion problems and to ensure adequate performance during the design life without dry docking and major repairs.

The existing systems shall be also evaluated and upgraded as necessary, to operate in an environment where the package support structure flexes and vibrates, and to the specified ambient temperature.

All materials and equipment furnished by CONTRACTOR for upgrades and new installation shall be selected to minimize degradation through corrosion and fatigue damage for a service life.

Materials, apparatus and equipment for SRT shall follow codes, standards as outlined in BOD [1] and guidelines as outlined in section 8.6.2.

For existing and upgraded cargo piping systems the material is to be a suitable grade of stainless steel and low temperature carbon steel is not acceptable for cargo piping systems.


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All material testing shall be approved by applicable IACS Classification Society.

8.9 Maintenance Philosophy

CONTRACTOR shall design the SRT in accordance with the maintenance principles provided herein by COMPANY.

A complete plan for handling and transporting heavy equipment or parts (≥ 75-kg which is beyond the ability for 2 personnel to lift manually) from their seat to workshops and to the deck crane handling area shall be provided. Permanent trolleys shall be provided to minimize man handling and shifting of the lifting gear.

Restriction of access openings by pipes, valves and heating coils shall be avoided and ladders shall be located in line with openings. All trunks, casings, etc., shall be large enough to facilitate servicing of piping, manifolds, etc. maintenance covers shall be removable without the need to remove long sections of piping or valves.

Provisions shall be made for the removal of machinery parts, which provide structural support to decks, bulkheads, etc. so that when a section so designated on working plans is removed, the remaining structure will be self-supporting and the standby machinery operational to continue full operation of the SRT.

Reliability, Availability and Maintenance (RAM) analysis will be used to establish uptime targets for the selected design concept.

CONTRACTOR shall evaluate the capacity, redundancy and quality of SRT equipment to ensure that the overall availability of the assets in operation at the SRT facility shall be consistent with requirements detailed in the BOD [1].

CONTRACTOR shall obtain the services of a third party entity, approved by COMPANY, to conduct a Reliability, Availability and Maintainability (RAM) Analysis on the SRT. The analysis shall be submitted to COMPANY approval before completion of the engineering work and prior to the start of the execution work. Findings and recommendations from the analysis to meet the required target shall be binding for implementation by CONTRACTOR and will not constitute deviation to the Scope of Work.

8.10 Sparing and Obsolescence

CONTRACTOR shall design the SRT with hardware and software components which can be supported throughout the design life of the facility.

CONTRACTOR shall ensure that obsolete models are supported through sparing and product support throughout the design life of the SRT.


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8.11 Documentation, Measuring Units and Language

8.11.1 Drawings and Documents for Approval

Within thirty (30) days after the effective date, CONTRACTOR shall provide COMPANY with a complete list of document and drawings that will be developed, or evaluated during the engineering phase, which shall covered as minimum, but not limited to the following:

• General Arrangement Plan

• Hull lines

• Trim and bending moment as well as shear forces calculations for various loading conditions

• Tank plan, including location of domes, access and ventilation hatches

• Deadweight calculation

• Stability (intact & damage) for various loading conditions.

• Fatigue analysis calculations and results reports

• Docking plan

• Positive Materials Identification plan

• Cabin plan with accommodation arrangements

• Design Safety Assessment analysis reports

• Life-saving equipment/arrangement

• Structural plans (amidships section, scantling profile & decks, bulkheads, bow construction, foundation, crane foundations, cargo plant foundations, superstructures, etc.)

• Shell expansion

• Sloshing calculations in cargo tanks

• Calculations of the forces/stresses in way of cargo tank supports due to the interaction of double bottom and cargo tanks

• Cargo tank foundations supports as well as anti-pitching, anti-rolling and anti-floating chocks

• Structural drawings of main cargo tanks and cargo buffer tanks

• Cargo tank insulation

• Model tests

• Calculation of fixed and sliding points of cargo piping

• Heat transfer calculations of cargo tanks

• Calculation of the deluge spray system

• Bilge keel

• Deck cranes


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• Structural plans of masts, derrick booms, deck crane pedestals, bulwarks, etc.

• Foundations of process skids on main deck

• Safety Assessment Analysis

• Safety Integrity Level Assessment

• Automatic Identification System (AIS)

• Pressure Safety Valve Sizing Calculation

• Field Instrument (Transmitter & Control Valve) Sizing Calculation

• Corrosion protection scheme

• Coatings system

• Derricks and masts arrangement

• Deck mooring arrangements

• Piping arrangement on main deck & cargo tanks

• Piping schedule and practices

• Mooring quick release hook arrangement

• Hazardous Classification Areas above deck

• Accommodation ladder, davits, etc.

• General arrangement of Cargo Handling systems

• Arrangements of cargo tanks and cargo holds

• Regasification plant

• Vibration analysis for main cargo compressors

• Cargo piping diagram, PFDs, isometrics, 3D drawings, and P&IDs

• Cargo Pumps and cargo pumping system

• All piping diagrams, PFDs, isometrics and P&IDs

• Cargo tanks and cargo handling system venting arrangements

• Inert gas systems (Inert Gas Generator, N2 generator)

• Ventilation arrangement for machinery spaces

• Engine room general arrangement and midship deckhouse(s) machinery general arrangement.

• Ballast tanks

• Ballast piping system arrangement and P&IDs

• Sea valves arrangement

• Area classification


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• Fire and Gas detection systems

• Fire extinguishing systems

• Integrated ESD system

• F&G Cause and Effects

• Cargo System Cause and Effects

• Deck machinery plans

• Main electrical generators with prime movers

• All auxiliary machinery plans

• Dimensional outline and complete rating of all generators, transformers, motors, and controllers

• Load flow analysis of electric plant

• Short circuit calculation of the system

• Breakers Coordination study

• Outline and front view and connection and wiring diagram of main switchboard and distribution circuit including cargo control console, engine room control desk, cargo control room desk

• Diagrams of wiring system, including cable sizes, type of insulation, working current, type and maker of protective devices

• Calculation noise and vibration and analysis reports

• GA and PA system

• CCTV system arrangement ,wiring diagrams and connection diagrams

• Navigation lights & Nav. Aids arrangements

• Administration LAN system

• Antennas Arrangement

• Main cable tray arrangement in engine room, accommodation, upper deck, forward decks and aft decks

• 13.6-kV and 6.6-kV equipment arrangement, wiring diagrams and connection diagrams

• Electrical outfitting, glanding and cable termination practices

• MV cable termination and MV & LV earthing practices

• Arrangement of main cables and electrical apparatus

• Arrangement of lighting fixtures

• Arrangement of radio equipment in communication room

• Connection diagram and assembly outline of important electrical apparatus

• List of spare parts and tools


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• Automation diagrams and arrangements

• Power management system

• Vessel control functional analysis

• Equipment drawings, data sheets and manuals from main subcontractors/suppliers

• Torsional vibration calculations of auxiliary engines

• Cargo control room control desk(s) layout

• Engine room control desk(s) layout

• Cargo Transfer Custody Control Systems.

• Cargo tanks level measuring and monitoring systems.

• Deck arrangement.

• Hardware and software.

• Ballast tanks level measuring system

• Mooring analysis report

• Hull side strength analysis report

• Integrated Monitoring & Process Control System

• Overall Singe Line Diagram (for existing and new install equipment)

• Motor Starting Analysis

• Transient Stability Analysis

• Lightning Protection Zone Drawing.

• Sizing & selection on marine loading arm ( including fatigue assessment, due to continues operation)

• Sizing & selection on fender system

• Surge analysis on cargo piping, loading arm and any other related piping and equipment in case of emergency shutdown.

• HP LNG pump and driver sizing and selection

• LNG vaporization unit sizing and selection

• Lab analysis equipment shall be provided by CONTRACTOR

• Line sizing, piping 3D model

• Blowdown system analysis.

This list shall include the estimated dates for the submission of the documents to COMPANY and Classification Society for review and approval.

CONTRACTOR shall seek mutual agreement to agree on the necessary extension.


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CONTRACTOR shall provide COMPANY with copies of all technical correspondence CONTRACTOR will have and exchange with the Classification Society during the classification Society engineering review, Classification Society inspection and Classification Society certification of the SRT.

CONTRACTOR shall instruct the Classification Society to copy COMPANY with all technical correspondence the Classification Society will have and exchange with CONTRACTOR during the Classification Society engineering review Classification Society inspection and Classification Society certification of the SRT.

CONTRACTOR shall provide COMPANY with an exhaustive list of all drawings and engineering documents approved by the Classification Society that required their approval during the engineering and construction phases. This list shall include the estimated dates for the submission of the documents for review and approval.

If the drawings and technical information are returned to CONTRACTOR within the said time limit supplemented with remarks and amendments by CONTRACTOR and if the said remarks and amendments are not of such nature or extent as to constitute modifications or alterations, then CONTRACTOR shall start or continue production on the corrected or amended drawings and technical information. In case such remarks and amendments are not clearly specified or detailed, CONTRACTOR shall seek clarification from COMPANY prior to implementation of the said remarks, or amendments. Such a clarification shall be regarded as the start of a new review cycle for the subject drawing of technical document.

The format of the comments shall be agreed to between CONTRACTOR and COMPANY. CONTRACTOR shall be responsible for tracking and recording the actions necessary to satisfy COMPANY comments.

8.11.2 Measurement Unit and Language

The measurement unit system and language is defined in the BOD [1]. All name plates and notices, field and panel gauges, meters, computer readouts, etc. shall be described in English language.

8.12 As-Built Documentation

8.12.1 General

CONTRACTOR shall be fully responsible for the as-built of project documents, drawings and data and for the as-built and updating as necessary all existing documents, drawings and data.

CONTRACTOR’s Contract obligations shall not be considered fulfilled until as-built is completed to the satisfaction of COMPANY.

8.12.2 As-built Procedures

CONTRACTOR shall be responsible for as-built of drawings, documents and data as necessary throughout all phases of the contract including fabrication and installation activities.

During execution of each major activity CONTRACTOR shall monitor as-built activities for all disciplines and ensure that at completion of that activity a complete set of documents and/or drawings


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clearly marked ‘as-built’ is available. A master copy of each set of as-built marked-up drawings shall be maintained in a central location and be available to all interested parties.

As-built modifications shall be distributed to all affected parties. Where changes may have a significant impact on a subsequent phase CONTRACTOR shall revise the applicable drawings and re-issue ‘AFC’. CONTRACTOR shall maintain a log of all changes made after completion of AFC activities.

8.12.3 As-built Registers

CONTRACTOR shall, at the completion of the engineering activities prepare an ‘As-built Register’ of all project documents and drawings that require as-built and/or update for the scope of Work.

8.12.4 Schedule

CONTRACTOR shall include a detailed breakdown of as-built activities in the overall project schedule. CONTRACTOR shall accomplish such required activities for interface requirement.

CONTRACTOR shall have an designated interface manager, and interface management reports and updated schedules and progress reports shall be issued on a weekly basis to COMPANY.

8.12.5 Vendor Data

Notwithstanding the responsibility of CONTRACTOR to ensure as-built of vendor’s and subcontractor’s documents, drawings and data, CONTRACTOR shall be responsible for ensuring that all as-built vendor/subcontractor data is captured in CONTRACTOR’s as-built documents, drawings and data. There shall be no missing information or ‘holds’ on the as-built documents and drawings.

8.12.6 Final Documentation

CONTRACTOR shall provide the following document quantities:

a) 1 (one) original document;

b) 7 (seven) copies;

c) 7 (seven) CD-ROM/DVD copies.

CONTRACTOR shall provide final documentation including but not limited to:

a) Engineering deliverables including native electronic files;

b) As-built documents and drawings (to be agreed between COMPANY/CONTRACTOR);

c) Electronic files, including calculations, analyses document/drawing databases and engineering databases;

d) Statistical reports;

e) Contract HSE plans and reports;

f) Contract QA plans and reports;

g) Feedback on experience, continuous improvement recommendations, lessons learned;


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h) Manufacturing data books;

i) Procurement-related data;

j) Packing and shipping records;

k) Fabrication dossiers;

l) Installation dossiers;

m) Hydrostatic test dossiers/records;

n) Inspection and certification dossiers;

o) Pre-commissioning dossiers;

p) Commissioning dossiers;

q) Change control records;

r) Contract specifications and procedures;

s) All certification from Third Party Inspection and Governmental Authorities

t) Jamaican Government Approvals for Sales Gas Metering systems

CONTRACTOR shall store, for a minimum of three (3) years, all hard and soft copy documents and drawings.


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9 PROCUREMENT AND EQUIPMENT HANDLING

With the exception of COMPANY SUPPLIED ITEMS, (if any) CONTRACTOR shall be responsible for the procurement of all materials and equipment as required to complete the WORK. Procurement activities shall include, but not be limited to, the preparation of all material take-offs and requisitions, purchasing, expediting, reporting, materials receipt, inspection, testing, QA/QC documentation, vendor data, storage, preservation, security and transportation to CONTRACTOR’s yard.

In addition to the above, CONTRACTOR shall:

a) Prepare documentation as required for the importation of items into Jamaica, e.g., Master List, PIB, RIB as applicable

b) Arrange for and expedite delivery of all materials and equipment to Sites

c) Expedite suppliers’ final data and documentation

d) Ensure suitable storage, handling and preservation for all materials and equipment

e) Maintain a suitable efficient materials management system that provides full traceability of the intended use of materials and equipment and their specific movements and location

f) Arrange for the timely provision of supplier representatives to the various sites

g) Produce real time updates to the PMS and issue to COMPANY on a weekly basis

h) Ensure by stating in all bid enquiries and purchase orders/subcontracts that COMPANY personnel or its representatives have unrestricted access to documentation, and activities of supplier and Sub - CONTRACTOR premises for the purpose of expediting, inspection, general reviews, audits and the like.

9.1 Procedures

CONTRACTOR shall issue procedures for procurement, supplier/Subcontractor control, expediting, materials control, warehousing, and logistics within twenty (20) business days of the effective date for review and approval by COMPANY.

9.2 Procurement Plan

CONTRACTOR shall have a detailed Procurement Plan available as of the effective date. The Procurement Plan shall set out the philosophy, organization, scope, systems, corrective action procedures, and the like, that shall apply to CONTRACTOR’s procurement activities and how they shall be managed and effected in an efficient manner.

9.3 Procurement Master Schedule

Within twenty (20) business days of the effective date, CONTRACTOR shall submit its project specific PMS showing all known materials, equipment, and services to be procured. CONTRACTOR shall specifically highlight all items having a limited amount of schedule float.


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9.4 Materials Management

CONTRACTOR shall utilize proven systems and procedures, facilities, and sufficient resources, to identify, purchase, manage, and report on MTO requirements, shortages, materials, look ahead requirements, material-receipt, materials reconciliation, transportation, storage, preservation, warehousing, issuing, in-storage maintenance, and security of all CONTRACTOR’s Supply.

9.5 Subcontractors and Vendors

CONTRACTOR shall:

a) Ensure that all candidate Subcontractors and candidate vendors have been assessed and approved by COMPANY to verify their organisational & technical capabilities and their level of competence to fulfil the identified scope of work or scope of supply;

b) Review all candidate vendors’ documentation for compliance with contract quality requirements;

c) Determine the level of quality surveillance required in order to ensure the technical integrity of the product or service;

d) Manage all Subcontractors and Vendors to ensure their quality requirements are achieved in accordance with CONTRACTOR’s responsibilities under the Contract;

e) Engage all subcontractors and Vendors in the shutdown planning activities including workshops and brainstorming sessions

f) Conduct quality audits on subcontrators and vendors in accordance with CONTRACTOR’s audit plan; sufficient notification of CONTRACTOR’s intent to carry out vendor audits shall be given to COMPANY, to allow COMPANY to witness or participate in such audits.

9.6 Import/Export

CONTRACTOR is solely responsible for making all necessary arrangements and requirements for the proper and timely exportation from, importation into and re-exportation from any country of CONTRACTOR’s Supply, and the Work.

CONTRACTOR shall make all such arrangements and requirements including the payment of all applicable taxes, tariffs, levies, surcharges, fees and other charges. CONTRACTOR shall do so in a timely manner to meet the Contact Schedule and in accordance with all Applicable Laws.

Any errors, omissions or delays in, or resulting from, the import & re-export process will not be grounds for a change.

CONTRACTOR shall arrange payment for any import duties, customs clearance and the like applicable to items imported into Jamaica.

CONTRACTOR shall also prepare for submission to the Jamaican Customs and/or other Government Authority any reports required to account satisfactorily for the final disposition of all items imported permanently or temporarily for the Work. CONTRACTOR shall be responsible for ensuring that all relevant Export Compliance regulations are followed as per the relevant section of the pro-forma Terms and Conditions contained within the tender package.


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CONTRACTOR shall be responsible for all import/export activities and requirements related to customs clearance for the long lead items.


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10 MECHANICAL COMPLETION, TESTING AND TRIALS

10.1 General

During the engineering phase of the Work, CONTRACTOR shall develop a detailed plan for execution and documentation of the Mechanical Completion and Commissioning of the SRT, including gas trials. The plan shall address all technical, safety and environmental requirements together with the acceptance criteria for each of the tests and shall be submitted to COMPANY for review and approval.

CONTRACTOR shall include CONTRACTOR’s operations key personnel in the planning and execution of the mechanical completion testing and commissioning work onboard the SRT.

CONTRACTORs operations group is responsible to provide operational input to the project ‘testing and commissioning team’ and for co-approving the testing and commissioning procedures and co-accepting the mechanical completion, testing and commissioning results.

Prior to gas trials CONTRACTOR shall ensure all systems for the LNG handling and utility services shall be tested, inspected and conditioned ready to receive LNG products.

Gas trials procedures and plan execution shall be prepared by a specialized LNG engineering/manufacturing CONTRACTOR and shall be submitted to COMPANY and the Classification Society for approval.

CONTRACTOR shall supply all the equipment, power, facilities and materials, including LNG and all processed fluid required for the testing and commissioning of the SRT.

CONTRACTOR shall ensure the adequacy of the testing facilities, equipment and permits required for the testing and commissioning work.

All work, equipment, outfitting, piping, wiring and tanks shall be thoroughly tested to demonstrate proper operation and stability for the purpose intended in accordance with approved inspection and test plan.

CONTRACTOR shall notify COMPANY’s representative in due time, but with a minimum of 24-hours, of all planned inspections and tests including the ones requested by the Classification Society or Regulatory bodies or of those requested by COMPANY representative.

CONTRACTOR shall keep COMPANY informed at all times of the inspection Work program and of the testing and inspection methods intended to be used. By failure of notification, tests are to be repeated.

CONTRACTOR shall keep evidence of tests and inspection results which shall be the basis of its Mechanical Completion and Commissioning programs and project PQA/QC. CONTRACTOR shall keep auditable records of all inspection and testing Work.


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10.2 Hull and Deck

CONTRACTOR shall implement a construction work verification program that meets the requirements of the Classification Society as indicated in Section 8.6.2.

Verification of cargo tank capacities, tank capacity tables, and corrections for trim and list and cargo tank affects on stability (GMT and GML) shall be carried out and certified by an independent certifying party approved by COMPANY.

All hull and deck equipment shall be thoroughly verified and tested at each stage in the fabrication and installation:

a) Deck machinery (cranes, winches, etc.)

b) Mooring equipment and fittings (aligning, fit-up, etc.)

c) Coating

d) Piping systems

e) HVAC

f) Accommodation and associated systems and equipment

In addition to other related activities CONTRACTOR shall test the integration structure as a whole as per the requirements and to the satisfaction of standards of the IMO IGC Code and applicable IACS Classification Society Rules and Regulations for building vessels for the carriage of Liquefied Natural Gas in bulk.

10.3 Machinery and Cargo Systems

CONTRACTOR shall carry out functional test to all equipment and systems related to the SRT operations after vessel conversion/new-build has been completed and all inspection defects and Non Conformance Records (NCRs) from the work have been closed by CONTRACTOR’s QA/QC and COMPANY representatives.

Successful completion of function tests shall constitute the Mechanical Completion of each system.

CONTRACTOR shall be responsible provide the procedures for the implementation of Mechanical Completion. CONTRACTOR shall submit the procedures to Classification Society and COMPANY for review and approval.

CONTRACTOR shall carry out the Mechanical Completion functional tests in a logical sequence from bottom up system’s hierarchy and after all fabrication items have been successfully inspected and tested.

CONTRACTOR must undertake HAZAN, HAZOP and HAZID on all testing procedures for the testing operational conditions and shall define contingency procedures as required by safety analysis results.

Selected machinery and equipment shall be operated for a reasonable duration of not less than 72-hours continuous at full capacity and within the normal operating range and fluid flow.

Any machinery or equipment that cannot be tested due to lack of operating medium such as LNG Products shall be pressure tested in the fabrication yard with appropriate fluid or gas such as He/N2


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mixture. Performance testing shall be conducted by CONTRACTOR during Gas Trial or during commissioning.

All systems, including LNG piping, Safety, Utility, and their instrumentation shall be integrated to the overall SRT system’s Mechanical Completion, pre-commissioning and Commissioning work.

All Classification Society tests must also be performed as required by Classification Society.


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11 SRT TRANSPORTATION, INSTALLATION, HOOKUP, TESTING, COMMISSIONING AND OPERATION

11.1 Transportation

CONTRACTOR shall transport all the applicable materials, equipment, and fabricated items, together with any necessary tools, labour, plant, machinery and consumables, from the fabrication site(s) or vendor shops to the site.

CONTRACTOR shall perform all engineering and prepare all required drawings in accordance with the requirements of the CONTRACT specifications for any temporary works that may be required for the transportation of any items of the WORK. CONTRACTOR shall verify that all structures and equipment are able to withstand transportation forces as defined by the CONTRACT specifications and design basis.

CONTRACTOR shall obtain all licenses, permits, approvals, requirements, laws, regulations and other obligations from authorizations, as may be necessary from the local, provincial, regional, or national governments or other regulatory bodies.

11.2 Installation

11.2.1 General

CONTRACTOR shall complete all installation activities to meet requirements set out in approved project specifications and this Scope of Work.

CONTRACTOR shall provide all equipment, material, manpower and services required for the installation and tie-in of all equipment and piping including lifting equipment, supervision, labour, purge gas facilities and the like.

CONTRACTOR shall have qualified engineering personnel present during installation to provide assistance in assuring works are completed to approved detailed design drawings, specifications and procedures.

Prior to installation, CONTRACTOR shall ascertain if any existing items need to be relocated to accommodate the new equipment, and subsequently plan and carry out the relocation.

11.2.2 Installation Requirements

CONTRACTOR shall:

a) Maintain a continuous record of the sequence and the characteristics of each installation activity;

b) Confirm correct alignment of all equipment;

c) Ensure that the agreed monitoring and control measures are followed;


Page 56

d) Ensure all activities are carried out in accordance with drawings, specifications and procedures, using only qualified personnel and acceptable equipment and facilities as agreed with COMPANY;

e) Follow the approved installation sequence and obtain written approval from COMPANY prior to any deviation;

f) Perform lifting, lowering into position, and bolt-up of each item of equipment to its relevant foundation or support;

g) Be responsible for the supply of all specialist equipment necessary for installation.

h) Provide a full set of video and photographic records of the installation process for COMPANY records.

11.3 Performance Testing

CONTRACTOR shall provide a Performance Test Procedure Manual to COMPANY for approval. The Performance Test shall fully demonstrate that the facilities are capable of meeting the capacity throughput, utilities consumption and emissions levels as are indicated on the final approved for construction drawings, documentation and BOD [1]. Performance testing of the facilities shall be the responsibility of CONTRACTOR, including providing LNG and all processed fluid required for the test. A complete procedure shall be developed by CONTRACTOR and approved by COMPANY to ensure a valid test and complete documentation.

Performance testing shall be conducted at first opportunity of the start up of the plant. CONTRACTOR shall be required at CONTRACTOR’s sole cost to repair or replace as required any part or parts of the facilities that do not meet the performance as required. The performance test shall be conducted at a total gas send out rate as per BOD [1] for 3 x 24-hours period continuously.

After performance test, CONTRACTOR shall be able to assure total gas send out rate at any time. CONTRACTOR shall carry out any necessary remediation for this purpose.

11.4 Commissioning

CONTRACTOR shall develop, for COMPANY acceptance, a commissioning plan that shall detail how all required activities will be accomplished.

Upon completion of the installation, CONTRACTOR shall perform SRT Commissioning and testing according to the procedures prepared by CONTRACTOR during the engineering phase and approved by the Classification Society and COMPANY.

CONTRACTOR shall include CONTRACTOR’s operations key personnel in the execution of the commissioning work onboard the SRT. CONTRACTOR’s operations group is responsible to provide operational input to the project commissioning team and for co-approving the commissioning procedures and co-accepting the commissioning results.

CONTRACTOR shall define a detailed commissioning program that will lead to successful completion of Provisional Acceptance of the SRT after its installation in the field and have it submitted for COMPANY’s review and approval.


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CONTRACTOR shall perform, as minimum, the following testing and commissioning activities as applicable to the selected SRT and mooring.

a) Seek to minimize offshore activities;

b) Prepare detailed commissioning procedures and detailed start-up procedures for COMPANY acceptance;

c) Prepare final commissioning manuals that compile the detailed scopes of work and relevant acceptance criteria and certificates.

d) The cargo handling systems, (process, regasification, pumping, cargo custody transfer)

e) The marine ancillary systems, (ballast, seawater cooling, IG and N2 generation, freshwater generation and supply, HVAC, compressed air),

f) The power supply, power distribution and power management systems,

g) The onboard safety systems,

h) The control and instrumentation,

i) The “in field” safety and communications systems, including data transmission.

CONTRACTOR shall obtain the technical assistance of the manufacturer’s supplied equipment as well as from the equipment manufacturers of major SRT equipment components (refrigeration compressors and electric motors, regasification hardware, mooring system, cargo pumps, custody transfer control system hardware and software, vessel control system, fire and gas detection systems, CCTV system etc.) for the commissioning of these equipment.

This technical assistance must have started at an early stage when the commissioning procedures have been developed.

CONTRACTOR shall provide COMPANY with all test records for evidence of the successful completion of the commissioning and testing as a requirement to achieve required milestone.

11.5 As-Built Survey

CONTRACTOR shall perform a comprehensive as-built survey at the latest three (3) days after the completion of the installation of the SRT. CONTRACTOR shall provide As-Built Survey Report within 14 (fourteen) days for COMPANY approval.

11.6 Operation of SRT

The CONTRACTOR shall operate and maintain facilities in accordance with applicable Jamaican & international regulatory/permitting requirements, COMPANY-approved operating procedures and within the terms of end-user supply agreements. Refer to the FSRU Operating Philosophy for details [6].


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12 REFERENCES

[1] WorleyParsons, “Jamaican LNG FSRU, Basis of Design” 402010-00260-00-GE-0001.

[2] WorleyParsons, “Jamaican LNG FSRU, Request for Quotation: Technical Form of Bid”. 402010-00260-00-GE-RFQ-0002.

[3] WorleyParsons, “Jamaican LNG FSRU, Pipeline & ORF Scope of Work”, 402010-00260-00-GE-SOW-0005.

[4] WorleyParsons, “Jamaican LNG FSRU, Jetty Moored FSRU Functional Specification”, 402010-00260-00-MA-SPC-0005

[5] WorleyParsons, “Jamaican LNG FSRU, Regasification Plant Functional Specification” 402010-00260-00-PR-SPC-0001.

[6] WorleyParsons, “Jamaican LNG FSRU, 402010-00260-00-PR-SPC-0002, Pipeline and ORF Functional Specification

[7] WorleyParsons, “Jamaican LNG FSRU, FSRU Operating Philosophy” 402010-00260-00-MA-PHL-0001.

[8] WorleyParsons, “Jamaican LNG FSRU, Jetty Design Philosophy”, 402010-00260-00-MA-PHL-0002.

[9] WorleyParsons, “Jamaican LNG FSRU, Pipeline and ORF Operating Philosophy” 402010-00260-00-PR-PHL-0001.

[10] Jamaica LNG Road Show Presentation by Taylor- DeJongh dated March 2011





Not yet available





Appendix 4 Pipeline Route





Not yet available





Appendix 5 Preliminary Mooring Analysis





Not yet available





Appendix 6 Near-shore Storm Modelling





Figure Appendix 6.1: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Significant Wave Height from the East [14]





Figure Appendix 6.2: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Significant Wave Height from the South East [14]





Figure Appendix 6.3: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Significant Wave Height from the South [14]





Figure Appendix 6.4: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Significant Wave Height from the South West [14]





Figure Appendix 6.5: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Storm Surge from the East [14]





Figure Appendix 6.6: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Storm Surge from the South East [14]





Figure Appendix 6.7: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Storm Surge from the South [14]





Figure Appendix 6.8: SWAN Proposed Near-shore Modelling Results showing 1-in-100 Year Return Period Storm Surge from the South West [14]

Attachment 04 - Pipeline & ORF Scope of Work

GOVERNMENT OF JAMAICA: OFFICE OF THE CABINET JAMAICA LNG PROJECT - REQUEST FOR QUOTATION PIPELINE & ORF SCOPE OF WORK

Page 1

Jamaica LNG Project Pipeline & ORF Scope of Work

402010-00260-00-GE-SOW-0005

25th August 2011


Page 2

CONTENTS

1 INTRODUCTION ................................................................................................... 8

1.1 General ............................................................................................................................... 8 1.2 Nomenclature ...................................................................................................................... 8 1.3 Definitions ......................................................................................................................... 10

2 Project Overview and Main Features .................................................................. 11

2.1 Project Overview ............................................................................................................... 11 3 Company’s Role and Responsibilities ................................................................. 12

3.1 General ............................................................................................................................. 12 3.2 Personnel .......................................................................................................................... 12 3.3 Representative .................................................................................................................. 12

4 CONTRACTOR’s Role and Responsibilities ....................................................... 13

4.1 General ............................................................................................................................. 13 4.2 Endorsement of COMPANY Supplied Information ........................................................... 15 4.3 Pre-Engineering Surveys .................................................................................................. 15

4.3.1 Marine Survey ................................................................................................................................ 15

4.3.2 ORF Location ................................................................................................................................. 15 4.4 Met-Ocean Data ................................................................................................................ 16 4.5 Construction and Commissioning Scope Interfaces ......................................................... 16 4.6 Conformance of the Work ................................................................................................. 16

5 HSE Management ............................................................................................... 18

6 Environmental Design Philosophy....................................................................... 19

6.1 General ............................................................................................................................. 19 6.2 Environmental Management ............................................................................................. 19 6.3 Community Engagement and Interface Management ...................................................... 19

7 Management and Administration......................................................................... 21

7.1 General ............................................................................................................................. 21 7.2 Project Management ......................................................................................................... 21

7.2.1 General 21

7.2.2 Project Execution Plan ................................................................................................................... 22

7.2.3 Engineering Management .............................................................................................................. 22


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7.2.4 Fabrication Management ................................................................................................................ 23

7.2.5 Mechanical Completion and Commissioning Management ............................................................ 24

7.2.6 Installation Management ................................................................................................................ 24

7.2.7 Information Management ............................................................................................................... 26

7.2.8 Interface Management ................................................................................................................... 26

7.2.9 External Interface Responsibilities ................................................................................................. 27

7.2.10 Operations Readiness Management .............................................................................................. 27

7.2.11 Operator Training ........................................................................................................................... 27 7.3 Quality Assurance and Quality Control ............................................................................. 27

7.3.1 General ......................................................................................................................................... 27

7.3.2 Quality Actions Prior to Commencement of the Work .................................................................... 29

7.3.3 Quality Plan for the Entire Work ..................................................................................................... 29

7.3.4 Testing Equipment ......................................................................................................................... 29

7.3.5 Auditing ......................................................................................................................................... 30 7.4 Codes and Standards ....................................................................................................... 30 7.5 Office Facilities for Company’s Personnel at the Sites(s) ................................................. 30 7.6 Certification ....................................................................................................................... 30 7.7 Errors & Omissions ........................................................................................................... 30 7.8 Hierarchy of Technical Documents ................................................................................... 31

8 Engineering ......................................................................................................... 32

8.1 General ............................................................................................................................. 32

8.1.1 Process & Safety Engineering ........................................................................................................ 32

8.1.2 Process Simulation ........................................................................................................................ 32

8.1.3 Process Flow Diagrams (PFDs) ..................................................................................................... 33

8.1.4 Piping and Instrument Diagrams (P&IDs) ...................................................................................... 33

8.1.5 Studies and Calculations ................................................................................................................ 34

8.1.6 Process Data Sheets...................................................................................................................... 35

8.1.7 Cause and Effect Drawings ............................................................................................................ 35

8.1.8 System Design and Operating Manuals ......................................................................................... 35

8.1.9 Pressure Vessels and Heat Exchangers ........................................................................................ 36

8.1.10 HAZID and HAZOP Reviews .......................................................................................................... 36

8.1.11 Utilities ......................................................................................................................................... 36


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8.1.12 Process Safety Engineering ........................................................................................................... 36 8.2 Pipelines Engineering ....................................................................................................... 37

8.2.1 Pipelines Design ............................................................................................................................ 38

8.2.2 On-Bottom Stability Analysis .......................................................................................................... 38

8.2.3 Thermal Expansion/Contraction Analysis ....................................................................................... 38

8.2.4 Pipeline Spanning Analysis ............................................................................................................ 39

8.2.5 Cathodic Protection ........................................................................................................................ 39

8.2.6 Installation Analysis ........................................................................................................................ 39

8.2.7 Pipeline Route ................................................................................................................................ 39

8.2.8 Pipeline Burial Design .................................................................................................................... 39

8.2.9 Upheaval Buckling Analysis ........................................................................................................... 40

8.2.10 Certification .................................................................................................................................... 40

8.2.11 Safety and Loss Control Engineering ............................................................................................. 40

8.2.12 Pipeline Risk Assessment .............................................................................................................. 40

8.2.13 Environmental ................................................................................................................................ 41

8.2.14 Specifications and Data Sheets ..................................................................................................... 41

8.2.15 Installation, Cleaning and Testing Procedure ................................................................................. 41

8.2.16 Documentation for Independent Certification ................................................................................. 41 8.3 Civil/Structural Engineering .............................................................................................. 42

8.3.1 Soil Investigation ............................................................................................................................ 42

8.3.2 Site Grading and Drainage ............................................................................................................. 42

8.3.3 Foundation Design ......................................................................................................................... 42

8.3.4 Buildings ......................................................................................................................................... 42

8.3.5 Roads & Pavements....................................................................................................................... 42

8.3.6 Fencing ......................................................................................................................................... 42 8.4 Mechanical Engineering ................................................................................................... 43

8.4.1 Mechanical Studies ........................................................................................................................ 44

8.4.2 Equipment Layout .......................................................................................................................... 45

8.4.3 Computer Model ............................................................................................................................. 46

8.4.4 Equipment List ............................................................................................................................... 47

8.4.5 Rotating Equipment ........................................................................................................................ 47

8.4.6 Equipment Mountings..................................................................................................................... 47


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8.4.7 Equipment Weight .......................................................................................................................... 47

8.4.8 Maintenance Management System ................................................................................................ 47

8.4.9 Supplier Data ................................................................................................................................. 48

8.4.10 As-built Layout/Mechanical Equipment Drawings .......................................................................... 48

8.4.11 Pressure Vessels ........................................................................................................................... 48

8.4.12 Heat Exchangers ............................................................................................................................ 49

8.4.13 Safety and Firefighting Material Engineering ................................................................................. 49

8.4.14 Noise Level Mitigation .................................................................................................................... 49

8.4.15 Equipment Dossiers ....................................................................................................................... 49

8.4.16 Piping Engineering / Layout Design ............................................................................................... 50

8.4.17 Pipe, Valve, and fitting Catalogue Updating ................................................................................... 51

8.4.18 Piping Layouts ................................................................................................................................ 51

8.4.19 Piping Plans and Sections and Pipe Support details ...................................................................... 51

8.4.20 Piping Line List, Specialty Piping (SP) Items, and Tie-in Schedule ................................................ 51

8.4.21 Piping Isometric .............................................................................................................................. 51

8.4.22 Piping Material Engineering ........................................................................................................... 52

8.4.23 Piping Details ................................................................................................................................. 52

8.4.24 Metering Systems .......................................................................................................................... 52

8.4.25 Material Take Off (MTO) and Bill of Material (BOM) ...................................................................... 52

8.4.26 Piping Installation, Cleaning and Testing Procedure ...................................................................... 52

8.4.27 As-built Layout/Piping Drawings ..................................................................................................... 52 8.5 Instrumentation and Control Engineering ......................................................................... 54 8.6 SIL Review ........................................................................................................................ 55 8.7 Electrical Engineering ....................................................................................................... 55 8.8 Engineering Activities Related to Procurement ................................................................ 56 8.9 Engineering Activities Related to Materials ...................................................................... 56

8.9.1 Material Selection ........................................................................................................................... 56

8.9.2 Corrosion Protection....................................................................................................................... 57 8.10 Engineering Design Codes ............................................................................................... 57 8.11 Operations Involvement .................................................................................................... 57 8.12 Final Documentation ......................................................................................................... 57 8.13 Preparation of Manuals ..................................................................................................... 58 8.14 As-built Documentation ..................................................................................................... 58


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8.14.1 General ......................................................................................................................................... 58

8.14.2 As-built Procedures ........................................................................................................................ 58

8.14.3 As-built Register ............................................................................................................................. 59

8.14.4 Schedule ........................................................................................................................................ 59

8.14.5 Vendor Data ................................................................................................................................... 59 9 Procurement and Equipment Handling ............................................................... 60

9.1 Procedures ........................................................................................................................ 60 9.2 Procurement Plan ............................................................................................................. 60 9.3 Procurement Master Schedule (PMS) .............................................................................. 60 9.4 Materials Management ..................................................................................................... 61 9.5 Subcontractors and Vendors ............................................................................................ 61 9.6 Import/Export .................................................................................................................... 61

10 Fabrication & Line-Pipe Coating ......................................................................... 63

11 Construction/Fabrication ..................................................................................... 64

11.1 General ............................................................................................................................. 64 11.2 Skids and Spools – Transportation, Installation and Tie-in .............................................. 64 11.3 Size and Quality of Workforce .......................................................................................... 64 11.4 Fabrication ........................................................................................................................ 65 11.5 Fabrication Yard Facilities ................................................................................................ 65 11.6 Dimensional Control.......................................................................................................... 66 11.7 Logistics Plan .................................................................................................................... 66 11.8 Lifting & Rigging Plan ....................................................................................................... 66

12 Transportation, Installation, Commissioning and Operation ................................ 67

12.1 Transportation ................................................................................................................... 67 12.2 Pipeline Offshore Installation ............................................................................................ 67 12.3 ORF Installation ................................................................................................................ 68 12.4 Pre-Commissioning........................................................................................................... 69 12.5 Pre-Commissioning Procedure ......................................................................................... 69 12.6 Pre-Commissioning Equipment ........................................................................................ 70

12.6.1 Test Water Supply .......................................................................................................................... 70

12.6.2 Fill Pumps ...................................................................................................................................... 71

12.6.3 Pressure Pumps ............................................................................................................................. 71

12.6.4 Flow meters .................................................................................................................................... 71


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12.6.5 Pressure Relief Valves ................................................................................................................... 71

12.6.6 Test Header ................................................................................................................................... 71

12.6.7 Instrumentation .............................................................................................................................. 71

12.6.8 Piping Temporary Works ................................................................................................................ 72

12.6.9 Pig Design ...................................................................................................................................... 72 12.7 Requirements for Pre-Commissioning Activities .............................................................. 73

12.7.1 General ......................................................................................................................................... 73

12.7.2 Organisation and Personnel Qualifications .................................................................................... 74

12.7.3 Cleaning, Filling and Gauging ........................................................................................................ 74

12.7.4 Hydrostatic Testing ........................................................................................................................ 76

12.7.5 Hydrostatic Test Report .................................................................................................................. 77

12.7.6 Dewatering and Drying ................................................................................................................... 77 12.8 Documentation – Specific Requirements ......................................................................... 77 12.9 Commissioning ................................................................................................................. 77 12.10 As-Built Survey ................................................................................................................. 78 12.11 Performance Testing ........................................................................................................ 78 12.12 Operation .......................................................................................................................... 78

13 References .......................................................................................................... 79


Page 8

1 INTRODUCTION

1.1 General

The Government of Jamaica: Office of the Cabinet, acting on behalf of the Jamaica Gas

Trust (‘the COMPANY’) is seeking a private entity willing to finance, develop, own and

operate a complete FSRU-based LNG import terminal and natural gas reticulation

system in Jamaica (‘the PROJECT’). GOJ will provide the appropriate regulatory and

enabling framework to facilitate project development and operations, and will require

“steps-in-rights” should the infrastructure not be operated in a manner which guarantees

energy security for Jamaica. It is proposed that the investment will be recouped via

throughput charges for gas delivered to end-users.

The Jamaica LNG Project facilities comprise:

• Storage and Regasification Terminal (SRT);

• Gas Transmission Pipeline;

• Onshore Receiving Facility (ORF).

This document addresses only the Pipeline and ORF Scope of Work. It is intended to be

reviewed in conjunction with the Basis of Design [Reference 1] documentation and

relevant specifications. Bidders shall strictly follow the Basis of Design requirements.

Any deviations to the BoD shall be clearly spelt out in the Technical Bids.

1.2 Nomenclature

To ensure consistency, the following nomenclature has been used where applicable throughout this document. All other abbreviations will in the first occurrence include a full description.

AFC Approved for Construction




ASTM American Society for Testing Materials


DBB Double Block & Bleed

C&E Cause & Effect


DCS Distributed Control System



Page 9

ECS Engineering Consultant Services

EIA Environmental Impact Assessment

EMMP Environmental Monitoring and Management Plan


FAT Factory Acceptance Test

F&G Fire & Gas

FEED Front-End Engineering & Design

FSRT Floating Storage and Regasification Terminal

FSRU Floating Storage and Regasification Unit


GSA Gas Sales Agreement

HAZID Hazard Identification

HAZOP Hazard and Operability

HIPPS High Integrity Pressure Protection System

HSE Health Safety Environment

HVAC Heating Ventilation Air Conditioning

HX Heat Exchanger

ISO International Organisation for Standards

ITP Inspection and Test Plan

km kilometre


m metre

MAOP Maximum Allowable Operating Pressure

MMscfd MM (=106) Standard Cubic Feet per Day

MR Material Requisition

MSS Manufacturers Standardisation Society

MTPA Millions of Tonnes per Annum

MTO Material Take-Off

NDE Non-Destructive Evaluation



Page 10

P&ID Piping and Instrument Diagram


PDMS Plant Design Management System

PFD Process Flow Diagram

PHA Process Hazard Analysis

PL Pressure Letdown


ppm Parts Per Million

PSC Production Sharing Company

psig pounds per square inch (gauge pressure)

RFQ Request For Quotation

RTU Remote Transmission Unit

SIMOPS Simultaneous Operations


UKAS United Kingdom Accreditation Service

UPS Uninterruptable Power Supply

VDU Visual Display Unit

WPQT Welding Procedure Qualification Test

1.3 Definitions

COMPANY Government of Jamaica, acting on behalf of the

Jamaica Gas Trust

CONTRACTOR PIPELINE & ORF BOOT Contractor


“Will” is used normally in connection with an action by the COMPANY rather than by the CONTRACTOR.




“Must” is used only where a provision is a statutory requirement.


Page 11

2 PROJECT OVERVIEW AND MAIN FEATURES

2.1 Project Overview

The COMPANY has completed concept engineering for the SRT, Pipeline and ORF, and on this basis intends to proceed with the bidding process for the facility Build-Own-Operate-Transfer (BOOT) Contracts

This document outlines the scope of work and requirements for the Pipeline & ORF BOOT Contract, hereinafter referred to as “the WORKS”.

The base design case for the SRT is an FSRU moored at a nearshore, dual-berth jetty. The CONTRACTOR may choose to consider alternative mooring arrangement / terminal designs subject to compliance with design requirements detailed in this document and positive cost-benefit analysis relative to the base option. In the event an alternative mooring arrangement is proposed, the CONTRACTOR must demonstrate that the LNG supplier ‘supermajors’, particularly those active in the region these being BP, BG and Shell, will submit to mooring their LNGC vessels at the facility.

Refer to the BoD [Reference 1] and relevant functional specifications [Error! Reference source not found., Reference 7] and Philosophies [Reference 8, Reference 9] for details.


Page 12

3 COMPANY’S ROLE AND RESPONSIBILITIES

3.1 General

Involvement by COMPANY personnel is principally to monitor compliance with the requirements of the Contract, supervise fabrication and installation activities, and to verify the overall quality of the Work being provided.

Furthermore, COMPANY pursues the highest standards of safety and environmental practices and can offer guidance to CONTRACTOR in these areas.

3.2 Personnel

COMPANY will assign relevant personnel to monitor that the CONTRACTOR has completed all required activities prior to those relevant to construction, and until CONTRACTOR has fulfilled the Provisional Acceptance requirements (i.e., design, fabrication, transportation, installation, and commissioning). COMPANY will develop a program of formal assessment for onsite inspections to ensure that there is full compliance with its requirements.

3.3 Representative

Throughout the Project execution, COMPANY will have representatives at the fabrication yards, on-board installation spread and onsite for installation. These representatives will act as the contact point for CONTRACTOR in all matters relating to the fabrication and preparation for onshore and offshore activities.


Page 13

4 CONTRACTOR’S ROLE AND RESPONSIBILITIES

4.1 General

CONTRACTOR shall manage and execute all activities to ensure satisfactory performance and completion of the Work in all respects in accordance with the provisions of the Contract. CONTRACTOR shall ensure that it is fully informed regarding the planned and actual status of all work activities at all times. It shall promptly take pre-emptive and corrective actions required correcting or avoiding actual and potential deviations from the Contract requirements and objectives.

CONTRACTOR shall have an efficient management organization, fully supported by effective systems and procedures, to ensure all WORK is performed to fully meet the quality, schedule, safety, environmental and other requirements of the Contract. During WORK, CONTRACTOR shall complete the activities as described in this scope of works and in accordance with the Contract Master Schedule, and the provisions of the Contract.

Sixty (60) days prior to Provisional Acceptance, CONTRACTOR shall submit to COMPANY for approval a copy of the Operating Manual for the Pipeline and ORF.

The following sections of this Scope of Work serve to clarify the overall responsibility of the CONTRACTOR, however omissions of text on specific areas does not reduce the overriding scope of WORK stated above. COMPANY reserves the right to increase or decrease the CONTRACTOR’s scope of supply described in any documents, instructions or specifications issued by COMPANY to CONTRACTOR. The provision of all permits licences and the like required to perform the work are as follows:

1. Provision of requirements of any Governmental authority having jurisdiction over the work;

2. Certification and classification of CONTRACTOR provided equipment and the provision of associated certification documentation;

3. Factory Acceptance Test (FAT), Site Acceptance Test (SAT) and meter calibration activities;

4. Adequate site security and protection of the work;

5. Validation of the COMPANY supplied tender engineering documents

6. Design, Engineering, Supply, Commissioning of all items discussed in this document;

7. Perform HAZOP , HAZID, SIL and QRA of the facility;

8. Implementation of all scope in accordance with specified minimum HSE standards;

9. Implementation of all scope in accordance with specified minimum Quality standards;

10. Pre-engineering survey, pre pipe- lay survey, post pipe-lay survey;

11. Supply of line pipe, bends, flanges and all materials required to execute the pipeline Works;

12. Mob and Demob of survey vessels, work barges, pipe lay barge, Horizontal Directional drilling spread;

13. Pre-commissioning, commissioning, pigging, de-watering, hydro test;


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14. Completion of the Detailed Engineering and preparation of Approved for Construction (AFC) packages including the incorporation of approved vendor data;

15. Completion of detailed Construction Engineering associated with methodologies for fabrication, transportation, construction, installation, tie-ins, control system integration, and commissioning;

16. Specification, procurement, inspection, transportation, customs clearance and delivery to CONTRACTOR’s Work Sites of all CONTRACTOR Supply equipment and materials;

17. Engaging and managing the technical services of Vendor’s field service engineers during installation and tie-in and commissioning activities;

18. Assume full responsibility of the procurement activities of the long lead items upon handover, including witnessing & inspection, checking material certificates, logging receipt, recording stock numbers and delivery to CONTRACTOR’s Work Sites;

19. Supply all equipment, tools, material, personnel and other items necessary to complete all fabrication activities within a workshop environment;

20. Supply all equipment, tools, material, personnel (including all accommodation requirements) and other items necessary to complete all transportation, construction, installation and tie-in, pre-commissioning, and commissioning activities;

21. Provision of transportation for all CONTRACTOR’s and CONTRACTOR’s Subcontractor’s personnel throughout all surveys, construction, installation and tie-in, pre-commissioning, and commissioning activities;

22. All required construction works including equipment foundations, civil works for constructing roads and buildings;

23. Procurement, fabrication, FAT, Dry Calibration, Wet Calibration, transportation, installation, pre-commissioning and commissioning of skid mounted, 2 x 100% Sales Gas Metering System(s), complete with flow computing system and Gas Chromatograph as required by COMPANY’s prevailing sales gas contracts;

24. Procurement, testing, installation, and commissioning of all facilities required to complete the Work;

25. Fabrication, testing, pre-commissioning and installation of all pipe spools between equipment, and from equipment to the tie-in points;

26. Carrying out site work in a safe manner without causing any harm to personnel or COMPANY properties;

27. Provision of temporary power for the tools and equipment required for the construction, installation and tie-ins, pre-commissioning, and commissioning activities;

28. Site clean-up, reinstatement and material disposal during and upon completion of the Works;

29. Provision for all specified COMPANY requirements during implementation of the Work;

30. Provide support in the form of manpower, tools and equipment to Site Operations during live commissioning of the plant;

31. Final documentation, including as-built documentation.


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32. Manning, operation and maintenance of facilities in accordance with applicable Jamaican & international regulatory / permitting requirements, COMPANY-approved operating procedures and within the terms of end-user supply agreements;

33. Training of COMPANY operations’ personnel prior to facility transfer.

4.2 Endorsement of COMPANY Supplied Information

COMPANY has supplied a preliminary package consisting of a Basis of Design, preliminary line sizing for sub-sea pipeline and specifications for the new facilities within the tender document.

These documents identify the concept and approach required on these new facilities. CONTRACTOR shall be responsible to verify all information and data, and to resolve any conflict or omission in the information and data that has been supplied by COMPANY. CONTRACTOR shall accept full responsibility for the content and correctness of the preliminary engineering package at the time of submission of his bid.

Changes required after Contract award, resulting solely from the identification of errors or omissions or from failure by CONTRACTOR to perform sufficient analysis or review of supplied information shall not constitute reason for a change to the Contract Price.

4.3 Pre-Engineering Surveys

4.3.1 Marine Survey

COMPANY shall provide the initial results of geophysical and geotechnical survey conducted by a third party (who shall be APPROVED by COMPANY). However CONTRACTOR at his own cost shall conduct the detailed geotechnical survey at the proposed pipeline route and shore crossing. COMPANY expects CONTRACTOR to start the marine survey within 2 (two) weeks of letter of award.

The CONTRACTOR shall prepare the detailed specification for geotechnical survey and shall submit to the COMPANY for approval prior to commencing the field work. The detailed geotechnical survey along the pipeline routes shall include but not limited to following:

1. Cone penetration tests with pore pressure measurement (PCPT) continuously to a nominal depth of 10.0m bsl per kilometre along pipeline route.

2. For HDD section, bore hole tests to at least 10.0m deeper than the pipeline longitudinal route profile per 250m along pipeline route;

3. Piston sampling boreholes to a nominal depth of 10.0m bsl per 500m along pipeline route. For the shallow water and near shore (HDD section) bore holes shall be drilled to a nominal depth of 20m bsl.

The sampling is to start from 1m below sea level (bsl).

4.3.2 ORF Location

The geotechnical investigation at the ORF shall comprise:

1. 2 continuous cone penetration tests with pore water pressure measurement (PCPT) until 50m of original soil level.

2. 2 box core samples

3. 2 piston sampling boreholes until 50m of original soil level


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All the box coring and sampling boreholes shall be carried out within 10m of the cone penetration tests.

The CONTRACTOR shall also perform all necessary laboratory testing on samples collected during the marine survey.

The CONTRACTOR shall supply qualified surveyors (who shall be approved by COMPANY) to complete a pre-engineering survey of the Pipeline route corridor. The survey shall be completed and results supplied to COMPANY at least ninety (90) DAYS prior to commencement of installation activities. The pre-engineering survey shall confirm the proposed Pipeline route to the respective ORF location confirmed by CONTRACTOR and the following information at a minimum:

1. Absence of shallow gas, seabed subsidence;

2. The presence of debris, existing facilities, unexploded ordinance etc;

3. Seabed profile; and

4. Geotechnical data.

CONTRACTOR shall coordinate and liaise with Vendor representatives including arranging required site visit to ORF locations.

4.4 Met-Ocean Data

CONTRACTOR shall use available Met-Ocean Data available in the BoD [Reference 1]. However CONTRACTOR shall engage a reputable metocean data company to obtain detailed metocean data for the pipeline route corridor. CONTRACTOR shall obtain as a minimum the following data:

1. Windsea and swell hind cast data for the pipeline corridor;;

2. 1 year return condition, wind, wave and current;



5. Current vs. Direction;

6. Cross correlation between the current and seas and the persistence of these;

7. Tsunami data

8. Cyclones data

The data shall be of sufficient detail to allow pipeline and shore crossing detailed design activities.

4.5 Interfaces

The SRT CONTRACTOR and pipeline & ORF CONTRACTOR shall be jointly responsible for interface management during all phases of the WORKS, inclusive of design, construction, commissioning and operating activities. Scheduling of key activities shall be optimised across the contract interface to avoid Project delays.

4.6 Conformance of the Work

All Engineering, Procurement, Surveys, Construction, Fabrication, Installation Pipe laying, HDD works and tie-in, Pre-Commissioning, and Commissioning Work shall conform to the highest standards expected of international contractors engaged in the oil


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and gas industry, and the specific requirements of this Contract, and with the COMPANY-approved drawings, specifications, reports and procedures issued by CONTRACTOR.

All materials and equipment supplied to COMPANY by CONTRACTOR shall be new and in accordance with this Scope of Work, and with drawings, specifications, reports and procedures issued by CONTRACTOR and/or other contractors and approved by COMPANY.

The Work and all components thereof shall be engineered and designed for a seaside, marine environment.

No deviations from the COMPANY Supplied Data or CONTRACTOR issued engineering data approved by COMPANY are to be made by CONTRACTOR without prior written approval from COMPANY.


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5 HSE MANAGEMENT

Safety, health and environmental protection are core values of COMPANY. Without exception, CONTRACTOR shall pay the highest regard to health, safety, and environmental protection, in design and in performance of each phase of the Work, and shall conform to all HSE-related items of COMPANY supplied documents.

CONTRACTOR shall have the objective to complete the Work without accident or incident and is solely responsible for:

• Providing a safe and healthy working environment;

• The safe performance of the Work by all personnel, and

• Ensuring that awareness of the importance of safety is actively promoted and monitored with adequate training given to all personnel (including authorized visitors entering any of CONTRACTOR’s Sites)

• Ensuring that all CONTRACTOR personnel, subcontractor personnel and any vendor representatives and the like travelling to and working at the pipeline and ORF are provided the necessary safety training and PPE; this shall be included in the CONTRACTOR’s Contract Price

• CONTRACTOR shall ensure through the proper application of its environment protection procedures that the Work is:

o Managed, planned and engineered to minimize any impact upon the environment;

o Performed and completed without incidents detrimental to the environment, and

o Performed in full compliance with the Contract environmental policy objectives

The CONTRACTOR is expected to strictly adhere to COMPANY-approved Health, Safety and Environmental standards.


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6 ENVIRONMENTAL DESIGN PHILOSOPHY

6.1 General

CONTRACTOR will conduct its business with respect and care for the environment in which it operates and will comply with COMPANY-approved Safety, Health, and Environmental standards.

In carrying out our environmental policy, CONTRACTOR will adhere to the following application principles:

• Comply with all applicable Jamaican regulations.

• Conduct operations as a Reasonable & Prudent Operator (RPO) by ensuring no adverse impact to the area’s air and water qualities.

• Maintain overall quality of the facility that is equal to or better than the industry norm in the area with respect to environmental issues.

6.2 Environmental Management

CONTRACTOR shall pay the highest regard to protection of the environment and shall conform to COMPANY’s Health, Safety and Environmental Policies and other COMPANY Supplied Data. CONTRACTOR shall carry out environmental management to ensure that the Work is executed in such a way as to protect the environment to comply with all requirements of the Contract.

CONTRACTOR’s objectives are to ensure, through the proper application of its environment protection procedures that the Work is:

• Managed, planned and engineered to minimize any impact upon the environment,

• Performed and completed without incidents detrimental to the environment, and

• Performed in full compliance with the environmental policy objectives and the Contract requirements.

COMPANY, at its sole discretion, may audit CONTRACTOR’s performance of the Work to ensure that the Contract requirements for environmental management are being satisfied in all respects. Any audits that take place shall be based upon CONTRACTOR's own environmental management manual(s), procedures, and environmental management plan. CONTRACTOR shall take immediate action to correct any non-conformances identified.

Not less than ninety (90) days prior to the Commencement Date, CONTRACTOR shall advise COMPANY on all types of waste and the anticipated quantities that shall be generated during operations and on their recommended disposal procedures and their frequency.

6.3 Community Engagement and Interface Management

In executing the Work, the CONTRACTOR shall comply with the design and construction obligations placed on COMPANY in accordance with the EIA stipulations [Reference 5] and ensure that no activities associated with the Work are undertaken in a manner so as to compromise the standing and reputation of COMPANY with the local community and


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stakeholders. The CONTRACTOR shall take all actions necessary to ensure the CONTRACTOR's Personnel reflect the CONTRACTOR's obligation in this regard.

The CONTRACTOR shall endeavor to maximize the use of local labour where practicable.


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7 MANAGEMENT AND ADMINISTRATION

7.1 General

CONTRACTOR shall manage and execute all activities to ensure satisfactory performance and completion of the Work in all respects in accordance with the provisions of the Contract.

CONTRACTOR shall ensure that it is fully informed regarding the planned and actual status of all Work activities at all times. It shall promptly take pre-emptive and corrective actions required correcting or avoiding actual and potential deviations from the Contract requirements and objectives.

7.2 Project Management

7.2.1 General

CONTRACTOR shall have an efficient management organization, fully supported by effective systems and procedures to ensure that all Work is performed to meet fully the quality, schedule, safety, environmental, price and other requirements of the Contract.

CONTRACTOR shall provide:

• Sufficient numbers of suitably qualified and skilled personnel with relevant experience;

• Suitable facilities;

• A project management system with all necessary systems and procedures needed for the proper control and management of the Work;

• All other resources whatsoever required for the proper performance and completion of the Work;

CONTRACTOR’s project management responsibilities include:

• Overall management of the Work

• Interface management

• Quality management

• Safety management

• Environmental management

• Engineering management

• Procurement management and materials management

• Transportation, care and custody of COMPANY provided equipment for the duration of the Work.

• Load-out and transportation of the pipeline and ORF components from fabrication sites, [including sea-fastening and approvals] to CONTRACTOR’s local marine operations Site.

• Fabrication management

• Installation management


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• Compliance with the Contract Schedule

• Financial management

• Information management

• Regulations, certification, Classification and permitting

CONTRACTOR is responsible for the proper management and execution of the Work, wherever performed, and it shall have appropriate representation at all Site(s) to ensure the safe and timely performance of all elements of the Work in accordance with the quality standards and other requirements set out in the Contract. CONTRACTOR shall keep COMPANY fully informed at all times of progress and areas of concern.

COMPANY shall assist and advise CONTRACTOR as COMPANY, in its sole judgment, considers appropriate in relation to CONTRACTOR’s performance of the Work without this relieving CONTRACTOR in any way of its responsibilities, duties and obligations under the Contract.

7.2.2 Project Execution Plan

CONTRACTOR shall prepare a Project Execution Plan (PEP) for the Work, for COMPANY approval. This shall include the progressive development, for COMPANY’s acceptance of the various lower-level plans and other documents that are described in the execution plan and which address specific topics in greater detail. Such plans and other documents shall cumulatively set out all CONTRACTOR’s management, planning and scheduling, internal control, quality, safety and other systems and processes required to ensure the proper performance and completion of the Work in accordance with the Contract.

CONTRACTOR shall update the execution plan as necessary during the performance of the Work securing COMPANY’s acceptance of any proposed deviations prior to their implementation. A deviation will only be applicable where proposed actions fall outside the boundaries described in the execution plan. CONTRACTOR deciding, with COMPANY’s agreement, between alternative courses of action that are described in the execution plan along with full details of the basis on which the decision would be made in accordance with the agreed Contract Schedule, will not be considered as a deviation requiring updating of the execution plan.

CONTRACTOR shall carry out the entire Work in accordance with this execution plan.

7.2.3 Engineering Management

CONTRACTOR shall manage all engineering in relation to the Work, giving particular consideration to all requirements and interfaces of engineering, procurement, fabrication, installation, commissioning and start-up and performance testing.

As a requirement in the bidding process CONTRACTOR shall submit an Engineering Management and Engineering Execution Plan for COMPANY approval.

CONTRACTOR is responsible for the implementation of the requirements contained in COMPANY Supplied Data, and for all engineering required to fully satisfy its obligations under the Contract. CONTRACTOR shall not deviate from the COMPANY Supplied Data unless it has obtained COMPANY’s prior written acceptance of the proposed deviation in each case.

CONTRACTOR shall ensure that all engineering is performed fully in accordance with the Contract Schedule. CONTRACTOR shall perform general engineering and ensure all interfaces are properly identified and managed.


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CONTRACTOR shall designate engineering personnel who will have specific and continuous responsibility for engineering throughout all phases of the Work. Such personnel shall:

• Be assigned to the Work from the Effective Date or such other date early in the engineering phase as COMPANY may agree in writing for each position;

• Give input to and review CONTRACTOR’s engineering to ensure that this is carried out to secure the most efficient possible performance of the Work within their respective areas of responsibility;

• Be the designated Key Personnel.

Reassignment of Key Personnel without COMPANY’s express permission shall be subject to financial sanction.

CONTRACTOR shall also include in its organization adequate level of supervision at fabrication sites and provide appropriate personnel from its engineering organization to ensure the proper implementation of the design intent throughout the Work. Such personnel shall participate actively in the development of detailed procedures for, and in the execution of, all fabrication, hook-up, pre-commissioning, start-up, and performance testing activities.

CONTRACTOR shall ensure that there are always sufficient suitably qualified and experienced engineering personnel, acceptable to COMPANY, assigned to the Work to fulfil properly the responsibilities described above.

Concurrent with progressive completion of engineering required for procurement, fabrication, installation, transportation, hook-up, testing, commissioning, and start-up, CONTRACTOR shall commence preparation of its close-out report for each phase. The objective is timely completion and issue of the close-out report together with CONTRACTOR’s as-built reporting.

CONTRACTOR shall ensure that all engineering in relation to the Work conforms to all requirements of the Contract, including particularly those of the Marine Insurance Surveyor and Classification Society.

7.2.4 Fabrication Management

CONTRACTOR is fully responsible for the fabrication and the management of all fabrication and integration activities in relation to the Work.

CONTRACTOR’s project management organization shall include an experienced fabrication manager in place from the Effective Date. CONTRACTOR shall be specifically responsible for:

• The approval of all fabrication procedures;

• The safe and timely performance of fabrication activities at all Site(s);

• The care and custody of all goods and materials at each Site;

• Safe working practices at all Site(s).

CONTRACTOR shall ensure safe and timely performance of all fabrication in strict compliance with the Contract.

At each Site, CONTRACTOR shall have a management team fully capable of directing and supervising fabrication activities in order to achieve satisfactory completion in accordance with the Contract Schedule, and in accordance with safety, quality, and technical requirements.

At each site, CONTRACTOR shall ensure:


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• A safe working environment for all personnel;

• All facilities and equipment required for the Work are fit for purpose and carry appropriate certificates for use;

• Proper security against theft and unauthorized visitors;

• The quality of all Work meets the Contract requirements.

7.2.5 Mechanical Completion and Commissioning Management

CONTRACTOR is fully responsible for the Mechanical Completion and Commissioning activities in relation to the Work.

CONTRACTOR’s project management organization shall include an experienced commissioning manager in place from the Effective Date. CONTRACTOR Commissioning Manager shall be specifically responsible to define and organize Commissioning Work responsibilities and instructions for execution, administration, monitoring and recording of data throughout the implementation and certification of Commissioning activities up to handover to Operations.

CONTRACTOR shall form a Commissioning Group under the direct direction and supervision of the Commissioning Manager [Designated Key personnel] that shall operate as an integrated part of CONTRACTOR’s team and whose responsibilities include the execution of Pre-Commissioning and Commissioning of Dynamic Systems. CONTRACTOR shall submit a Pipeline and ORF Commissioning Plan and Mechanical Completion and Commissioning Plan to COMPANY for approval prior to commencement of any commissioning or mechanical completion activities.

CONTRACTOR shall provide labour, equipment, materials, supplies and utilities, including but not limited to temporary electrical power, diesel fuel, instrument air, potable water, etc., as necessary to perform all commissioning activities.

7.2.6 Installation Management

CONTRACTOR shall plan all details of its marine operations for the installation of the Pipeline and ORF to ensure they are carried out safely, efficiently, and in accordance with the Contract Schedule. CONTRACTOR’s detailed plans will be subject to COMPANY’s acceptance.

CONTRACTOR shall coordinate its marine operations with those of COMPANY’s field operations. The overall objective is to complete all operations safely in the shortest practicable time and with the most efficient use of vessels and equipment.

CONTRACTOR shall prepare a detailed installation plan and associated schedules. The plan shall outline all installation activities, durations, and shall include task sheets detailing all required vessels, materials, equipment and personnel needed to carry out the complete offshore installation and related operations. As a minimum, the installation plan shall detail the following information:

• Plan for mobilization and demobilization of all marine equipment, marine vessels, equipment, personnel and materials required to perform the Work in accordance with the specifications, drawings and Contract Schedule;

• Plan for pre-surveys;

• Plan for transporting the pipe-lay barge and line pipe to Port Esquivel;

• Plan for pipe-lay and trenching/backfilling operations;

• Plan for installation of HDD or pre-trench and push/pull method;


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• Plan for installation of ORF equipment;

• Plan for leak testing of the pipelines and ORF equipment;

• Detailed marine operations schedule covering all vessel movements and marine activities.

CONTRACTOR’s installation plan shall also address the following:

• Management of interfaces, physical or other, between the Work and field operations;

• Weather criteria and weather windows for all operations including monsoon weather periods;

• Details of all spreads and vessels including installation vessel, cargo barge and all vessels for anchor handling, tow, dive support, testing and pre-commissioning;

• Details of the facilities at the mobilization Site;

• Consumables and materials logistics;

• Tow required equipment and Navigation Aids.

• Survey and positioning requirements;

• Inspection requirements;

• Communications arrangements;

• Personnel qualifications, certification;

• Transportation and accommodation of personnel;

• Quality assurance procedures;

• As-installed survey procedure and report;

• HSE procedures;

• Contingency plans for all installation activities.

The installation plan shall incorporate all recommendations made by the Marine Insurance Surveyor, Classification Society, and COMPANY.

CONTRACTOR’s project management organization shall include an experienced Installation Manager. The installation manager shall be a Key person and shall be specifically responsible for:

• The development and approval of all mobilization and installation procedures;

• All mobilization activities;

• The safe and timely performance of all offshore installation activities;

• All marine activities.

CONTRACTOR shall prepare contingency procedures to ensure, in the event of any unforeseen circumstance or occurrence, that the mobilization and installation shall proceed without risk to personnel, CONTRACTOR’s Spread, existing structures and facilities in the field, and the SRT CONTRACTOR’s equipment and operations.

Each installation phase shall be subject to HAZID and HAZOP review as part of the procedure preparation, the results of which shall be incorporated into the procedures. CONTRACTOR shall conduct the HAZID and HAZOP reviews with participation from


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Classification Society, and Marine Insurance Surveyor, as appropriate. COMPANY, at its sole discretion, shall participate in the reviews.

CONTRACTOR shall ensure that all mobilization, installation and contingency procedures are submitted simultaneously to COMPANY and to the Marine Insurance Surveyor for approval.

CONTRACTOR shall make due allowance of the time necessary for the various reviews of mobilization, installation and contingency procedures leading to approval by the Marine Insurance Surveyor, Classification Society, and COMPANY. CONTRACTOR shall fully test the critical equipment and demonstrate to COMPANY that all are well functional before demobilization.

• CONTRACTOR shall ensure that CONTRACTOR’s Spread:

• Complies with the requirements of the Marine Insurance Surveyor;

• Is properly crewed and manned, equipped, provisioned and bunkered;

• Is properly certified and fit for purpose.

For all works adjacent to offshore facilities, CONTRACTOR shall ensure the documented Contract specific management system and safety plan complies with all relevant Health, Safety and Environment requirements, Permit to Work requirements and Emergency response/accident reporting requirements. CONTRACTOR shall cover all aspects of Work relating to HSE procedures in the simultaneous operations (SIMOP) procedure.

7.2.7 Information Management

CONTRACTOR shall establish a secure, Contract-specific, document and information management system. The information management system shall be capable of efficient distribution/dissemination, handling, filing and retrieval of all data and documentation in relation to the Work.

7.2.8 Interface Management

CONTRACTOR shall manage and coordinate Work-related interfaces, including all interfaces with COMPANY, and among CONTRACTOR Group. CONTRACTOR shall carry out all required interface activities to assure the successful execution of the Work and all interfacing work performed by other entities.

CONTRACTOR shall ensure that components at each physical interface are fully compatible in all respects, including but not limited to:

1. Engineering;

2. Materials and equipment supplied;

3. COMPANY provided Equipment;

4. Dimensions;

5. Fabrication;

6. Installation;

7. Pre-Commissioning.

CONTRACTOR shall manage the interfaces at the point of connection of the gas export pipeline to the SRT.

CONTRACTOR shall keep COMPANY fully informed at all times regarding its proposed schedule of interface meetings, and shall amend the schedule as necessary to take


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account of COMPANY’s comments. CONTRACTOR shall give COMPANY timely notice of all unplanned interface meetings.

COMPANY shall attend interface meetings at its discretion, but in any event CONTRACTOR shall keep COMPANY fully informed regarding the results of all meetings. CONTRACTOR shall include all Contract Group within interface meetings, as appropriate for the specific pipelines and riser components.

7.2.9 External Interface Responsibilities

An external interface register shall be submitted to COMPANY within twenty (20) Business Days from the Pipelines & ORF BOOT Contract award, for COMPANY’s review and approval. Upon COMPANY’s approval, CONTRACTOR shall issue the external interface register to all persons to whom CONTRACTOR has an interface obligation, or who have an interface obligation to CONTRACTOR.

The register shall identify the person (CONTRACTOR Group, COMPANY, or one of COMPANY’s other contractors) that has the primary responsibility for the management of individual interface items. All needed dates for information from one person to another, or for delivery of physical items, shall be agreed between CONTRACTOR Group, COMPANY and COMPANY’s other contractors.

7.2.10 Operations Readiness Management

As soon as possible after the Effective Date, CONTRACTOR shall engage with COMPANY Operations personnel to assess the requirements to merge CONTRACTOR’s Operations and Safety Management and Operations and Safety Management of the COMPANY.

CONTRACTOR shall present an Operation Preparedness Activities document to COMPANY for approval ninety days (90) prior to installation of the pipelines.

Sixty days (60) prior to the installation of the pipeline, COMPANY’s Corporate Operations shall audit CONTRACTOR’s Operations and Safety Management to assess its readiness and preparedness for operations integrated to the Jamaica LNG Management System.

CONTRACTOR shall achieve successful result of the audit program as a requirement to connect the SRT to the onshore gas network.

7.2.11 Operator Training

CONTRACTOR shall advise of manning requirements for the operation of the ORF and shall prepare an operator training plan 2 years in advance of the transfer of ownership / lease expiry date which is to be confirmed by the CONTRACTOR. The CONTRACTOR shall undertake operator training, in line with SIGTTO competency standards.

7.3 Quality Assurance and Quality Control

7.3.1 General

The CONTRACTOR shall be responsible for overall Quality Assurance and Quality Control (QA/QC) for all aspects of the WORK in accordance with COMPANY requirements, with the objective of eliminating defects, non-conformances and the need for remedial work. CONTRACTOR shall provide a QA/QC procedure for the WORK as an exhibit in the bid documentation for COMPANY approval.

CONTRACTOR shall perform the Work in full compliance with its quality assurance and safety management systems and provide COMPANY with adequate documentation in verification thereof.


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CONTRACTOR shall have a well established and widely utilized throughout its organization Quality Management System for use during the design engineering and construction of the SRT.

This System shall be acceptable to COMPANY and conform to the ISO 9000 series of standards or an equivalent internationally recognized standard to ensure that the Pipelines and ORF design, engineering and fabrication is properly managed and controlled.

CONTRACTOR shall provide a Quality Management System customized for the Pipelines and ORF design, engineering and fabrication that shall:

1. Set down the Quality Policy and objectives for the Pipelines and ORF design, engineering and fabrication.

2. Identify all relevant procedures, work instructions and the like to be applied and used by CONTRACTOR and main Subcontractors during the project. COMPANY shall have the option to review and comment on any such procedures, work instructions and the like. The procedures shall, be made available for COMPANY audit and/ or review at all times. CONTRACTOR shall supplement existing procedures or develop additional procedures, as may be necessary where COMPANY considers existing procedures are inadequate.

3. Provide a Project Quality Management Plan (PQMP), which shall show in logical sequence all of the activities required for the Pipelines and ORF design, engineering and fabrication. The activities shall be in clearly identifiable elements that allow ready determination of the inspection requirements for CONTRACTOR, and third parties as may be required. The PQMP will be a comprehensive management document detailing for each discipline the activities, codes, rules and regulations applicable to the Work, and shall include at the most detailed level the tools, equipment and materials required to enable the activities to be performed correctly and accurately. The PQMP shall specify or refer to a procedure that sets how to manage the interfaces within CONTRACTOR’s organization and with all other parties.

4. Set out a process whereby auditable records of compliance with the Quality Management System are maintained. CONTRACTOR shall define and operate a procedure for formally documenting any deficiencies in its quality system and for corrective actions and closure of such deficiencies. COMPANY reserves the right to suspend any or all of the work affected by a deficiency and/ or to reject any of the work so affected.

CONTRACTOR shall define and operate a formal procedure for documenting, registering and rejecting/approving any request for a deviation from the agreed technical specifications, materials or goods made either by CONTRACTOR or Subcontractors. Repair, refurbishment or acceptance of non-conforming materials shall be treated as a concession. Concessions shall be requested separately from and not through the technical query system. COMPANY shall be advised of all concession requests and the subsequent conclusions.

CONTRACTOR shall ensure compliance with the PQMP through conducting a predetermined series of internal and external audits. Each audit shall be recorded in an audit report comprising a checklist, associated findings and non-compliances (if any), with references to timing for re-audit of non–compliances after corrective actions. COMPANY shall have access to all such reports, and shall have the opportunity to participate in technical audits/ reviews during performance of the Work.


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7.3.2 Quality Actions Prior to Commencement of the Work

Prior to the commencement of Work at each Site, CONTRACTOR shall ensure through its quality system that:

1. All applicable systems, procedures and documentation are in place, and all personnel are fully familiar and complying with them;

2. All project document registers are established and maintained which list all of the relevant project documents comprising the Project Quality System and indicating their current status;

3. All correct engineering data is available including the latest revision of applicable drawings, specifications and other pertinent documentation;

4. All required testing and qualification of personnel and work processes, and all other prerequisites for Work to be allowed to start have been duly carried out;

5. Applicable engineering data and procedures have achieved AFC status;

6. The correct materials and all required resources are available;

7. All plant, equipment, facilities, and vessels are fit for purpose, certified, and suitable in every respect for the safe and satisfactory performance of the Work.

7.3.3 Quality Plan for the Entire Work

Within twenty (20) days of the Effective Date, CONTRACTOR shall submit its proposed quality plan for the entire Work to COMPANY. COMPANY shall review the plan and give its comments to CONTRACTOR within ten (10) Business Days from receipt.

Thereafter, CONTRACTOR shall:

1. Revise the quality plan to take due account of COMPANY’s comments;

2. Issue the COMPANY-accepted quality plan to COMPANY for immediate implementation after the Effective Date.

During the period between the Effective Date and finalization of the quality plan, CONTRACTOR shall manage and perform all aspects of the Work in compliance with COMPANY specifications and any COMPANY-approved documents that CONTRACTOR progressively develops.

The objective of the plan is to ensure the Work is performed and completed fully in compliance with the Contract requirements. CONTRACTOR shall plan and carry out a systematic program of audits and verification activities in support of the quality objective. Such program shall be subject to COMPANY’s approval.

CONTRACTOR shall manage the quality of the Work and shall adhere to and enforce its quality plan. CONTRACTOR shall take timely action to identify and correct deficiencies in CONTRACTOR’s quality system in order to avoid potential non-conformances, and correct actual non-conformances. CONTRACTOR shall at all times comply with its quality management system.

7.3.4 Testing Equipment

CONTRACTOR shall establish and maintain documented procedures to control, calibrate and maintain inspection, measuring and test equipment (including test software) used by CONTRACTOR to assure the safety or health of personnel, or monitoring of the environment. CONTRACTOR’s procedures shall comply with ISO 9001 and Contract requirements.


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7.3.5 Auditing

CONTRACTOR shall provide reasonable support and access during review and audits conducted in association with the Work, as may be undertaken by COMPANY and/or its representatives. Such reviews and audits may be directed at any part of the Work, including but not limited to performance and competency of personnel, management systems (including procedures and processes), HSE and quality matters, and records.

CONTRACTOR shall establish a schedule for audit of its own processes, procedures and personnel as may be related to the Work. CONTRACTOR shall seek concurrence from COMPANY of its audit schedule and CONTRACTOR shall provide COMPANY with a copy of all audit schedules in a timely manner. Furthermore, CONTRACTOR shall conduct audits on key Subcontractors/ Suppliers and any such audits shall be included in the audit schedule.

COMPANY shall have the option to participate in any such internal audits, excluding any audit or part of audit that may be of a proprietary nature to CONTRACTOR. COMPANY shall be promptly issued with a copy of all audits reports produced from such audits. Any non-conformance and corrective action identified from any review audit or as may otherwise be identified shall be promptly rectified by CONTRACTOR and/ or Subcontractors/ Suppliers.


The relevant codes and standards are provided in the Project BoD [Reference 1], specifications [Error! Reference source not found., Reference 6, Reference 7] and philosophies [Reference 8, Reference 9].

7.5 Office Facilities for Company’s Personnel at the Sites(s)

CONTRACTOR shall provide eight (8) workstations (desks, chairs) equipped with phone line (local and international), broadband internet access, PCs (loaded with Microsoft Windows and Office standard software packages) and independent A3/A4 colour printer and domestic power supply for the use of COMPANY personnel for the duration of the construction and commissioning phases of the WORKS.

7.6 Certification

The relevant certification is provided in the Project BoD [Reference 1], specification [Error! Reference source not found., Reference 6, Reference 7] and philosophies [Reference 8, Reference 9].

7.7 Errors & Omissions

CONTRACTOR shall understand that the drawings, specifications, and data sheets of COMPANY’s supplied Tender Engineering documents are not intended as detailed design or construction drawings and shall not be used as such.

It is an obligation of CONTRACTOR to check the CONTRACT documents, specifications, data sheets, and drawings and satisfy itself that it has sufficient information to plan and execute the WORK to the satisfaction of COMPANY. CONTRACTOR shall review the COMPANY supplied Tender Engineering documents and carry out FEED get it approved by COMPANY for the smooth progress of the WORK. CONTRACTOR shall give COMPANY notice in writing of deviations to COMPANY supplied documents and advise COMPANY of proposed actions with the reasons for such deviations.


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It will be CONTRACTOR’s responsibility to identify any conflicts in the COMPANY supplied documents. Should any error, omission or discrepancy appear in the drawings, specifications, instructions, or in other WORK done by others, CONTRACTOR shall notify COMPANY at once, and advise COMPANY of proposed actions to rectify same.

7.8 Hierarchy of Technical Documents

In the event of any technical conflicts between the various documents contained within the CONTRACT, the ranking of precedence for technical documents shall be:

1. Basis of Design;

2. Scope of Work;

3. Project Specification.

CONTRACTOR shall advise COMPANY of all conflicts and COMPANY shall decide resolution of same.


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8 ENGINEERING

8.1 General

CONTRACTOR shall perform all engineering necessary to provide Approved For Construction (AFC) design documents and drawings to be used during fabrication, construction, installation and tie-in, pre-commissioning, and commissioning.

All calculations and design documents / packages shall be submitted to COMPANY for review and approval.

CONTRACTOR shall perform necessary pre engineering surveys and site visit of the ORF before commencing the detailed engineering.

CONTRACTOR shall review existing soil investigation data prior to commencement of foundations design.

CONTRACTOR shall identify all engineering deliverables, in total and for each discipline, and compile a complete deliverables listing within twenty (20) Business Days after the Contract award. CONTRACTOR shall:

1. Diligently check all COMPANY Supplied Design Basis for inconsistencies, and advise COMPANY of same, and

2. Complete the engineering review and verification of the documents and drawings contained within COMPANY Supplied Design Basis and advise COMPANY of any identified errors

CONTRACTOR shall provide all documents necessary to certify the design of the Work and prepare all “as-built” drawings and data sheets to complete the certification of the installed Work to COMPANY’s and Governmental Authorities’ satisfaction.

The following list of studies and engineering tasks are not prioritized in order of importance or logical sequencing. CONTRACTOR shall perform these tasks in a logical sequence such that rework is minimized and important studies are completed first.

8.1.1 Process & Safety Engineering

CONTRACTOR will take full responsibility for all aspect of the process design from Contract Award. CONTRACTOR shall develop all aspects of process design to facilitate fabrication, installation, commissioning, start-up and operation, and environmental impact of the facilities in accordance with design criteria and functional requirement.

CONTRACTOR shall carry out all necessary process discipline design and engineering associated with the ORF and pipelines.

CONTRACTOR shall develop the process flow diagrams (PFDs), process data sheets, and piping and instrument diagrams (P&IDs) for to COMPANY Approval.

8.1.2 Process Simulation

CONTRACTOR shall develop simulation model(s) and heat and material balances for COMPANY review and approval. CONTRACTOR shall develop the steady state model(s) utilizing the latest version of HYSYS Process™ or other COMPANY-approved steady state simulation package.

CONTRACTOR shall maintain the process simulations, progressively incorporating the latest supplier and piping information, and updating the process design to accurately reflect the process simulation results. CONTRACTOR shall document the process simulation basis and results for COMPANY’s review and approval.


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8.1.3 Process Flow Diagrams (PFDs)

CONTRACTOR shall develop PFDs for COMPANY review and approval. These drawings shall show all relevant details including:

• Process and utility equipment, tag numbers, and interconnecting pipe work;

• Shutdown valves and location of blow down valves;

• Manual isolation valves (only if required to differentiate between operating modes)

• NC (normally closed) valves when required to distinguish normal flow path from alternate flow paths

• Major process control systems;

• Heat and material balances;

• Process equipment operating and design temperatures and pressures;

• Process equipment design capacity

• Vessel diameter and tan-to-tan length;

• Compressor driver brake horsepower;

• Compressor design (rate, horse power, etc)

• Special considerations such as insulation and heat tracing if critical to system performance

CONTRACTOR shall update the PFDs throughout the performance of the Work to include Supplier equipment data, as such data becomes available.

CONTRACTOR shall update all PFDs to “as-built” status.

8.1.4 Piping and Instrument Diagrams (P&IDs)

CONTRACTOR shall develop the P&IDs to “As-Built” status for COMPANY review and approval. The P&IDs shall include all relevant information including:

• Sizing of all piping based on detailed hydraulic calculations;

• Piping numbering, material specification, service, and insulation thickness;

• Valve and piping arrangements;

• Set points on all switches, shutdowns, and controllers;

• Instrumentation and control loops

• Signals to/from the control room and between package units

• Instrumentation type and control loop(s) and connection(s)

• Equipment design information;

• Confirmed supplier information;

• Details required by technical specifications;

• Relief valve set pressure, sizes and controlling relief scenario;

• Extent of heat tracing and insulation;


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• Control valve, shutdown valve and blow down valve size, failure position, and tag number;

• Manual valve size, interlocking requirements, and tag number;

• Material and pressure rating specification limit boundaries;

• Skid boundary limits;

• Unique tag numbers, including specialty piping items;

• All flanges shall be indicated to help future projects identify possible tie-in points. Note that any flanges added during fabrication, or hook-up & commissioning phases, shall be shown on the as-built drawings as well;

• Main process piping shall be indicated by heavier lines.

CONTRACTOR shall update the P&IDs throughout the performance of the Work to reflect the current design as it develops, and to include Supplier information as it becomes available. CONTRACTOR shall redraft all Supplier P&IDs, utility flow diagrams and such data into the same format required by the approved P&ID specification.

CONTRACTOR shall update all P&IDs to “as-built” status prior to Final Acceptance.

8.1.5 Studies and Calculations

CONTRACTOR shall perform as a minimum the following studies/calculations, which shall be submitted to COMPANY for approval.

Process Philosophies, Studies, Reports

CONTRACTOR shall perform:

• Capacity limitation study to determine the process, utility system or component that limits the maximum gas sales achievable.

• Develop and update documentation of overall process design conditions; and

• Prepare reports as required for securing approval by Governmental Authorities of relief and vent system, drain system, effluents and potable water system. The scope of the reports shall be developed during detailed design.

• Cold Vent Dispersion analysis, radiation studies and design report

• Environmental Impact Study

CONTRACTOR is responsible for preparing a report which identifies and quantifies facility emissions and discharges to the environment. The report shall address atmospheric emissions from power generation facilities as well as an estimate of flare emissions and discharges to the sea.

Start-up, Operating, Shutdown and Maintenance Procedures

CONTRACTOR shall develop detailed start-up, operating, shut-down and maintenance procedures for both the plant). Procedures shall be developed for all operating modes of the facilities, including Black Start.

Corrosion Review for Process Equipment and Piping

CONTRACTOR shall prepare the study and review the material selection determined by COMPANY in FEED and ensure material selection is suitable for intended service. CONTRACTOR shall perform all engineering design, taking full account of corrosion mitigation requirements.


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8.1.6 Process Data Sheets

CONTRACTOR shall prepare process data sheets for equipment and instruments for COMPANY review and approval. CONTRACTOR shall update the data sheets to reflect actual design conditions, equipment information provided by Suppliers, and any other design developments.

CONTRACTOR’S responsibility shall include, but not be limited to:

• Confirm or determine the size of all vessels

• Confirm final internals designed for the services,

• Listing process conditions, range of operations and connections.

• Sizing calculations for all in-line instruments such as pressure relief valves, control valves and flow elements

In specifying process data for sizing, operation, and mechanical design of any component, CONTRACTOR shall consider and determine the governing case (with supporting calculations) from the following:

• Start-up (black, warm);

• Shut-down (emergency, planned pressurized hold, depressurized);

• System performance test;

• Settle-out conditions;

• Field life-cycle changes.

Particular note must be taken of relief valve sizing requirements, which shall determine the governing case from blocked discharge, fire, gas expansion etc as applicable.

8.1.7 Cause and Effect Drawings

CONTRACTOR shall prepare Cause & Effect drawings for the facilities for COMPANY review and approval. These shall be updated as required to incorporate actual selected equipment information and any changes in the design.

8.1.8 System Design and Operating Manuals

CONTRACTOR shall prepare system design manuals for all process and utility systems for subsequent use by CONTRACTOR in preparation of systems operating manuals. These documents will be subject to COMPANY review and approval. Operating Manuals developed by CONTRACTOR shall address the ORF facilities. Operating manuals shall provide detailed information on each system. The system design manuals shall include the following:

• System description;

• System interfaces and dependencies;

• Utility consumption;

• Shutdown and start-up procedures (including black start);

• Equipment list and Supplier specific data;

• Line sizing basis;

• Instrument data including control, alarm and trip settings;


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• General start-up and shut-down operating guidelines;

• Relevant PFDs and P&IDs (A3 size);

• Document references.

8.1.9 Pressure Vessels and Heat Exchangers

CONTRACTOR shall develop vessel and heat exchanger data sheets for COMPANY review and approval. CONTRACTOR shall prepare detailed vessel data sheets suitable for vessel fabrication.

8.1.10 HAZID and HAZOP Reviews

CONTRACTOR shall be responsible for conducting HAZID and HAZOP reviews, close out of review action items and implementation into the design development accordingly.

8.1.11 Utilities

CONTRACTOR shall prepare and maintain a summary of the process utility requirements for COMPANY review and approval. This summary shall include, but not be limited to the following:

• Fuel and/or purge gas;

• Potable water;

• Utility and instrument air;

• Diesel;

• Electrical power;

• Nitrogen (bottles) if required.

CONTRACTOR shall review and update the utility requirements throughout the performance of the Work.

8.1.12 Process Safety Engineering

CONTRACTOR shall be responsible for ensuring that the design of the facilities incorporates all the findings and recommendations of Design Review, HSE Studies, (including HAZID and HAZOP), and with statutory environmental reporting requirements.

CONTRACTOR scope of work shall include implementation engineering activities (including outstanding HAZOP actions from FEED) and analysis of ALL high integrity safety systems (ESD, FGS, etc.) and document results as per IEC 61508. No safety study as per IEC 61508 has been documented to date.

CONTRACTOR shall develop safety deliverables for COMPANY review and approval. As a minimum, the following documents shall be produced:

• Hazardous Area Classification drawings

• Escape Route layouts

• Safety Equipment layouts including signs

• Fire Protection Equipment layouts

• Material Safety Data Sheet for all chemicals

• Safety Equipment List


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• Safety Sign Schedules

• Fire Protection Equipment List

• Specifications and Data Sheets for Fire Protection and Safety Equipment

CONTRACTOR shall perform dynamic transient analysis starting from the SRT outgoing pipeline and ORF. The main purpose of the transient analysis is to verify the metering header sizes particularly and evaluate shutdown systems and any HIPPS requirements. The transient hydraulic analysis shall include but not be limited to:

• Modelling both the SRT gas export pipelines and facilities at the ORF;

• Modelling the any proposed future additional equipment;

• Modelling the downstream piping to an acceptable level of detail, and;

• Completing sensitivity runs to verify the design, in particular in terms of shut-in requirements.

CONTRACTOR shall design, procure, and install acoustic insulation around pressure let down stations so as to ensure noise from the control valves does not exceed 85dB.

CONTRACTOR shall supply a fire water truck permanently on standby for the purposes of fire protection.

8.2 Pipelines Engineering

The CONTRACTOR shall perform the detailed design of the pipelines, PLEM and/or tie-in spool for the LNG SRT development, in accordance with the requirements of the BoD [Reference 1], contract specifications and statutory requirements of Jamaica.

The pipelines route is preliminary only and shall be finalised through detailed design to be completed by the CONTRACTOR. The quantity of the line-pipe to be used by CONTRACTOR, including pipes for Welding Procedure Qualification Test (WPQT), welder qualifications, spares, etc. The CONTRACTOR shall submit details of proposed pipelines lengths to COMPANY for approval. The CONTRACTOR's design shall include weight and joint coating (if required), corrosion protection, cathodic protection, pipe-laying, installation tie-ins, connection details and installation aids.

The CONTRACTOR shall ensure that the requirements stipulated in the governing codes and standards, specifications and documents concerning the design, construction, manufacturing, assembly, testing, supply, installation, and pre-commissioning of the pipelines are satisfied. All such equipment shall meet the acceptance criteria stipulated in the governing specifications with regard to proven design, trouble-free operation, and performance at the installation site.

All detailed design documentation shall be subjected to review and certification by the COMPANY appointed certifying authority.

The CONTRACTOR shall perform the following design activities and analyses as a minimum:

a. Verify the final pipelines route, taking into consideration to the potential for: 1. Shallow gas hazards;

2. Burial requirements;

3. Soft soils;

4. Wave pressure effects;

5. Seabed stability and subsidence;


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6. Debris;

7. Marine spread anchor requirements and shipping lanes;

8. The avoidance of pipelines freespan;

9. The minimization of seabed intervention and remedial works necessary.

10. Shore Crossing by means of HDD method or conventional shore crossing.

b. Produce all design documentation necessary for the pipelines including

mechanical design, stability design, buckling analysis, in-situ stress calculations,

specifications and installation analysis;

c. Verify the weight coating requirements to ensure on-bottom stability of the

pipelines;

d. Verify the pipelines corrosion coating and sacrificial anode/cathodic protection

system;

e. Verify the minimum burial depths and the method of pipelines trenching

methodology in accordance with EIA and Jamaican regulatory requirements;

f. Verify data sheets for all the material required for pipelines systems, including but

not limited to bends, flanges, anode, insulating joints, and valves; and

g. Verify the Material Take Off (MTOs) for the completion of all pipelines scope.

The CONTRACTOR shall interface with the COMPANY’s SRT CONTRACTOR to ensure the respective SRT facilities have adequate piping, vent and drainage for pre-commissioning the pipelines.

8.2.1 Pipelines Design

CONTRACTOR shall supply the following design criteria, analysis, calculations, and reports which outline the criteria and philosophies utilized in all aspects of the pipelines design. All criteria and designs shall be approved prior to proceeding with the subsequent detailed design activities. Reports shall as a minimum include a list of proposed software used.

8.2.2 On-Bottom Stability Analysis

CONTRACTOR shall develop an On-Bottom Stability Analysis report to determine the stability of the pipelines when subjected to environmental loading and to establish the weight coating requirements for the pipelines. Forces to be considered in the analysis include the pipelines submerged weight, hydrodynamic drag, lift, inertial forces (including wave and seismic), and soil friction. The design water depths shall be consistent with the on bottom stability analysis provided as COMPANY supplied documents.

CONTRACTOR shall submit the On-Bottom Stability Analysis Report for COMPANY review and approval.

8.2.3 Thermal Expansion/Contraction Analysis

CONTRACTOR shall complete pipeline analysis and confirm that the stresses induced by thermal expansion/contraction of the pipeline do not exceed the maximum allowable stress for the material used. For burial sections, upheaval buckling analysis shall also be carried out.


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The CONTRACTOR shall prepare a Thermal Expansion/Contraction Analysis report for COMPANY review and approval.

8.2.4 Pipeline Spanning Analysis

The CONTRACTOR shall perform Pipeline spanning analysis to determine the allowable free-span length. The determination of this length shall include vortex shedding requirements as per latest applicable DNV code. Appropriate consideration of design pressure and product weight shall be applied to ensure that the critical condition is analyzed.

The CONTRACTOR shall prepare a Pipeline Spanning Analysis Report for COMPANY review and APPROVAL.

8.2.5 Cathodic Protection

CONTRACTOR shall develop a cathodic protection system for the whole pipelines system (including HDD section). The cathodic protection system shall be based on a sacrificial bracelet anode system to meet the Facility design life (40 years).

The CONTRACTOR shall prepare a Cathodic Protection Design Analysis Report for COMPANY review and approval.

8.2.6 Installation Analysis

CONTRACTOR shall analyze the installation of the pipelines for laying from the CONTRACTOR’s proposed pipe lay barge to establish required tensions and stinger configuration. The analysis shall include but not limited to pipe head design, Horizontal Directional Drilling (HDD) laying analysis (or pre-trench and push/pull analysis in the case of traditional shore crossing), initiation and termination (with consideration of temporary lay-down and retrieval during severe weather), welding and NDT, anchor handling, tie-in spool installation and pre-commissioning. Soil analysis data provided by COMPANY will be analyzed by CONTRACTOR to determine if mattresses or other support mechanisms are required for temporary lay down.

The CONTRACTOR shall prepare an Installation Analysis report for COMPANY review and approval

8.2.7 Pipeline Route

CONTRACTOR shall propose designated optimal pipeline route for COMPANY review and approval, including carrying out any additional survey work at CONTRACTOR cost and shall subsequently make use of any up-to-date information obtained to analyse the trenchability of soils, the level of spanning and overstressing such that extent of seabed intervention by CONTRACTOR can be finalised. Finalization of the pipelines route shall have made maximum effort to avoid possible areas of marine traffic activity (subject to the outcome of the Pipeline Risk Assessment).

It shall be the responsibility of the CONTRACTOR to verify the suitability of the proposed route and ensure that there are no obstacles which would impede or adversely affect the installation or operation of the pipelines, such as wrecks, rock outcrops, holes, mines, wellheads, etc. Pipeline route planning shall avoid excessive seafloor gradients (less than 1°) that could be subject to movement due to hydrostatic and/or seismic induced forces.

8.2.8 Pipeline Burial Design

COMPANY requires that the pipeline is trenched to a minimum of 2.0 m above top of pipe for water depths under 13m (with an option for full pipeline burial along the route), and in accordance with Jamaican regulations. CONTRACTOR shall present calculations


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to demonstrate to COMPANY that his proposed trenching and burial equipment can meet these requirements. The CONTRACTOR shall also present calculations to demonstrate to COMPANY that appropriate buoyancy control measures (i.e. weight control and/or anchoring systems), if required, have been included in the pipeline burial design package.

The CONTRACTOR shall prepare a Pipeline Burial Design report for COMPANY review and approval.

8.2.9 Upheaval Buckling Analysis

As the pipelines will be buried below the seabed, analysis shall be carried out to assess the upheaval buckling potential of the pipelines. Liquefaction from wave and seismic effects shall also be considered.

8.2.10 Certification

It is the CONTRACTOR’s responsibility to obtain approval from the certifying authority for the design, fabrication and installation of the pipelines. The COMPANY will not accept any claim for delay from CONTRACTOR resulting from any delay as a consequence of the Jamaican regulatory approval process.

8.2.11 Safety and Loss Control Engineering

Safety, health, and safeguarding of the environment are core COMPANY values. The CONTRACTOR shall ensure that the work performed adopts a design approach that recognises the requirement to ensure that the facilities and associated pipelines provide As Low As Reasonably Practicable (ALARP) risk levels to offshore personnel. All costs for achieving this risk level are deemed to be included in the Contract price.

8.2.12 Pipeline Risk Assessment

The CONTRACTOR shall employ a specialist sub-contractor on behalf of COMPANY to perform a Pipeline Risk Assessment. The Pipeline Risk Assessment shall cover a 1 km corridor, consider the risks to the pipelines system and determine requirements for protection based on ALARP principles.

The Pipeline Risk Assessment shall identify all hazards affecting the operation of the pipelines (for example arising from shipping traffic, fishing activity, seismic activity, instability and other potential hazards), determine probable frequencies of occurrence of hazards and quantify such hazards as acceptable/unacceptable. For hazards involving unacceptable risk, the CONTRACTOR shall propose hazard mitigation measures and propose associated design value recommendations (for input to the design phase by others).

This study as a minimum shall cover the following: 1. Identification of all hazards to the pipelines due to normal shipping traffic and

fishing activities along the pipelines corridor, as well as other potential major hazards that may cause damage to the pipeline. As a minimum the following hazards shall be considered:

a. Riser - vessel impact; b. Expansion spool - dropped object; c. Seismic induced loads and slope instability; d. Fishing areas - trawling interaction with the pipelines; e. Shipping channel - anchor drag and impact; f. Shallow areas adjacent to shipping channels - vessel grounding;

2. Estimation of the probable size of vessels and anchors involved in anchoring of vessels along the pipeline corridor;


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3. Establish the possible failure modes for each threat identified on the pipelines and identify where along the pipelines the failure mode is applicable;

4. Undertake qualitative consequence analysis of the hazardous scenarios to determine the magnitude of the risk and estimate probable size of vessels, anchors, dropped objects, fishing gear, etc;

5. Undertake a frequency analysis to determine the likelihood of occurrence of the identified scenarios;

6. Qualitatively estimate risk levels due to ship, vessel traffic impact and other potential identified hazards by combining the results of the consequence and the frequency analysis,

7. Provide recommendations on potential mitigation measures for the high consequence scenarios to reduce the risk in accordance with ALARP principles. Hazard mitigation recommendations do not include engineering of protective means.

The Pipeline Risk Assessment study report shall be fully traceable, and shall provide results in a form that can be used in further decision making process. The Pipeline Risk Assessment report should contain complete information and should be read as a stand alone document.

8.2.13 Environmental

In completing the Work, the CONTRACTOR shall comply with the design obligations placed on COMPANY in accordance with the Jamaican process. The CONTRACTOR shall be solely responsible for design verification in accordance with Jamaican environmental laws, rules and regulations.

8.2.14 Specifications and Data Sheets

The CONTRACTOR shall design pipeline flange and bolting details to accommodate hydraulic torque requirements. Hydraulic bolt torqueing shall be used on all process gas and process liquid connections and generally as required by the COMPANY supplied documents.

The CONTRACTOR shall verify and endorse the MTOs and bulk bills of material items for the following:

1. Linepipe and bends; 2. Anti corrosion and concrete weight coating 3. Insulation Joints; 4. Weld Neck and Swivel Flanges; 5. Anodes 6. Bolts and Nuts; and 7. Gaskets.

8.2.15 Installation, Cleaning and Testing Procedure

The CONTRACTOR shall prepare a detailed procedure for installation, hook up and re-commissioning of the pipelines for COMPANY approval. This procedure shall include hydrotest P&ID drawings showing blinds, vents, temporary jumpers, drains and fill connections, test pressures, testing media, test zone boundaries and test legend. The procedure shall also detail instrument removal and re-instatement, recording instrument locations and requirements, purge and hydrostatic fluid volumes and pressures, valve operating positions, identification and sequences, and a detailed execution schedule.

8.2.16 Documentation for Independent Certification

The CONTRACTOR shall obtain approval and certification of the design from an independent certifying authority.


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8.3 Civil/Structural Engineering

8.3.1 Soil Investigation

CONTRACTOR shall obtain necessary geotechnical and geophysical data to facilitate design of the ORF.

8.3.2 Site Grading and Drainage

CONTRACTOR to confirm extent of fill required for both elevation and plan area.

CONTRACTOR shall prepare drawings and detailed designs to show site grading and drainage plans to ensure that surface water will not accumulate on the site. Surface run off shall be arranged so that contaminants from the process will not flow to the local water shed.

All trenches in areas that are utilized on a regular basis for operation and maintenance shall be covered with steel grating or suitable covers to ensure safety of personnel.

8.3.3 Foundation Design

CONTRACTOR shall prepare foundation designs suitable for equipment, pipe racks, buildings, structures, and miscellaneous supports. All foundations for major equipment and other major loads subject to settlement shall be piled. As a minimum, all major vessels, towers, packaged equipment, flare/ Vent tower and communication, storage tanks and buildings, shall be piled. Piling is also required for all pipe supports between the pipe racks and equipment. If spread footing and piling type foundation is used for other items, fill and compaction shall be done to suitable levels to support intended load.

CONTRACTOR shall consider the requirement for piles for smaller loads based on the soil test data and provide pile foundation as required, based on meeting acceptable minimum long term settlement requirements.

CONTRACTOR to consider that all load bearing supports will be piled.

8.3.4 Buildings

CONTRACTOR shall prepare all necessary drawings, specifications, and documents required for building design and construction. CONTRACTOR to take into account local soil conditions:

1. Foundations for all buildings shall be piled.

2. Buildings shall be designed in accordance with the Functional Specification for Building. Construction and shall be in accordance with Building Work specification.

8.3.5 Roads & Pavements

CONTRACTOR shall design and build internal plant roads that connect to the external roads. Hard surfacing shall be provided where indicated for areas such as the car park.

8.3.6 Fencing

CONTRACTOR shall provide adequate security fences around the plant site (i.e. fencing details and MTO etc)

Civil/Structural Detailed Engineering deliverables shall include, but not necessarily be limited to:


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1. Construction specifications and procedures for civil/structural, roads and building works;

2. Composite lay-out of underground utilities;

3. Detailed drawings of underground utilities;

4. Foundation location plans;

5. Detailed drawings of equipment foundations;

6. Detailed drawings of miscellaneous foundations;

7. Structural drawings of access-ways;

8. Structural drawings of miscellaneous supports;

9. Structural calculations of equipment foundations;

10. Structural calculations of miscellaneous foundations;

11. Structural calculations of miscellaneous steel supports/ access-ways;

8.4 Mechanical Engineering

CONTRACTOR shall complete mechanical engineering work needed to design, procure, fabricate, and install equipment required for the facilities.

CONTRACTOR shall comply with the COMPANY supplied Design Basis to develop complete engineering, design, installation and test requirements, and detailed equipment specifications for all facility mechanical, safety, and special piping equipment. The information developed by CONTRACTOR shall be used for procurement of all such equipment. CONTRACTOR shall incorporate all supplier data into the design as such data becomes available.

CONTRACTOR shall ensure to meet requirements stipulated in the governing Specifications and Documents concerning Design, Construction, Manufacturing, Assembly, Testing, Supply, Erection, and Commissioning, and proving performance guarantee of the Equipment covered under the various units.

All the equipment shall meet the acceptance criteria stipulated in the governing specifications, with regard to proven design, trouble-free operation, and performance at site. The reference list meeting the above shall be obtained from each equipment supplier for COMPANY’s approval by the CONTRACTOR.

Updating of COMPANY-Supplied Specifications/Preparation of the specifications:

1. While specific guidelines pertaining to individual equipment and packages are given in the general equipment specifications, following general considerations shall be kept in view for all items while formulating their specifications and also in subsequent procurement and engineering activities:

2. Reliability in service (assessed from OEM’s relevant Track Record and improved by incorporating certain minimum design features or requirements in the specifications).

3. Compliance with applicable national or international codes (or equivalent codes of other countries) and standards as well as any statutory regulation/local regulation in existence for a specific item.

4. Ease of operation and maintenance, including any necessary measures for ensuring safety of personnel and equipment, as well as acceptable working environment.


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5. Standardization of components.

6. Adherence to any limitations of space available for the equipment and its operation/maintenance.

7. Facility for future expansion/phased construction with a minimum of modifications or shutdown.

8. Equipment shall be designed for the given tropical site conditions.

9. Pressure vessels, pumps, compressors/blowers, and other equipment, piping, instrumentation and electrical works, wherever applicable for the equipment, shall be engineered as per the requirements specified in the respective sections of the tender specifications.

10. The design pressure, temperature, corrosion-resistance and other conditions of operation should in no case be inferior to the applicable codes and standards.

8.4.1 Mechanical Studies

CONTRACTOR shall perform, and issue for COMPANY review, all necessary studies required to satisfy both CONTRACTOR and the COMPANY that key engineering issues have been fully assessed. All requirements arising out of the studies shall form part of CONTRACTOR scope including, but not limited to, the following:

Material selection

CONTRACTOR shall develop a Materials selection report for the process requirements. for COMPANY review and approval.

Noise and Vibration Studies

CONTRACTOR shall develop an overall noise prediction profile, and shall ensure that noise limitations imposed by industry and Jamaican standards, are not exceeded. CONTRACTOR shall incorporate supplier information into the prediction model. CONTRACTOR shall implement noise insulation, or other measures as required, to reduce noise levels to acceptable levels.

Vibration analyses shall be performed as required for piping connected to rotating equipment and supports to prevent resonance. Updates to the calculations shall be performed to incorporate actual purchased equipment details and to ensure safe levels of stress and loads. CONTRACTOR shall determine which piping will operate under severe cyclic conditions, and shall these conditions accordingly in the design, fabrication, installation and testing of such piping.

CONTRACTOR shall perform an acoustically-induced vibration study to ensure that the flare and blow down piping has sufficient strength and ample fatigue life (i.e. at PSV and BDV tailpipes etc.)

Mechanical and material handling study including Maintenance access and area requirement piping of congested configurations.

CONTRACTOR shall identify the size and number of hoists, monorails, and other handling equipment, ensuring that operational efficiency and safety-related aspects are satisfied. CONTRACTOR shall prepare Material Handling Report for COMPANY review and acceptance, and compile a manufacturer’s list for procurement of the equipment.


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8.4.2 Equipment Layout

The technical documents include a preliminary layout of the process units, utilities, and buildings. The functional engineering design has confirmed that the area allocated is sufficient to house the necessary piping and equipment that may be utilized for these services except for the cold vent tower location, which needs to be further studied by the CONTRACTOR during detail engineering

A HAZID workshop shall be performed by the CONTRACTOR in conjunction with COMPANY prior to finalising the equipment layout

CONTRACTOR shall develop a detailed plot plan showing every individual equipment item and listing it by tag name on the plot plan. This plot plan is to be optimized taking into account actual factors that impact the layout on the actual plant site.

CONTRACTOR shall prepare/obtain from Supplier, layout drawings, based on supplier data as applicable, showing design concepts for skid-mounted equipment packages. The drawings shall provide information on skid dimensions, layout of major equipment (e.g., vessels, pumps), control panels (with areas reserved for access), junction boxes, skid pan drain connections, maintenance areas, and edge of skid connections for piping, access areas, ladders, platforms, stairs, and maintenance areas. The layouts shall be developed into detailed skid drawings, suitable for fabrication, transportation, and installation.

CONTRACTOR shall produce detailed equipment interface schedules for all disciplines in order to coordinate interface details with others.

CONTRACTOR shall ensure that:

1. All control elements and monitoring devices are to be readily visible and accessible to the operator in a manner that does not force an operator into a dangerous or precarious situation.

2. All handling and lifting equipment (fixed and portable) shall be identified by CONTRACTOR, and Material Handling Report shall be prepared accordingly for COMPANY approval. Moving or removal of heavy equipment components or parts for servicing or overhaul (including heaviest piece for major overhaul, as defined by equipment supplier) can be performed by the use of crane, monorail, davits, portable sturdy hoist sets, hand trucks, or other necessary handling equipment as per mechanical handling report approved by COMPANY.

3. Maximum unencumbered clearance shall be considered in the equipment layout for removal of equipment parts for all maintenance and overhaul activities.

4. Access is provided for movement of bulk consumables to user maintenance equipment.

5. Safe operator egress during emergencies including clear fire fighting access is provided.

CONTRACTOR equipment layouts shall be submitted to COMPANY for review and acceptance. Layout drawings shall include dimensions, layout of major equipment, control panels, junction boxes, pipe racks, cable trays, tubing bulkheads, maintenance areas (pull areas for exchangers, panel access areas, maintenance areas, etc.), ladders, platforms, stairs, walkways etc. CONTRACTOR shall develop the layouts into detailed drawings, suitable for fabrication.

CONTRACTOR shall complete a detailed material handling plan which ensures that clearance and lift capability are provided for in equipment layout for all operation, maintenance and overhaul activities. This plan shall require acceptance by COMPANY.


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8.4.3 Computer Model

CONTRACTOR shall develop all designs utilizing a 3-dimensional, PC based, process plant modelling software program such as Plant Design Management System (PDMS). CONTRACTOR’s software selection shall require COMPANY acceptance. The 3-D design modelling shall be implemented during initial stages of engineering. The 3-D model shall be continuously updated to as-built status and shall be delivered to COMPANY as part of the final documentation.

COMPANY shall be provided with electronic access to the program output on a real time basis. The final 3-D as-built design shall be provided to COMPANY as part of Agreement close-out. CONTRACTOR’s software selection shall require COMPANY acceptance.

Within the 3D model development, datum benchmark points shall be established to an accuracy of +/-15 mm to allow COMPANY to capture 3-D laser measurements for future interface connections.

All catalogues, specifications, and supplier equipment data shall be incorporated. The PDMS model shall be part of the final documentation deliverables.

CONTRACTOR shall prepare MTOs and bulk bills of material, including piping SPs, from the 3D model for the following:

1. Ball Valves

2. Check/NRV valves

3. Blow down Valves

4. Gate Valves

5. Globe valves

6. Butterfly valves

7. Bolts and Nuts

8. Gaskets

9. Material MTOs for all carbon steel piping including any LTCS

10. Material MTOs for all CRA Piping

11. PSVs

12. GRE/HDPE Pipe and Fittings

13. Strainers

14. Deluge sprinkler nozzles

15. Liquid drain traps

16. Sample connections

17. Pipe support spring hangers

18. ESD Valve Assemblies

19. Pipe Supports

CONTRACTOR shall prepare the following drawings:

1. Piping GA’s/plot plans, key plans, isometrics and elevation CAD drawings


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2. All small bore piping hook-up drawings including details of connections for instruments and sample connections.

8.4.4 Equipment List

CONTRACTOR shall develop the equipment and packaging datasheets. CONTRACTOR shall also revise the datasheet formats as appropriate so that they are consistent with the datasheet formats provided in the latest edition of Applicable Codes and Standards.

CONTRACTOR shall develop and maintain a comprehensive listing of all equipment throughout its performance of the WORK.

8.4.5 Rotating Equipment

The ORF will have items of rotating equipment such as air compressors and water pumps. CONTRACTOR shall prepare complete equipment data sheets for this equipment and ensure that detailed design takes into account all requirements for rotating equipment, both supplied as part of a skid or as stand-alone items. CONTRACTOR shall ensure that operations and maintenance requirements have been considered in the design and location of rotating equipment.

8.4.6 Equipment Mountings

CONTRACTOR shall prepare an equipment hold-down plan. The plan shall outline details of connections, hold down bolting details, grouting of the equipment, equipment vibration considerations, and use of pads. This plan shall be kept fully updated at all times, incorporating any changes. CONTRACTOR’s hold-down plan shall include all COMPANY and supplier requirements and shall be maintained throughout the Work, incorporating any changes from receipt of new supplier data and for other reasons. CONTRACTOR shall issue a final plan to COMPANY for review and acceptance prior to any equipment installation.

8.4.7 Equipment Weight

CONTRACTOR shall confirm equipment weights (dry, operating and test) for all equipment items. CONTRACTOR shall regularly update this information as actual equipment data becomes available and design details are developed and shall be incorporated into a civil design report.

8.4.8 Maintenance Management System

CONTRACTOR shall compile a composite time-based schedule and check list for lubrication and fluid changes for all equipment. The CONTRACTOR shall maintain a Maintenance Management System (MMS) on behalf of the COMPANY. CONTRACTOR shall also provide basic equipment data for COMPANY review and acceptance and insertion into the MMS as follows:

1. PO number and Supplier’s reference;

2. Equipment serial numbers and tag numbers;

3. Recommended time based schedule of maintenance activities;

4. Priced spare parts lists;

5. Supplier names, addresses, phone/fax/e-mail numbers;

6. Equipment description.


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8.4.9 Supplier Data

CONTRACTOR shall submit supplier document list identifying the documents for COMPANY review and Information. CONTRACTOR shall issue all vendor documentation to COMPANY for review/information.

CONTRACTOR shall review and approve all Supplier drawings, reports, etc. to ensure they are in accordance with COMPANY’s requirements. CONTRACTOR shall seek and take account of COMPANY comments during all document reviews.

CONTRACTOR shall prepare a complete and comprehensive list of proposed spare parts for two years operation for supplied equipment. This list shall include details of insurance spares or minimums, and guaranteed stock levels of replacement equipment, held within the region by selected, tagged equipment vendors. Common spares shall be identified for identical equipment to minimise the inventory.

In addition to the COMPANY’s requirements, CONTRACTOR shall provide COMPANY with 1 (one) copy of all vendor data manuals, complete with recommended spare parts lists and maintenance recommendations, prior to FAT. Further, in addition 1 (one) copy of vendor documentation including operating manuals shall be submitted to COMPANY when received from vendor but not later than at the time of installation of equipment.

8.4.10 As-built Layout/Mechanical Equipment Drawings

CONTRACTOR shall develop layout/mechanical equipment drawings to as-built status for COMPANY review and approval. This responsibility shall include development of supplier data catalogues and a facility 3D model or models.

8.4.11 Pressure Vessels

CONTRACTOR shall be responsible for the detailed design of all the vessels and tanks. The work to be performed by CONTRACTOR shall include, but not necessarily be limited to the following:

1. Verify and confirm the size of all the vessels and tanks.

2. Confirm the internal design required for each of the services.

3. Detail vessel design calculations.

4. Detail vessel drawings and data sheets.

Detailed vessel and tank design calculations and drawings shall be submitted for COMPANY review and approval prior to fabrication.

The general design of pressure vessels shall incorporate the requirement that all connections shall be flanged and that no vessel connections shall be less than 2” nominal. Inspection openings of a minimum of 12” are to be provided on any vessel that does not have a manway.

All pressure vessels shall be designed, fabricated and certified in accordance with the requirements of ASME Section VIII, Division 1 or 2 requirements. CONTRACTOR shall be responsible for checking all manufacturers’ vessel calculations, materials of construction, welder qualification records and weld procedures, and submitting these items to COMPANY for acceptance, prior to fabrication.

Design as per ASME Div. 2 is not mandatory for vessel having thickness above 50 mm as ASME Div. 1 design is acceptable. CONTRACTOR shall evaluate vessel fabricator capabilities and propose the fabricator for COMPANY approval.

A valid U2 stamp is required for Div. 2 vessel manufacturer with the approval of professional engineer for vessel certification.


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All carbon steel nuts and bolts on piping, tanks and vessels shall be galvanised instead of Cadmium plated as specified within various specifications.

Requirements as stated in the BoD, [Reference 1] shall apply for the galvanising.

8.4.12 Heat Exchangers

CONTRACTOR shall be responsible for the detailed design of all heat exchangers. Process data sheets shall be developed for each service. Design of all exchangers shall include a 10% increase of the surface area that is required for the specific application. In Air Cooled Heat Exchanger Design, 10% margin shall be added to the surface area (to cover outside fouling from air, debris and deposits on tubes). Further 10% shall be added for “design margin” – “design margin” = (“Z” x 110%) x 110%.

All heat exchangers shall be designed and fabricated in accordance with the requirements of ASME Section VIII, Division 1 or 2/TEMA & ASME rules for heat exchangers. CONTRACTOR shall be responsible for checking all manufacturers’ calculations, materials of construction, welder qualification records and weld procedures, and submitting these items to COMPANY for acceptance, prior to fabrication.

CONTRACTOR shall ensure that maintenance access and required supports are included in the design of exchangers, to ensure that tube cleaning, bundle replacement etc., can be carried out without interference due to other piping and equipment.

All carbon steel nuts and bolts on piping, tanks and vessels shall be galvanised instead of Cadmium plated as specified within various specifications.

Requirements as stated in the Basis of Design, [Reference 1] shall apply for the galvanising.

Air Coolers shall be equipped with bug screens to prevent fouling of the fin tubes. Detailed drawings of the Bug Screen structure, support and framework shall be approved by COMPANY.

8.4.13 Safety and Firefighting Material Engineering

The requirements for Safety and Fire Fighting studies are covered under section 11 below. Based on the study requirements, the CONTRACTOR shall detail all data sheets, specifications, and RFQ in conjunction with safety, piping, and materials engineering. CONTRACTOR shall implement an equipment numbering system in accordance with COMPANY requirements.

8.4.14 Noise Level Mitigation

CONTRACTOR shall ensure that all equipment shall have noise levels within the limits specified in the relevant Contract specifications. Any special design requirements to mitigate noise level to the specified limit shall be incorporated by CONTRACTOR at no additional cost to COMPANY. The noise study report shall be submitted to COMPANY for approval.

8.4.15 Equipment Dossiers

CONTRACTOR shall prepare dossiers for all mechanical equipment. These documents shall be presented to COMPANY for acceptance.

CONTRACTOR shall develop complete engineering, design, installation and test requirements and detailed equipment specifications for all Contract items in compliance with COMPANY-supplied functional specifications [References 10 & 11]. CONTRACTOR shall incorporate all Vendor data into the design as such data becomes available.


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All aspects of engineering and design shall incorporate operability, maintainability, and reliability.

CONTRACTOR shall carry out all necessary detailed mechanical discipline design and engineering including procurement and construction support. Mechanical deliverables shall include, but not be limited to:

1. Equipment Lists

2. Data Sheets

3. Specifications

4. Material Handling Report

5. Bidders List for Equipment Procurement

CONTRACTOR shall update the data sheets to reflect actual design conditions, equipment information provided by Vendors, and any other design developments. Where data sheets specify “Vendor Standard” or “Manufacturer Standard”, CONTRACTOR shall evaluate whether Vendor or manufacturer standard is acceptable for design conditions, and provide conclusions for COMPANY approval. Where “Vendor Standard” or “Manufacturer Standard” is deemed to be unacceptable, CONTRACTOR shall revise data sheets with appropriate requirements.

CONTRACTOR shall use Microsoft Exce l to de ve lop a nd ma inta in a compre he ns ive lis t of all equipment throughout its performance of the Work. This list shall contain weight data on each item of equipment. CONTRACTOR shall ensure that COMPANY has ready on-line, read-only access to the current version of CONTRACTOR’s equipment lists at all times.

CONTRACTOR shall complete a detailed material handling plan and this plan shall require approval by COMPANY.

CONTRACTOR shall compile a check list for maintenance activities for all equipment. This shall include, but not be limited to the following information:

1. Purchase order number and Vendor’s reference;

2. Equipment serial numbers and tag numbers;

3. Recommended time based schedule of maintenance activities;

4. Priced spare parts lists;

5. Vendor’s names, addresses, phone/ fax/ e-mail number;

6. Equipment descriptions;

7. Vendor data.

CONTRACTOR shall review and approve all Vendor drawings, reports, etc. to ensure they are in accordance with COMPANY’s Specifications. CONTRACTOR shall seek and take account of COMPANY comments during all document reviews.

CONTRACTOR shall prepare dossiers for all mechanical equipment. These documents shall be presented to COMPANY in accordance with COMPANY specifications.

CONTRACTOR shall develop pre-commissioning and commissioning procedures for all equipment and packages.

8.4.16 Piping Engineering / Layout Design

CONTRACTOR shall review, verify completeness, and update all necessary layout/piping discipline design and engineering associated with the plant.


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CONTRACTOR shall utilize design information provided in the COMPANY Supplied Design Basis to complete the plant layout/piping design.

8.4.17 Pipe, Valve, and fitting Catalogue Updating

CONTRACTOR shall verify and revise pipe, valve, and fitting material specifications in the 3-D model including supplier catalogues for the various process and utility systems.

8.4.18 Piping Layouts

CONTRACTOR shall prepare detailed piping layouts to define the piping routing within the plant site. The layout shall be developed taking into consideration access and clearance for maintenance of the equipment installation, safety considerations, and code requirements. Piping layout shall generally allow for grade access to all operating valves. Valves that are located at elevations more than 1.5 meter above grade require platforms and caged ladder access for operation and maintenance. Piping layouts shall consider the most efficient and logical layout of piping minimizing use of fittings and extraneous piping run. Pipe runs shall be only in vertical and horizontal planes. All vents shall be taken to flare or a safe location, depending upon the properties of fluid to be vented. For all equipment located on grade level, the height of foundation shall be minimised for easy accessibility. When it is not possible to do so, suitable working platform shall be provided around the equipment for ease of operability and maintenance.

Drawings shall incorporate actual purchased equipment data. CONTRACTOR shall ensure pipe and cable corridors are identified early in the design to avoid pipe, cable tray, and structure clashes.

8.4.19 Piping Plans and Sections and Pipe Support details

CONTRACTOR shall prepare piping plan, section, and pipe support detail drawings for all plant piping, with sufficient detail to define pipe routing, pipe support locations, slopes, valve locations and orientation, insulation, instrumentation, control device installations, show equipment clearance and access provisions. Drawings shall incorporate actual purchased equipment data.

CONTRACTOR shall develop the standard pipe support details.

8.4.20 Piping Line List, Specialty Piping (SP) Items, and Tie-in Schedule

CONTRACTOR shall prepare piping line list showing piping class, size, process conditions, insulation, connections and hydrostatic test requirements for each line.

CONTRACTOR shall prepare specialty items list, specifications, and datasheets to define performance parameters and connection details for the items.

CONTRACTOR shall prepare tie-in schedule to capture and monitor all piping tie-ins to interfacing facilities.

8.4.21 Piping Isometric

CONTRACTOR shall prepare isometric drawings for lines shown on the piping plans and sections. The piping isometrics shall show dimensions, material take-off, field welds and piping components in suitable detail for fabrication. CONTRACTOR shall prepare isometric spool drawings to expedite ease of fabrication, material control, and spool control during fabrication and installation. Field run Isometrics shall be required for piping smaller than 2 inches NPS. It shall include overall dimensions only and material list.


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8.4.22 Piping Material Engineering

CONTRACTOR shall develop pipe, valve and fitting material specifications for the various process and utility systems for review and approval by COMPANY.

CONTRACTOR shall design piping flange and bolting details to accommodate hydraulic bolt tensioning and hydraulic torque requirements. Hydraulic bolt tensioning/torque shall be used on all process gas and process liquid connections.

CONTRACTOR shall detail all valve data sheets in conjunction with process and mechanical/materials engineering. CONTRACTOR shall implement a valve numbering system in accordance with COMPANY requirements.

8.4.23 Piping Details

CONTRACTOR shall prepare drawings showing details for vessel and equipment trim, including instrument connections, level bridles.

CONTRACTOR shall provide pipe support and installation details for review and approval by COMPANY.

CONTRACTOR shall design all meters and metering systems to provide for easy and convenient calibration of all meters.

8.4.24 Metering Systems

CONTRACTOR shall design all meters and metering systems to provide easy and convenient calibration access and, if applicable, in full compliance with prevailing Jamaican and internationally-recognised regulations and requirements.

8.4.25 Material Take Off (MTO) and Bill of Material (BOM)

Material Take Off (MTO) shall be prepared for each isometric and all the bulk piping material which is not included in the Isometrics. All the MTO’s shall be consolidated into a Bill of Material (BOM) for procurement.

8.4.26 Piping Installation, Cleaning and Testing Procedure

CONTRACTOR shall prepare a detailed procedure for installation, flushing, hydro-testing, air test, purging, pressurization, and chemical cleaning of piping. This procedure shall include hydrotest P&ID drawing showing blinds, vents, temporary jumpers, drains and fill connections, test pressures, testing media, test zone boundaries, and pipe test legend. The procedure shall also detail instrument removal and reinstallation, recording instrument locations and requirements, purge and hydrostatic fluid volumes and pressures, valve operating positions, identification and sequences, and a detailed execution schedule.

8.4.27 As-built Layout/Piping Drawings

CONTRACTOR shall develop all layouts, piping drawings, isometric drawings to as-built status. CONTRACTOR shall complete the engineering and design equipment layout incorporating comments of the HAZOP and HAZID workshops. The deliverables resulting from Piping engineering/ Layout Design shall include, but not be limited to the following:

1. Pipe valve and fitting material specifications

2. Piping Line List

3. Specialty Piping (SP) items


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4. Tie-in Schedule

5. Piping 3D Layout drawings in PDMS

6. Piping Plans

7. Piping Sections

8. Pipe Support Details

9. Piping Fabrication Isometrics and Spool Drawings

10. Valve Datasheets

11. Pipe Stress Analysis Reports

The piping line list shall show piping class, line number, size, process conditions, operating & design condition, insulation, connections and hydrostatic test requirements for each line.

The tie-in schedule shall capture and monitor all piping tie-ins to interfacing facilities, defining the tie-in details, testing requirements and piping specification breaks.

The piping layout drawings shall define general pipe routing and equipment layout to show equipment clearance and access provisions. Drawings shall incorporate actual purchased equipment data. CONTRACTOR shall ensure pipe and cable corridors are identified early in the design to avoid pipe, cable tray, and structure clashes.

CONTRACTOR shall prepare piping plan, section, and pipe support detail drawings for all equipment and piping, with sufficient detail to define pipe routing, pipe support locations, slopes, valve locations and orientation, insulation, instrumentation, control device installations, show equipment clearance and access provisions. Drawings shall incorporate actual purchased equipment data.

CONTRACTOR shall prepare isometric drawings for lines shown on the piping plans and sections which shall be used during fabrication. The piping isometrics shall show dimensions, material take-off (including piping component size, number of material and material of piping component), testing requirements, and piping components in suitable detail for fabrication. CONTRACTOR shall prepare isometric spool drawings to expedite ease of fabrication, material control, and spool control during fabrication and installation.

CONTRACTOR shall design piping flange and bolting details to accommodate hydraulic bolt tensioning and hydraulic torque requirements. Hydraulic bolt tensioning/ torque shall be used on all connections.

CONTRACTOR shall provide pipe support and installation details for review and approval by COMPANY.

CONTRACTOR shall prepare detailed procedures for hydrostatic testing to be carried out in an offsite workshop environment, and installation, flushing, leak testing and purging, and pressurization to be carried out at the ORFs. The procedures shall include P&ID drawings showing blinds, vents, drains and fill connections, test pressures, testing media, test zone boundaries and pipe test legend. The procedures shall detail instrument removal and reinstallation, recording instrument locations and requirements, purge and N2 gas volumes and pressures, valve operating positions, identification and sequences, and a detailed execution schedule.

CONTRACTOR shall complete all valve data sheets in conjunction with process and mechanical/ materials engineering.

All design requirements, such as general and special requirements, valve operations, valve type, body and internals design, auxiliary requirements, dimensions, end


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connections and materials shall comply with the project specifications, applicable codes and standards.

CONTRACTOR shall implement a valve numbering system in accordance with COMPANY’s specifications.

CONTRACTOR shall prepare layout drawings, based on Vendor data as applicable, showing design layouts for equipment packages. The layouts shall be detailed drawings, suitable for fabrication, transportation and installation. The maximum unencumbered clearance shall be considered in the equipment layout for removal of equipment parts for all maintenance and overhaul activities.

CONTRACTOR equipment layouts shall be submitted to COMPANY for review and approval. Layout drawings shall include layout of major equipment, control panels, junction boxes, cable trays, maintenance areas, ladders, platforms, stairs, and walkways.

All handling and lifting equipment shall be identified by CONTRACTOR, and the Material Handling Report shall be updated accordingly.

CONTRACTOR shall note that pipe stress analysis has not been performed prior to the EPCI phase of the project. CONTRACTOR shall conduct all necessary stress analysis on the piping prior to finalization of the Piping GA’s and isometric drawings.

CONTRACTOR shall complete an animated 3D presentation in PDMS showing the sequence of mechanical activities to be carried out.

8.5 Instrumentation and Control Engineering

Activities, which shall be conducted by CONTRACTOR, includes engaging and managing a Sub-contractor(s) to complete the engineering and identify the certification requirements of the custody transfer metering system and the gas analyser system. Engineering shall include field equipment, data transmission, systems hardware and software and interface / integration requirements with existing and / or 3rd party control and shutdown systems.

Significant attention shall be paid by CONTRACTOR to the fiscal metering system. It is anticipated that CONTRACTOR will engage a Jamaican regulations approved Sub-contractor with specialist metering personnel for the design, procurement, testing, installation and commissioning of the metering skid modifications. Upon completion, the fiscal metering system must be in accordance with the prevailing Gas Sales Agreement Specifications, and any regulatory requirements.

Instrumentation and Control Detailed Engineering deliverables shall include, but not necessarily be limited to:

1. Metering Skid Certification Dossier

2. Instrument Index/I/O List

3. Specifications

4. Instrument Data Sheets

5. Instrument Calculations

6. Material Requisitions

7. Technical Bid Evaluations

8. Overall System Architecture (PCS/ESD/F&G) Update

9. Block Wiring Diagram


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10. JB Wiring Diagram

11. Loop Diagram

12. Instrument Location Drawing

13. Cable Routing drawing

14. Hook-up Drawing

15. Material Take Off

16. Cabinet General Arrangement and Wiring Diagrams

17. Fire & Gas Detector Layout Drawing

18. Cause & Effect Matrix

19. Logic Diagrams

20. System I/O Assignments and Serial Data Exchange Tables

21. HMI Graphics Print-out

22. Inspection and Test Plan

23. Acceptance Test Procedures and Reports

24. Pre-Commissioning/Commissioning Procedures and Reports

8.6 SIL Review

CONTRACTOR shall perform a SIL (Safety Integrity Level) review and ensure that the SIL dossier and all SIL documents are provided. CONTRACTOR may choose to delegate this responsibility to its Sub-contractor.

8.7 Electrical Engineering

CONTRACTOR shall carry out all necessary Electrical Design and Engineering, such as specification, data sheet, drawings, schedule, calculation/studies, procedures, material take off, and engineering manual as minimum requirements.

CONTRACTOR shall prepare all required specification either for procurement or installation procedure purposes, including but not limited to:

1. Electrical Installation work

CONTRACTOR shall in a timely manner, prepare data sheet as required for all electrical equipment with due consideration to the procurement schedule, including but not limited to:

1. Distribution Board.

CONTRACTOR shall develop all electrical drawings and schedules required for the works, and also be responsible for the update of existing plant drawings, including but not be limited to:

1. Electrical drawing index

2. Electrical legend & symbol

3. Cable routing / tray layout

4. Earthing and lightning protection layout


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5. Lighting layout

6. Hazardous Area Classification

7. Electrical & Instrument equipment layout

8. Single Line Diagrams (LV switchboard, existing UPS, Distribution Boards)

9. Electrical cable schedule

10. Termination / Connection / Wiring Diagram (LV switchboard, and Distribution Boards)

11. Installation detail drawings, developed for the installation of all electrical equipments such as power, lighting, tray, earthing and lightning protection.

CONTRACTOR shall perform all required calculations and studies, including but not limited to:

1. Cable sizing

2. Electrical Load Lists

3. Lighting illumination calculation

CONTRACTOR shall diligently prepare weight details and material quantities based on experience and actual material take-offs from drawings. CONTRACTOR shall continuously update all pertinent details in its material database for all electrical equipment and electrical bulk materials.

CONTRACTOR shall prepare all required Procedures, including but not be limited to:

1. Tie-in procedures

2. Electrical installation and testing procedures

3. Electrical pre-commissioning and commissioning procedures.

8.8 Engineering Activities Related to Procurement

CONTRACTOR shall as a minimum:

1. Produce all documents (drawings, material requisitions, specifications, reports, procedures, detailed bills of material, technical bid evaluations, and the like) necessary for the efficient procurement of all items;

2. Ensure Subcontractors’ and Vendors’ deliverables comply fully with the Contract requirements;

3. Update all related deliverables/ documents where applicable and provide any updates and/ or additional specifications as required, for COMPANY comment and acceptance;

4. Review and incorporate as applicable Vendors’/ Subcontractors’ engineering data in relevant deliverables.

8.9 Engineering Activities Related to Materials

8.9.1 Material Selection

CONTRACTOR shall develop and apply a consistent materials selection philosophy. CONTRACTOR’s material selection shall be subject to COMPANY’s approval.


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8.9.2 Corrosion Protection

CONTRACTOR shall develop coating specifications for COMPANY approval. Coating shall comply with approved specifications.

8.10 Engineering Design Codes

The design, the construction documents, the execution and the completed Works shall comply with any and all applicable specifications, technical standards, building, construction and environmental codes specified by COMPANY or defined by any applicable Jamaican Laws and Regulations.

A list of different design codes, specification and design manuals, which will be referenced to, but shall not necessarily be limited to, is presented in the Basis of Design.

8.11 Operations Involvement

CONTRACTOR shall include relevant operations personnel in the review of drawings at conceptual and detailed design phases.

Senior operations personnel shall also be involved in HAZOPs, HAZIDs and similar safety reviews associated with the preparation of the Safety Assessment Analysis. Operations personnel shall be involved as far as practicable in construction activities.

Operations personnel shall participate in mechanical completion and commissioning activities. CONTRACTOR shall designate operations personnel to “sign off” the documentation associated to the Mechanical Completion, pre-commissioning and Commissioning dossiers.

8.12 Final Documentation

CONTRACTOR shall provide final documentation including but not limited to:

1. Engineering deliverables including native electronic files;

2. As-built documents and drawings (to be agreed between COMPANY/ CONTRACTOR);

3. Electronic files, including calculations, analyses document/drawing databases and engineering databases;

4. Statistical reports;

5. Contract HSE plans and reports;

6. Contract QA plans and reports;

7. Feedback on experience, continuous improvement recommendations, lessons learned;

8. Manufacturing data books;

9. Procurement-related data;

10. Packing and shipping records;

11. Fabrication dossiers;

12. Installation dossiers;

13. Hydrostatic test dossiers/ records;


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14. Inspection and certification dossiers;

15. Pre-commissioning dossiers;

16. Commissioning dossiers;

17. Change control records;

18. Contract specifications and procedures;

19. All certification from Third Party Inspection and Governmental Authorities

20. Jamaican Regulatory Approvals for Sales Gas Metering systems

CONTRACTOR shall store, for a minimum of three (3) years, all hard copy documents and drawings.

8.13 Preparation of Manuals

CONTRACTOR shall prepare the following manuals in accordance with the requirements of the Contract, and other Contract documents. This shall include, but not be limited to:

1. Commissioning Manual

2. Equipment and Facility /Maintenance Manuals

3. Start-up and Operations Manuals

4. System Performance Testing Manual

5. Engineering Data Books

6. MDR – Material Data Reports for Mechanical completion

7. Certification Dossier

8.14 As-built Documentation

8.14.1 General

CONTRACTOR shall be fully responsible for the as-built of project documents, drawings and data and for the as-built and updating as necessary all existing documents and data.

CONTRACTOR’s Contract obligations shall not be considered fulfilled until as-built is completed to the satisfaction of COMPANY.

8.14.2 As-built Procedures

CONTRACTOR shall be responsible for as-built of drawings, documents and data as necessary throughout all phases of the contract including fabrication and installation activities.

During execution of each major activity CONTRACTOR shall monitor as-built activities for all disciplines and ensure that at completion of that activity a complete set of documents and/or drawings clearly marked ‘as-built’ is available. A master copy of each set of as-built marked-up drawings shall be maintained in a central location and be available to all interested parties.

As-built modifications shall be distributed to all affected parties. Where changes may have a significant impact on a subsequent phase CONTRACTOR shall revise the applicable drawings and re-issue ‘AFC’. CONTRACTOR shall maintain a log of all changes made after completion of AFC activities.


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8.14.3 As-built Register

CONTRACTOR shall, at the completion of the engineering activities prepare an ‘As-built Register’ of all project documents and drawings that require as-built and/or update for the scope of Work.

8.14.4 Schedule

CONTRACTOR shall include a detailed breakdown of as-built activities in the overall project schedule.

8.14.5 Vendor Data

Notwithstanding the responsibility of CONTRACTOR to ensure as-built of Vendor’s and Sub-CONTRACTOR’s documents, drawings and data, CONTRACTOR shall be responsible for ensuring that all as-built Vendor/ Sub-contractor data is captured in CONTRACTOR’s as-built documents, drawings and data. There shall be no missing information or ‘holds’ on the as-built documents and drawings.


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9 PROCUREMENT AND EQUIPMENT HANDLING

The CONTRACTOR shall be responsible for the procurement of all materials and equipment as required to complete the WORK. Procurement activities shall include, but not be limited to, the preparation of all material take-offs and requisitions, purchasing, expediting, reporting, materials receipt, inspection, testing, QA/QC documentation, Vendor Data, storage, preservation, security and transportation to the CONTRACTOR’s yard.

In addition to the above, CONTRACTOR shall:

• Prepare documentation as required for the importation of items into the Government of Jamaica, e.g., Master List, PIB, RIB as applicable

• Arrange for and expedite delivery of all materials and equipment to Sites

• Expedite suppliers’ final data and documentation

• Ensure suitable storage, handling and preservation for all materials and equipment

• Maintain a suitable efficient materials management system that provides full traceability of the intended use of materials and equipment and their specific movements and location

• Arrange for the timely provision of supplier representatives to the various Sites

• Produce real time updates to the PMS and issue to COMPANY on a weekly basis

• Ensure by stating in all bid enquiries and purchase orders/subcontracts that COMPANY personnel or its representatives have unrestricted access to supplier and Sub-contractor premises for the purpose of expediting, inspection, general reviews, audits and the like.

9.1 Procedures

CONTRACTOR shall issue procedures for procurement, supplier/subcontractor control, expediting, materials control, warehousing, and logistics within twenty (20) Business Days of the Effective Date for review and approval by COMPANY.

9.2 Procurement Plan

CONTRACTOR shall have a detailed Procurement Plan available as of the Effective Date. The Procurement Plan shall set out the philosophy, organization, scope, systems, corrective action procedures, and the like, that shall apply to CONTRACTOR’s procurement activities and how they shall be managed and effected in an efficient manner.

9.3 Procurement Master Schedule (PMS)

Within twenty (20) Business Days of the Effective Date, CONTRACTOR shall submit its Project specific PMS showing all known materials, equipment, and services to be procured. CONTRACTOR shall specifically highlight all items having a limited amount of schedule float.


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9.4 Materials Management

CONTRACTOR shall utilize proven systems and procedures, facilities, and sufficient resources, to identify, purchase, manage, and report on MTO requirements, shortages, materials, look ahead requirements, material-receipt, materials reconciliation, transportation, storage, preservation, warehousing, issuing, in-storage maintenance, and security of all CONTRACTOR’s Supply.

9.5 Subcontractors and Vendors

CONTRACTOR shall:

1. Ensure that all candidate Subcontractors and candidate Vendors have been assessed and approved by COMPANY to verify their organisational & technical capabilities and their level of competence to fulfil the identified scope of work or scope of supply;

2. Review all candidate Vendors’ documentation for compliance with Contract quality requirements;

3. Determine the level of quality surveillance required in order to ensure the technical integrity of the product or service;

4. Manage all Subcontractors and Vendors to ensure their quality requirements are achieved in accordance with CONTRACTOR’s responsibilities under the Contract;

5. Engage all Subcontractors and Vendors in the shutdown planning activities including workshops and brainstorming sessions

6. Conduct quality audits on Subcontractors and Vendors in accordance with CONTRACTOR’s audit plan; sufficient notification of CONTRACTOR’s intent to carry out Vendor audits shall be given to COMPANY, to allow COMPANY to witness or participate in such audits.

9.6 Import/Export

CONTRACTOR is solely responsible for making all necessary arrangements for the proper and timely exportation from, importation into and re-exportation from any country of CONTRACTOR’s Supply, and the Work.

CONTRACTOR shall make all such arrangements including the payment of all applicable taxes, tariffs, levies, surcharges, fees and other charges. CONTRACTOR shall do so in a timely manner to meet the Contract Schedule and in accordance with all Applicable Laws. Any errors, omissions or delays in, or resulting from, the import & re-export process will not be grounds for a change.

CONTRACTOR shall arrange payment for any import duties, customs clearance and the like applicable to items imported into Jamaica.

CONTRACTOR shall also prepare for submission to the Jamaican Customs and/or other Government Authority any reports required to account satisfactorily for the final disposition of all items imported permanently or temporarily for the Work. CONTRACTOR shall be responsible for ensuring that all relevant Export Compliance regulations are followed as per the relevant section of the proforma Terms and Conditions contained within the tender package.


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CONTRACTOR shall be responsible for all import/export activities related to customs clearance for the long lead items.


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10 FABRICATION & LINE-PIPE COATING

The CONTRACTOR shall complete all pipeline fabrication and coating activities required to complete the Work in all respects. These activities shall include, but not be limited to, the following:

1. Provision of all required plant and equipment, labour, project management, engineering, supervision, services, utilities, transportation, materials, insurances and consumables that are necessary for the timely completion of the Work;

2. Instruct or award the fabrication/coating yard so the Work (line pipes and bends) can be fabricated/coated and loaded-out onto suitable transportation barges;

3. Maintain the fabrication/coating yard to a level of cleanliness to prevent damage to fabricated items due to foreign object ingress;

4. Takeoff, procure and transport to the fabrication yard all items of material and equipment as shown on the design drawings, or called out in the specifications; and

5. Receive, offload, handle, inventory, preserve, store and maintain in good order all items of material or equipment.


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11 CONSTRUCTION/FABRICATION

11.1 General

CONTRACTOR shall at all times provide adequate construction equipment, construction materials, fabrication facilities, supervision, labour, trades, equipment, tools and material to enable CONTRACTOR to complete the Work, in accordance with this Contract and to the satisfaction of COMPANY.

COMPANY reserves the right to inspect all phases of CONTRACTOR’s construction operations including construction at the ORF, fabrication shops, equipment assembly, testing, packing and transport operations to ensure conformity to the drawings, specifications and safe working practices.

CONTRACTOR shall:

1. Perform all activities, including fabrication and assembly to bring the Work to a condition where it is completely fabricated;

2. Complete all construction works on site to meet requirements of this Scope of Work, and allow adequate time for curing of concrete;

3. Complete all inspection and testing requirements consistent with requirements of this Scope of Work and all Third Party requirements;

11.2 Skids and Spools – Transportation, Installation and Tie-in

CONTRACTOR shall as a minimum:

1. Perform all engineering related to the delivery of the skids and pipe spools and produce all AFC documents necessary;

2. Provide all engineering, calculations, procedures and AFC documents including fabrication quality drawings and MTO;

3. Develop procedures and AFC documents necessary to perform the Work;

4. Perform all required safety engineering, including a HAZID/HAZOP register and reports; studies shall include a dropped object study for the installation works, including that which shall be carried out during a shutdown;

5. Submit for COMPANY approval, details of its skids and spools installation and tie-in activities and procedures.

6. Provide details of lifting and lowering procedures, method of rigging, and positioning of spools;

7. Provide procedures for removal of gas in existing pipelines, and purging;

8. Provide detailed shutdown plans and procedures for the planned shutdown;

9. Provide procedures on quality assurance and control, and

10. Provide safety procedures.

11.3 Size and Quality of Workforce

CONTRACTOR shall be solely responsible for provision of qualified construction and fabrication labour, in type and numbers corresponding to agreed plans and in accordance with the agreed Contract Schedule. CONTRACTOR shall arrange for


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approval of all weld procedures and testing of welders by the appropriate Certifying Authority.

CONTRACTOR shall supply Contract-dedicated yard supervision in the form of construction foremen or equivalent having at least two years experience in that position.

In the event that CONTRACTOR desires to subcontract parts of the fabrication Work to COMPANY-approved Sub-contractors or Vendors, in addition to the required prior approval from Company for such actions, Company’s approval of such subcontracting shall be contingent on CONTRACTOR providing a specified level of its own supervision and QC personnel to follow up the work at any Site. CONTRACTOR shall also provide a Sub-contractor organization chart and proof of experience of the Sub-contractor workforce and supervision.

CONTRACTOR shall ensure all CONTRACTOR, Sub-contractor(s) and vendor personnel have the appropriate permits to enter and work in Jamaica.

11.4 Fabrication

CONTRACTOR shall, prior to the commencement of fabrication, update and re-issue CONTRACTOR’s Project Execution Plan (PEP), and ensure all construction, mechanical completion and testing related procedures are complete, and issued for COMPANY approval. In particular, this shall include:

1. Updating and reissuing CONTRACTOR’s risk driven HSE Management System for use during all phases of the project.

2. Updating and reissuing the Quality Plan incorporating all QA/QC requirements including all Inspection and Test Plans;

3. Updating and reissuing CONTRACTOR’s Contract Schedule; the Contract Schedule shall incorporate CONTRACTOR’s proposed sequence for all fabrication and construction activities but shall not change agreed milestones without COMPANY approval;

4. Comprehensive procedures to cover all construction, fabrication, testing, commissioning;

Items fabricated in a workshop environment shall successfully pass Factory Acceptance Testing (FAT) prior to delivery to site.

11.5 Fabrication Yard Facilities

CONTRACTOR shall provide the following, as a minimum:

1. A complete yard facility capable of undertaking all aspects of the Fabrication phase of the Works, including testing;

2. Fabrication workshop office, stores, warehouses, materials and equipment, yards, parking, and the like;

3. Personnel and equipment for satisfactory operation of the workshop facilities and for the receipt, handling, storage and preservation of each and every item of construction material and equipment;

4. All necessary scaffolding required to complete the Work. Erection of scaffoldings at the existing facility will require COMPANY approval;

5. All temporary lifting, slinging and rigging equipment required - all such equipment shall be tested and certified by the applicable local Certifying Authority and;


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6. Assurance that loose material is regularly dampened in order to prevent it from being blown into stored materials or onto the Works. The fabrication site shall be maintained in a clean, dust free and orderly condition.

11.6 Dimensional Control

CONTRACTOR shall provide all labour, qualified surveyors and surveying equipment to ensure that the work is fabricated in accordance with tolerances stated in the (AFC) drawings and approved specifications.

11.7 Logistics Plan

CONTRACTOR shall prepare a detailed logistics plan in support of all activities related to transportation and installation.

The Logistics Plan shall include;

1. Transport of personnel to/from the work sites (Offshore and Onshore)

2. Provision and transport of fuel, food, water and other consumables to the work sites

3. Removal of garbage, trash and human waste from the work sites

4. Transport of installation spreads and construction equipment to the work sites.

11.8 Lifting & Rigging Plan

CONTRACTOR is responsible for the transfer of all equipment, piping, and materials between port facilities, fabrication/ construction sites.

CONTRACTOR shall prepare a detailed installation lifting and rigging plan for all activities related to the Work, including communications procedures between CONTRACTOR’s workshop/warehouse and the ORF.


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12 TRANSPORTATION, INSTALLATION, COMMISSIONING AND OPERATION

12.1 Transportation

CONTRACTOR shall provide all equipment and services required for the transportation of all equipment, piping and materials to the ORF or shore facility. CONTRACTOR shall map the route to the ORF or shore facility, and secure any permits required to haul an oversize load and the like to the ORF or shore facility.

Any improvement work or reinforcement required for the transportation or parking of heavy vehicles associated with on site activates shall be the responsibility of CONTRACTOR.

CONTRACTOR shall obtain all necessary approvals for the use of all existing roads within the site boundary.

12.2 Pipeline Offshore Installation

CONTRACTOR shall perform all pipelines hook-up and pre-commissioning work as required to prepare the pipelines for start-up. The CONTRACTOR shall provide all required plant and equipment, labour, project management, engineering, supervision, services, materials, insurances, consumables and offshore accommodation (or any suitable sea transportation from onshore accommodation) that are necessary for the timely completion of the pipelines hook-up and pre-commissioning work.

CONTRACTOR shall allow for sufficient barge time for the completion of the hook-up and pre-commissioning work activities up to the approval of the pipelines ready for start-up certificate.

CONTRACTOR is responsible for establishing the necessary support and logistics base for the offshore hook-up and pre-commissioning work. The location of this base shall be that which enables the most efficient execution of the Work, together with the availability of local facilities, labour skills and experience.

COMPANY will assist the CONTRACTOR in negotiations with the local community with regard to WORK at the installation site, however responsibility for this process shall reside solely with the CONTRACTOR.

CONTRACTOR must obtain the necessary permits, approvals and marine clearances as required for the completion of the Work, which may include, but not limited to the following:

1. Permit for Hazardous Waste Storage & Transportation;

2. Permit for Chemical Discharge;

3. Permit for Use of Radioactive Material

4. Permit for Radio Communication & Telecommunication;

5. Permit for Dredging and Reclamation;

6. Permit for Under Water Work;

7. Permit for Pipeline Installation;

8. Permit for Marine Operations;

9. Permit for Offshore Survey; and

10. Permit for Pipeline Construction (Internation Maritime Bureau, IMB).


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CONTRACTOR shall complete all installation activities to meet requirements set out in approved project specifications and this Scope of Work.

CONTRACTOR shall provide all equipment, material, manpower and services required for the installation and tie-in of all equipment and piping including lifting equipment, supervision, labour, purge gas facilities and the like.

CONTRACTOR shall have qualified engineering personnel present during installation to provide assistance in assuring works are completed to approved detailed design drawings, specifications and procedures.

Prior to installation, CONTRACTOR shall ascertain if any existing items need to be relocated to accommodate the new equipment, and subsequently plan and carry out the relocation.

CONTRACTOR shall develop, for COMPANY’s acceptance, an Installation, Hook-up and Commissioning plan that shall detail how all required activities will be accomplished.

CONTRACTOR shall:

1. Seek to minimize offshore activities.

2. Prepare detailed Commissioning procedures and detailed start-up procedures

for COMPANY’s acceptance.

3. Prepare final Commissioning manuals that compile the detailed scopes of

work and relevant acceptance criteria and certificates.

12.3 ORF Installation

CONTRACTOR shall prepare the site, construct foundations and structures, set all equipment, install all items of the Work and make all necessary connections to complete the Work.

CONTRACTOR shall:

1. Maintain a continuous record of the sequence and the characteristics of each

installation activity, including video and photographic records for COMPANY

use;

2. Confirm correct alignment of all piping and equipment;

3. Ensure that the agreed monitoring and control measures are followed;

4. Ensure all activities are carried out in accordance with drawings,

specifications and procedures, using only qualified personnel and acceptable

equipment and facilities as agreed with COMPANY;

5. Follow the approved installation sequence and obtain written approval from

COMPANY prior to any deviation;

6. Perform lifting, lowering into position, and bolt-up of each item of equipment to

its relevant foundation or support;

7. Be responsible for the supply of all specialist equipment necessary for

installation.


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CONTRACTOR shall be considered to have completed the construction of the facilities upon COMPANY acceptance that Mechanical Completion has been achieved, with no outstanding punch list items.

12.4 Pre-Commissioning

At completion of piping and equipment installation activities, CONTRACTOR shall pre-

commission all newly installed pipeline, piping, mechanical, electrical and

instrumentation items. This includes checks on the integrity of all connections and

gaskets, and all functional testing. As much pre-commissioning as possible shall be

completed prior to the planned shutdown in order to minimise the duration of the planned

shutdown.

Pre-Commissioning activities shall include but not necessarily be limited to the following:

1. Full pressure nitrogen testing and flushing of piping;

2. Functional testing of all electrical equipment and motors;

3. Functional testing of all mechanical equipment and valves;

4. Operational checks of all control systems, as much as possible;

5. Testing and calibration of all instrumentation;

6. Touch-up of all painting and protective coatings where required.

7. Pipeline system is missed.

In accordance with the CONTRACTOR prepared Mechanical Completion and Pre-

Commissioning Checklists, CONTRACTOR shall demonstrate that Mechanical

Completion and Pre-Commissioning has been achieved and certified by COMPANY.

The supply of pre-commissioning spare parts and consumables shall be the

responsibility of CONTRACTOR.

12.5 Pre-Commissioning Procedure

The pre-commissioning procedure covering each of the activities for the export pipelines shall be submitted for approval and included in the Installation Manual.

As a minimum the Pre-commissioning Procedure shall include the following:

• Organisation and Qualifications and Safety procedures and Job Hazard Analyses (JHAs).

• Quality procedures including Inspection and Test Plans (ITP).

• Environmental management issues addressing the specific test issues and their impact.

• Details of the pipeline segment to be tested defining length, diameter, wall thickness, volume, and elevations. Piping and instrumentation diagrams, schematics and arrangement drawings shall also be included.

• Description of activities at each end of the pipelines.


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• Detailed drawings and design / pressure rating information including Non-Destructive Evaluation (NDE) results and pressure test results pertaining to proposed pig receivers, test heads, pressure relief valves, non return valves and operating valves.

• Make/type and design of pigs to be used for various phases, including drawings.

• Make/type of all equipment to be used including pumps, pressure and temperature gauges, high pressure / low pressure flowmeters, snubbers, filters, temperature probes and instrumentation (including current certification/calibration).

• Method of monitoring progression of pigs along the pipelines.

• Flow diagram for pipeline filling.

• Source of water for filling and hydrotesting the pipelines.

• Full details of chemicals, MSDSs, dosage rates, mixing methodology, based on water samples at intake locations and discharge considerations.

• Arrangements for storage of chemicals, mixing of chemicals with the test medium and injection.

• Determination of thermal stabilisation period.

• Specified test pressure.

• Holding times for tests.

• Inventory of testing equipment and instruments.

• Procedure for cleaning, gauging and filling the pipelines.

• Procedure for hydrostatically testing the pipelines, including pressurisation and depressurisation activities and acceptance criteria.

• Calculation procedure for determining the effect of temperature variations on the recorded pressure.

• Methods of recording temperature.

• Procedure for dewatering the pipelines and disposal of the contents in an environmentally acceptable manner.

• Contingency procedures.

• Experience of testing personnel and certification.

• Quality control procedures, including copies of all test result proformas to be used.

• Format and contents of Pre-commissioning Report, which will form part of the As-Built Data Report.

12.6 Pre-Commissioning Equipment

12.6.1 Test Water Supply

Contractor shall submit a Water Management Plan for Company review and approval.

The Water Management Plan shall detail water source, quantity, maximum rate required,

chemical details and concentrations and water handling and disposal methods.


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12.6.2 Fill Pumps

Fill pumps and fill lines shall be sized for the volumes of water to be pumped in each

case.

Filters shall be installed between all unprocessed water sources and the pipelines as

specified in DNV OS F101, Section 9, O-403.

Filters shall be installed in such a manner to permit back flushing or change out without

interruption of the pumping operation and without bypassing the filtration system.

12.6.3 Pressure Pumps

Pressure pumps shall be capable of inducing a pressure up to 10% greater than the

hydrotest pressure with a minimum filling rate of 10 litre / min, unless otherwise

approved.

Pressure pumps shall be equipped with a stroke counter and a variable speed control

and shall be capable of maintaining a rate of 50 kPa per minute or less at a constant

volumetric injection.

12.6.4 Flow meters

Flowmeters shall be of high pressure and low pressure types, which shall be suitable for

pressurising and filling operations respectively.

12.6.5 Pressure Relief Valves

The test system shall have pressure relief valves (PSV) of adequate quantity to ensure

that no component in the test system shall be over pressurised. The PSV’s shall be set

at a pressure 10% higher than the maximum test pressure. The PSV’s shall be of

adequate capacity and carry certification tags.

12.6.6 Test Header

The tests shall be carried out via a test header, unless otherwise approved. The test

manifold shall be pretested to at least 1.25 times the maximum test pressure. The test

manifold shall consist of the test system valves such that all valve operations are carried

out remote to the pipelines pressurising point.

12.6.7 Instrumentation

All deadweight testers, standard gauges, pressure recorders, and temperature recorders

shall have been certified for accuracy by a UKAS (United Kingdom Accreditation

Service) or Jamaican equivalent certified testing laboratory within the last six months

before the date of testing. Serial numbers and period of calibration validity shall be

clearly indicated on the certificates and the instruments.

The deadweight gauges shall be the prime source of monitoring pressure throughout the

hydrostatic test. The pressure recording equipment shall operate between 25% and 75%

of the full scale indication. The accuracy of the standard gauges at the time of

certification shall be ±0.1% and the sensitivity shall be 0.1% of the full-scale indication.


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Pressure recorders and transducers shall be used to make a continuous record of the

pressure during testing at both ends of the pipelines. Pressure recorders shall be seven-

day wind, twenty-four-hour circular chart recorders or similar. Pressure recorders shall be

calibrated on the deadweight tester immediately prior to pressure testing.

The pressure recorder and pressure gauges shall be calibrated against the dead-weight

tester at the start and end of each test.

Two temperature recorders shall be used to make a continuous record of both ambient

and pipe temperature during testing at suitable and approved locations. Temperature

recorders shall be calibrated to a test thermometer at two points on the scale

immediately prior to testing. The test thermometer shall be of laboratory grade mercury

filled, with a range from -10°C to 50°C, and have 1° divisions.

The pipe temperature sensors shall be checked by recording the readings from all

sensors against the same temperature medium before and after each test.

12.6.8 Piping Temporary Works

Temporary pig launchers, pig receivers (if subjected to full test pressure), test headers,

drying headers and all associated valves and fittings shall be designed for a safe working

pressure at least 10% above the maximum pressure expected during hydrotesting

activities.

The design calculations shall be executed by a competent Professional Engineer and

verified / approved by a similarly competent Professional Engineer.

The fabricated items shall be hydrotested to the design pressure as defined above for

one hour, to Company’s satisfaction.

12.6.9 Pig Design

The design of pipeline pigs for flooding, cleaning and gauging of the pipelines shall be

the responsibility of the Contractor taking into account specific Company requirements.

Contractor will be required as part of the detailed procedure to demonstrate to the

satisfaction of Company the suitability of any pig design and its safe operation.

A general requirement is that all equipment and chemicals used during pre-

commissioning that are introduced into the pipelines and the associated subsea system

shall be of a material / composition that are compatible with the system. In particular no

tools or equipment of carbon steel construction shall be permitted to come into contact

with any permanent duplex parts of the pipelines during any pigging (filling, cleaning,

gauging, dewatering, batching) operations as this may cause subsequent corrosion of

the duplex. These comprise but are not necessarily limited to:

• Barred Tees including pipe section immediately downstream; and,

• In-line valves.

All pigs shall be capable of negotiating all ball valves, and other valves, fittings and

bends as indicated in the work scope.

All pigs shall be bi-directional.


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Company acceptance of any design or procedure will not absolve Contractor of his

responsibility to complete the work in as diligent and as timely a manner as is practically

possible.

Gauging plates shall be made following the requirements as stated in the BoD,

[Reference 1].

All pigs shall be permanently marked with a unique number that shall be clearly visible.

A photographic record shall be kept of all pigs and gauging plates before and after each

run.

12.7 Requirements for Pre-Commissioning Activities

12.7.1 General 1. The pipelines and appurtenances shall be free of dirt and debris prior to filling

the test section.

2. Any flange or pipeline appurtenance under pressure shall not be tightened or otherwise disturbed.

3. Pre-commissioning activities shall not commence until the pre-commissioning procedure, supervisory personnel, equipment certification and proposed reporting arrangements have been approved.

4. Any chemicals proposed by Contractor shall not be detrimental to the environment. Treated hydrotest fluid and indication dye shall be acceptable to authorities for release into the sea in order to ensure environmental compliance. Contractor shall provide Material Safety Data Sheets along with handling instructions for all chemicals and products alike.

5. All pigging trains proposed for various phases of the works shall be approved.

6. Any pig that stops during traversing and cannot be dislodged shall be cut from the line and the pipeline repaired in accordance with the specifications provided elsewhere in the Contract.

7. The pressure test shall not be terminated prior to receipt of Company written acceptance.

8. Contractor shall submit for Company approval schematics of test equipment set-ups identifying pressure relief and high pressure components requiring certification.

9. Contractor shall submit for Company approval an Environmental Management Plan with hold points incorporated in ITP.

10. Company shall be the sole judge of the acceptance of each hydrostatic test.

11. Should the pipelines hydrostatic test fail, the pipelines shall be re-tested fully in accordance with this Specification, on completion of remedial works to Company’s satisfaction.

12. Complete records of failures occurring during the hydrotesting shall be kept, including exact locations, type and cause of failure and the method of repair. Pipe, fittings and valves, which fail and are replaced, shall be marked with their pipeline locations and pressure at which they failed. Contractor shall not dispose of such materials, until approved.


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12.7.2 Organisation and Personnel Qualifications

The testing organisation shall be UKAS (United Kingdom Accreditation Service)

accredited or Jamaican equivalent certifying body. The Contractor’s Hydrotest Engineer

who is responsible for the testing activities shall have UKAS or Jamaican equivalent

accreditation and sign the final hydrotest records.

12.7.3 Cleaning, Filling and Gauging

Contractor detailed filling procedures shall include methods and equipment used to

measure and monitor injection rates. A flow meter of sufficient size and accuracy shall be

used to measure the quantity of water injected into the test section.

Chemical injection rates shall be monitored to ensure the correct concentrations are

being created.

Sufficient chemicals shall be injected to provide at least 6 months effective inhibition

following depressurisation after the successful hydrotest and prior to dewatering.

Pigs used during filling, cleaning and gauging and subsequent commissioning activities

shall be launched from and received in temporary traps furnished and installed by

Contractor.

Company and Contractor shall agree before the pigging operation begins on the degree

of cleanliness to be achieved.

A pig train consisting of cleaning, flooding and gauging pigs shall be driven at a minimum

speed of 0.5 m/sec and a maximum speed of 1.0 m/sec.

Pumps shall be capable of driving pigs at the above speed and pressure range, water

volume and pressure shall be recorded to establish progress of pig.

Should a pig become stuck in the pipelines, all operations shall be shut down. The pig

shall be located and the pipelines shall be inspected at the location where pig is stuck. If

no damage is found the pig shall be pushed back and run again.

Contractor shall provide procedures for safe delivery of the pig at the receiver end of all

operations.

Filling Water Treatment

No water is permitted to enter the pipelines unless it is treated with chemical to control

corrosion and biological attack.

The minimum chemical treatment shall include dosing with approved oxygen scavenger

and biocide. Biocide shall be included subject to water quality as given below. The

scavenger dosage shall ensure all dissolved oxygen is displaced and provide a small

residual. The chemical dosing equipment shall be capable of delivering a proportion

dosage rate within 5% of that specified.

Tolerance limits on water quality shall be:

(a) Oxygen Nominal maximum level of 30 ppb (µg/l) but zero after complete reaction with the oxygen scavenger

(b) Total solids Maximum permitted level of 1.0 mg/l


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(c) Bacteria Not more than 100 total bacteria per ml, and no SRB (sulphate reducing bacteria) (no SRB detected by serial dilution technique < 1 per ml)

(d) pH Minimum acceptable pH of 6.5

Contractor will be responsible for developing the chemical mixture (ensuring

compatibility) to be used comprising, biocide and oxygen scavenger to mitigate against

deterioration of the pipelines between cleaning and commissioning and a dye to enable

flange leak checks during the leak test.

The chemicals shall be injected into the filling water stream individually via separate

injection pumps, unless otherwise approved. The dosing rate of each chemical and the

pressurising flowrate shall be continuously monitored and the dosage rate shall be either

automatically or manually adjusted to ensure that the correct ratio of each chemical is

obtained. The system shall incorporate recording instrumentation that will verify that all

water entering the pipelines is properly dosed with chemicals. As a minimum the record

shall show the flow rates of water and chemicals, and the cumulative totals of each.

Should the chemical dosing system be based on dispensing the chemical in powder form

to a mix tank, equivalent monitoring systems shall be adopted.

The system should also record the dissolved oxygen concentration in the water entering

the pipelines.

The chemicals used shall be non-toxic and biodegradable after use. In the case of

treated sea water, end of use toxicity levels shall be tested and verified prior to

discharge, in accordance with the discharge permit.

Cleaning Criteria

Cleaning and gauging shall conform fully with DNV OS F101 Section 9, O-400.

A quantity of filtered, untreated water equivalent to 200m length of the pipelines shall be

introduced ahead of the first pig train to ensure wetting, washing and rinsing away of

foreign materials. The leading slug of water may contain construction debris. Disposal of

this water shall be in accordance with approved procedures.

The first pig train shall consist of pigs to remove all entrained air and large debris.

Pigs shall be Bi Di four (4) disc type unless approved otherwise by Company.

Unless otherwise agreed with Company, the minimum complete cleaning cycle should

comprise of a poly pig run, two hard brush steel bodied mechanical pig runs and soft

flexible bristle brush steel bodied pig run. A line can be considered adequately clean for

the final soft bristle steel bodied pig run if the quantity of removed deposit (remaining in

the receiver ahead of the last pig received) with the last hard brushed mechanical pig run

does not exceed 10% of that removed during the previous run and uncompacted volume

of debris does not exceed 500 cm³.

If agreed with the Company, a debris pick up gel may be used in conjunction with two

hard brush pigs, in lieu of multiple cleaning pig train runs. The Contractor shall take gel


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samples for analysis to permit verification of the performance of the pick up gel if

required by the Company.

Cleaning pig runs shall be driven through the pipeline using treated filtered water as

described in this Section.

Gauge Pigging

The acceptance criteria for the gauge pigging shall be in accordance with DNV OS-F101,

Section 9, O-400.

Filling shall be accomplished with appropriate pig trains suitable for the proper

displacement of air by water.

The speed of travel of the pig(s) shall be regulated in order to prevent water from

bypassing the pigs during the filling operations. Contractor shall nominate maximum pig

traverse speed for approval.

Contractor shall provide a detailed procedure for the gauge pig run for approval. This

procedure shall include at least the maximum, minimum and design velocity for the entire

run.

Following the pig run, the gauge pig shall be removed in the presence of the Company’s

Representative. Photos shall be taken of gauge plate which shall form part of data book.

The Contractor shall make good any defects to the pipeline which exceeds the

acceptance criteria. Pipeline repair procedures shall be approved. Should any pigs be

stopped in the line, the pig shall be located, the cause(s) of the stoppage ascertained

and any defects made good. On completion of this work gauge pigging operations shall

recommence from the start.

12.7.4 Hydrostatic Testing

Test Pressure

The test pressures shall be nominated by the CONTRACTOR for COMPANY approval.

Pressurization and Pressure-Volume Plot

Contractor shall pressure the pipelines in accordance with DNV OS-F101, Section 9, O-

512 and O-513 up to test pressure.

Following stabilisation, and notwithstanding the requirements of DNV OS-F101, Section

9, O-516, the test pressure shall be held for the minimum of duration specified in the

Basis of Design.

Acceptance criteria shall be in accordance with DNV OS-F101, Section 9, O-519.

Upon successful pressure testing the pipelines shall be depressurized in accordance

with DNV OS-F101, Section 9, O-520.


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12.7.5 Hydrostatic Test Report

A hydrostatic test report, which addresses each of the items, identified in AS 2885.5 shall

be issued for each of the tests.

The report shall be signed by the Hydrostatic Test Engineer (UKAS or Jamaican

equivalent accredited) and shall certify that the pressure tests meet the requirements of

this Specification and the applicable Standards. The Hydrostatic Test Engineer shall

sign all charts and forms.

Test data and associated graphical output shall also be submitted in electronic format, as

an Excel spread sheet.

12.7.6 Dewatering and Drying

After line depressurization is complete the pipelines shall be de-watered using bi-

directional pigs.

The pigs will be designed to be run in a single pass pigging operation.

All requirements of the Government approved Company Environmental Plan shall be

complied with. Test water shall be discharged in accordance with Approved procedures

and the Company Environmental Plan.

Acceptance criteria for dewatering the pipelines shall be:

• Contain no significant residual free water; and

• Be substantially free of residual debris/dust

No significant residual water shall mean that the residual water shall not be more than

5% of the calculated pipeline volume after accounting for physical and measurement

tolerances.

Following bulk dewatering the pipeline section shall be left nitrogen filled with oxygen

content less than 2%.

12.8 Documentation – Specific Requirements

Upon completion of each major hydrostatic test activity, an Interim Hydrostatic Test

Report containing all test results shall be submitted to Company, including a record of

deadweight gauge readings, recorder charts, PV (pressure volume) plot, instrument

calibration certificates, pigging, gauging, dewatering, drying and other data pertinent to

the test.

The contents of the Interim Hydrostatic Test Reports, along with all other documentation

for pre-commissioning activities shall be included in the As-Built Data Report.

12.9 Commissioning

COMPANY shall be responsible for all planning, data capture, and execution activities of

live commissioning activities with the support of CONTRACTOR’s personnel.

CONTRACTOR’s personnel shall be supervised by COMPANY while carrying out the

live commissioning activities.


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CONTRACTOR’s responsibilities shall include but not be limited to:

• Supply of commissioning spare parts;

• Supply of all materials, equipment and consumables required to assist in commissioning;

• Supply of manpower and expertise required to assist in commissioning;

• Coordination of Vendors required to assist in commissioning;

• First fill and the installation of all lubricants required for plant operation.

12.10 As-Built Survey

CONTRACTOR shall perform a comprehensive as-built survey within three (3) days of completion of the installation of the pipeline.

12.11 Performance Testing

CONTRACTOR shall provide a Performance Test Procedure Manual to COMPANY for

approval. The Performance Test shall fully demonstrate that the facilities are capable of

meeting the capacity throughput, utilities consumption and emissions levels as are

indicated on the final approved for construction drawings, documentation and original

Basis of Design. Performance Testing the facilities shall be the responsibility of

COMPANY.

CONTRACTOR, at its cost, is expected to have appropriate representation present

during any Performance Test. While COMPANY will attempt to test the complete

facilities, if restrictions to sales volumes or other encumbrances exist, COMPANY, at its

option, may complete the Performance Test by utilizing one part or several parts of the

facilities. If this is the case, a complete procedure will be developed by CONTRACTOR

and approved by COMPANY to ensure a valid test and complete documentation.

Performance Testing shall be conducted within one year of the start up of the plant.

CONTRACTOR shall be required at CONTRACTOR’s sole cost to repair or replace as

required any part or parts of the Facilities that do not meet the performance as required.

12.12 Operation

The CONTRACTOR shall operate and maintain facilities on behalf of the COMPANY in

accordance with applicable Jamaican & international regulatory / permitting

requirements, and within the terms of end-user supply agreements. Facility operation

and maintenance shall be undertaken such that optimal availability is achieved. Refer to

the Pipeline and ORF Operating Philosophy [Reference 1] for details.


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13 REFERENCES

Reference 1 402010-00260-00-GE-BOD-0001: Basis of Design

Reference 2 402010-00260-00-GE-RFQ-0002: Request for Quotation: Technical Form of Bid

Reference 3 402010-00260-00-GE-SOW-0004: SRT Scope of Work

Reference 4 Jamaica LNG Road Show Presentation by Taylor- DeJongh dated March 2011

Reference 5 EIA dated 2007

Reference 6 402010-00260-00-MA-SPC-0005: Jetty Moored FSRU Functional Specification

Reference 7 402010-00260-00-PR-SPC-0001: Regasification Plant Functional Specification

Reference 8 402010-00260-00-MA-PHL-0001: FSRU Operating Philosophy

Reference 9 402010-00260-00-MA-PHL-0002: Jetty Design Philosophy

Reference 10 402010-00260-00-PR-PHL-0001, Pipeline and ORF Operating Philosophy

Reference 11 402010-00260-00-PR-SPC-0002, Pipeline and ORF Functional Specification

Attachment 05 - Pipeline & ORF Functional Specification

GOVERNMENT OF JAMAICA - OFFICE OF THE CABINET JAMAICA LNG PROJECT PIPELINE AND ORF FUNCTIONAL SPECIFICATION

Page i

Jamaica LNG Project Pipeline and ORF Functional Specification

402010-00260 – 00-PR-SPC-0002

26-Aug-11


Page ii

CONTENTS 1. INTRODUCTION ..................................................................................................................... 5

2. SCOPE OF WORK .................................................................................................................. 6

2.1 General ........................................................................................................................ 6

2.2 Description of Work ..................................................................................................... 6

3. DEFINITIONS .......................................................................................................................... 7

4. ABBREVIATIONS .................................................................................................................... 8

5. CODES, STANDARDS, REGULATIONS AND PROJECT DOCUMENTS ........................... 14

5.1 General ...................................................................................................................... 14

5.2 Regulations ................................................................................................................ 14

5.3 Codes and Standards ................................................................................................ 14

5.3.1 SAWL Line Pipes ................................................................................................. 14

5.3.2 Pipeline,Fabrication, Testing and Transportation ................................................ 15

5.3.3 ORF ...................................................................................................................... 15

5.4 Project Documents and References.......................................................................... 15

5.5 Quality Assurance ..................................................................................................... 15

5.6 HSE ........................................................................................................................... 16

5.7 Inspection and Testing .............................................................................................. 16

6. PIPELINE REQUIREMENTS ................................................................................................ 17

6.1 General ...................................................................................................................... 17

6.2 Manufacturing ............................................................................................................ 17

6.3 Pipeline Properties .................................................................................................... 17

6.4 Material Properties .................................................................................................... 18

6.4.1 Chemical Composition ......................................................................................... 18

6.5 Exceptions, Clarifications and Additions to DNV-OS-F101 ....................................... 19

6.6 Documentation .......................................................................................................... 19

6.7 Transportation, Handling, Storage and Marking ....................................................... 19

6.8 Pipeline Fabrication and Installation.......................................................................... 20

7. ONSHORE RECEIVING FACILITY (ORF) ............................................................................ 24


Page iii

7.1 General Requirements .............................................................................................. 24

7.1.1 Design Life ........................................................................................................... 24

7.1.2 Human Factors Engineering ................................................................................ 24

7.1.3 Units of Measurement .......................................................................................... 25

7.1.4 Hazardous Area Classification ............................................................................. 25

7.1.5 Availability and Reliability ..................................................................................... 25

7.1.6 Design Document Order of Precedence .............................................................. 26

7.1.7 Plot Layout, Piping Specification breaks .............................................................. 26

7.1.8 Codes and Standards .......................................................................................... 26

7.1.9 Documentation ..................................................................................................... 27

7.1.10 Purchase Order Documentation .......................................................................... 27

7.1.11 Material Certification ............................................................................................ 28

7.1.12 Field Transmitters ................................................................................................ 28

7.1.13 Actuated Ball Valves ............................................................................................ 28

7.1.14 Spares and Consumables .................................................................................... 28

7.1.15 Special Tools ........................................................................................................ 29

7.2 Pig Receiver .............................................................................................................. 29

7.3 Pipeline Filters ........................................................................................................... 29

7.4 Fiscal Metering .......................................................................................................... 30

7.4.1 Metering Skid Overview ....................................................................................... 30

7.4.2 Metering Skid Operation ...................................................................................... 31

7.4.3 Temperature Instrumentation ............................................................................... 31

7.4.4 Pressure Instrumentation ..................................................................................... 31

7.4.5 Gas Chromatograph ............................................................................................ 31

7.4.6 Calibration and Carrier Gas ................................................................................. 34

7.4.7 Hydrocarbon Dewpoint Analyser ......................................................................... 34

7.4.8 Water Content Analyser ....................................................................................... 34

7.4.9 Analyser Shelter ................................................................................................... 34

7.4.10 Sample Conditioning and Sampling Systems ...................................................... 34

7.4.11 Overall Measurement Uncertainty ....................................................................... 35


Page iv

7.4.12 Metering Runs Layout .......................................................................................... 35

7.4.13 Ultrasonic Flow Meters ........................................................................................ 35

7.4.14 Flow Conditioners ................................................................................................ 35

7.4.15 Calibration ............................................................................................................ 36

7.4.16 Factory Acceptance Test (FAT) ........................................................................... 36

7.4.17 Systems Integration Testing (SIT) ....................................................................... 36

7.4.18 Site Acceptance Tests ......................................................................................... 36

7.4.19 Commissioning and Startup ................................................................................. 38

7.5 Flow Metering Computers Panel ............................................................................... 38

7.5.1 Panel Design – General ....................................................................................... 38

7.5.2 Power Supplies .................................................................................................... 38

7.5.3 Flow Computers ................................................................................................... 38

7.5.4 Calculations .......................................................................................................... 40

7.5.5 Software ............................................................................................................... 41

7.5.6 Reporting .............................................................................................................. 41

7.5.7 Data Logging and Storage ................................................................................... 42

7.6 Piping ......................................................................................................................... 43

7.7 Utilities ....................................................................................................................... 43

7.7.1 Cold Vent ............................................................................................................. 43

7.7.2 Instrument Air Compressor and Dryer ................................................................. 43

7.7.3 Utility Water System and Fire Water System ....................................................... 44

7.7.4 Diesel Generator (as required) ............................................................................ 44

7.7.5 Heating, Ventilation and Air- Conditioning (HVAC).............................................. 44

8. REFERENCES ...................................................................................................................... 45


Page 5

1. INTRODUCTION



supply. The strategy aims at introducing imported natural gas into Jamaica’s energy supply mix to











Regasification Terminal (SRT) and natural gas export system in Jamaica (‘the PROJECT’) on a Build-



Page 6

2. SCOPE OF WORK

2.1 General

This specification shall cover the minimum requirements for the supply, fabrication and installation of

Submerged Arc Welded Longitudinal (SAWL) carbon steel submarine gas pipeline and the Onshore

Receiving Facility (ORF) including the Fiscal Gas Metering for the Jamaica LNG Project. This

specification is intended for use in conjunction with the Basis of Design (BOD) [1] which details

project specific requirements.

The scope of work to be performed by the CONTRACTOR under this specification includes the

provision of complete design, all labour, materials, tools, facilities and services required to supply,

fabricate, install, test, commission and operate the pipeline and ORF including the Fiscal Gas

Metering.

2.2 Description of Work

The work required by CONTRACTOR includes, but is not limited to, the activities listed below in which

CONTRACTOR shall be responsible.

• Prepare all required documentation

• Procure all required materials.

• Manufacture and test the line pipes.

• Install the submarine pipeline and their tie-in spool piece

• Perform the shore approach installation work by (Horizontal Directional Drilling (HDD)

method

• Design, Engineer, Install complete ORF including the Fiscal Metering.

• Carry out commissioning, start-up and operation of the submarine pipeline, ORF including

fiscal gas metering.


Page 7

3. DEFINITIONS

The following definitions shall apply within this specification:

Boundaries, Limits, and

Exclusions

The package limit shall be regarded as including all elements

as detailed in the scope of supply and all necessary support

services of the management, manufacture, assembly ,testing,

commissioning, start-up and operation of the system(s).

COMPANY The Government of Jamaica (GOJ), acting on behalf of the

Jamaica Gas Trust

CONTRACTOR Reference to nominated SRT & Gas Export System

Contractor(s)

Design The documentation required allowing production of equipment

or provision of service. This documentation or parts thereof

shall enable a review to be performed.

Inspection and Test Plan A schedule of inspection and test activities identifying the

stages at which CONTRACTOR, COMPANY, third parties, or

independent inspectors are involved and additionally

identifying the involved specifications, acceptance criteria, and

instructions that are relevant.

May

PROJECT

‘May’ Indicates where alternatives are equally acceptable

Jamaica LNG Project

Shall ‘Shall’ Indicates where a provision is mandatory

Should ‘Should’ Indicates where a provision is preferred

Sub-Contractor The person, group, or organisation who may be employed by

CONTRACTOR to provide services for the supply of the line

pipes.

Third Party

Will

Independent Verification Body and/or Certifying Authority

acting on behalf of COMPANY.

‘Will’ is used normally in connection with an action by

COMPANY rather than by CONTRACTOR


Page 8

4. ABBREVIATIONS


ASTM American Society for Testing and Materials

BOD Basis of Design


EN

HDD

Euro Norm

Horizontal Directional Drilling

ISO International Standards Organisation

ITP Inspection and Testing Plan

MDR Manufacturer’s Data Report

MPQT Manufacturing Procedure Qualification Test

MPS Manufacturing Procedures Specification

NDT

PLEM

Non Destructive Testing

Pipeline End Manifold


PPM Pre-Production Meeting

QA Quality Assurance

QC Quality Control

RAM Reliability, Availability and Maintenance

SAWH Submerged Arc Welding Helical

SAWL Submerged Arc Welding Longitudinal

SDRL Supplier Data Requirements List

SI International System of Units

SSPC Steel Structure Painting Council

ST

TBABC

Surface Testing

To Be Advised By CONTRACTOR, subject to approval by COMPANY

UT Ultrasonic Testing


Page 14

5. CODES, STANDARDS, REGULATIONS AND PROJECT DOCUMENTS

5.1 General

The SAWL line pipes shall be manufactured and tested in accordance with the requirements of this

specification, the BOD, other referenced project specifications, and the latest editions of the codes,

standards and regulations given at Sections 5.2 and 5.3 and other documents referenced therein.

The pipeline fabrication, transportation, testing and installation shall be in accordance with the

applicable requirements of DNV-OS-F101 (2007), classification rules, laws, this specification, the

relevant BOD, other project specifications where referenced in the Contract, and the latest editions of

the codes, standards and regulations given at Sections 5.2 and 5.3 and other documents referenced

therein.

ORF items design, supply, transportation, installation, testing and commissioning shall be in

accordance with the requirements of this specification, the BOD, other project specifications and the

latest editions of the codes, standards, regulations given in this Specification and other documents

referenced therein.

5.2 Regulations

Where Jamaican Regulations exist, the requirements of these shall apply.


The requirements of the latest editions of the following codes and standards shall be complied with:

5.3.1 SAWL Line Pipes

API 5L Specification for Line Pipe

DNV-OS-F101 Det Norske Veritas, Submarine Pipeline Systems, 2007

EN 10204 Metallic Materials: Types of Inspection Documents

ISO 9001 Quality Management Systems – Requirements

SSPC SP-1

Surface Preparation Commentary for Steel and Concrete Substrates –

Solvent Cleaning


Page 15

5.3.2 Pipeline,Fabrication, Testing and Transportation

5.3.3 ORF

The applicable standards for ORF design, inclusive of fiscal metering requirements, are detailed in

Section 7.1.8.

5.4 Project Documents and References

This specification shall be read in conjunction with the following specifications:

• 402010-00260-00-GE-BOD-0001 Basis of Design

• 402000-00260-00-PR-SPC-0001 Regasification Plant Functional Specification

• 402010-00260-00-MA-SPC-0002 LNG FSRU Functional Specification – Permanently

Moored

• 402010-00260-00-PR-PHL-0001 Pipeline and ORF Operating Philosophy

5.5 Quality Assurance

The CONTRACTOR shall demonstrate that they operate a quality system in accordance with an

internationally recognized standard such as ISO 9001. The effectiveness of the quality system and

the compliance with it shall be subject to monitoring by COMPANY and in addition, may be audited

following an agreed period of notice.

The CONTRACTOR shall submit a Project Quality Management Plan (PQMP) for COMPANY review

and approval, and is solely responsible for ensuring that all Project activities are completed in

compliance with an approved PQMP.

API 5LW Recommended Practice for Transportation of Line Pipe on Barges and

Marine Vessels

DNV-OS-C101 Det Norske Veritas, Design of Offshore Steel Structures, General (LRFD

Method)

DNV-OS-F101 Det Norske Veritas, Submarine Pipeline Systems, 2007

EN 10204 Types of Inspection Documents

IMCA D-014 IMCA International Code of Practice for Offshore Diving

IMCA D-018 Code of Practice on the Initial and Periodic Examination, Testing and

Certification of Diving Plant and Equipment

IMCA D-023

Diving Equipment Systems Inspection Guidance Note (DESIGN) for

Surface Orientated (Air) Diving Systems


Page 16

5.6 HSE The CONTRACTOR shall provide Health, Safety and Environmental (HSE) manuals and procedures that adequately cover all aspects of the WORK for COMPANY review and approval. The CONTRACTOR is solely responsible for ensuring that all Project activities are completed in compliance with approved HSE procedures.

5.7 Inspection and Testing

CONTRACTOR shall develop an Inspection and Test Plan (ITP) for submission to COMPANY for

approval prior to the commencement of manufacture. CONTRACTOR shall perform inspection and

testing activities in accordance with the requirements of this specification and the approved inspection

and test plan(s).

CONTRACTOR shall prepare inspection and test procedures in accordance with quality assurance

requirements (TBABC).


Page 17

6. PIPELINE REQUIREMENTS

6.1 General

In general, the SAWL pipeline shall be manufactured and tested in accordance with the requirements

in Section 7 of DNV-OS-F101 with additional requirements in this project specification.

Mechanical and corrosion testing of the pipelines shall be conducted in accordance with Appendix B

of DNV-OS-F101.

Welding of the pipelines shall be performed in accordance with Appendix C DNV-OS-F101 and all

Non-Destructive Testing (NDT) shall be conducted in accordance with Appendix D of DNV-OS-F101.

6.2 Manufacturing

CONTRACTOR shall prepare a Manufacturing Procedures Specification (MPS) and a Manufacturing

Procedure Qualification Test (MPQT) and seek COMPANY approval prior to commencement of

production. The MPS and MPQT shall be in accordance with the requirements in Section 7, A600 of

DNV-OS-F101.

6.3 Pipeline Properties

The subsea pipeline will make landfall at Old Harbour. The specific landfall and ORF location to be

advised by CONTRACTOR, subject to approval by COMPANY (TBABC).

CONTRACTOR is responsible for completion of pipeline sizing to meet the gas throughput

requirements including flow, temperature and pressure as per BOD [1]. Pipeline shall be designed for

Design Life as specified in BoD[1]. The pipeline shall be fitted with a “Last Valve Off” (LVO) located

downstream of the SRT regasification unit outlet manifold, as well as “First Valve On” (FVO)

immediately upstream of the ORF for the purpose of emergency shutdown.

Contractor to provide the details in Table 6-3 below at star marked ‘*’ locations:


Page 18

Table 6-3.1: Line Pipes Properties (from SRT to Old Harbour and from SRT to Rocky Point) Properties Unit Value

Outside Diameter mm *

Thickness (tnom) mm *

Length m *

Material Grade - DNV Grade 360

SMYS MPa *

SMTS MPa *

NDT Level - Ref. to Appendix D, DNV-OS-F101

Density kg/m3 *

Internal Corrosion Allowance mm 1

Young’s Modulus GPa *

Poisson’s Ratio - *

Thermal Expansion Coefficient °C-1

*

Thermal Conductivity W/m°C *

Design Temperature °C *

End Finish - *

6.4 Material Properties Material of the line pipes shall be suitable for field welding using conventional welding process.

without preheating and/or Post Weld Heat Treatment (PWHT).

The weldability of the line pipes shall be as follows:

• Steel shall have adequate weldability for all stages of manufacture, fabrication & installation

of the pipeline, including field contingency condition and anode installation.

• Welding and welding procedures, welding personnel, handling of welding consumables, and

the execution of welding shall meet the requirements in Appendix C of DNV-OS-F101.

Requirements for the methods and procedures for the mechanical and corrosion testing are

those as given in Appendix B of DNV-OS-F101.

6.4.1 Chemical Composition

The chemical composition of the line pipes shall comply with the requirements in Table 7-3, Section 7

of DNV-OS-F101 (For delivery condition N or Q and welded pipe).


Page 19

6.5 Exceptions, Clarifications and Additions to DNV-OS-F101

CONTRACTOR shall indicate if there are any exceptions, clarifications and additions to the DNV-OS-

F101 [TBABC]

6.6 Documentation

All documentation and correspondence shall be in the English Language.

The International System of units (SI) shall be used in all documentation. Equivalent imperial

dimensions may be shown in parenthesis following the SI units.

Before dispatch of the line pipe to the site, CONTRACTOR shall carry out all manufacturer’s standard

quality tests and all factory inspections and tests called for in the specifications.

CONTRACTOR will submit the key documents to COMPANY for review and approval (TBABC).

6.7 Transportation, Handling, Storage and Marking

Marking shall be as per API 5L. Pipe numbers shall be hard stamped at one pipe end. As a minimum

the following information shall be paint stencilled on each pipe at one end, parallel to the pipe axis:

• COMPANY name

• Project name

• Manufacturer name

• Purchase order number

• Pipe outside diameter (mm)

• Pipe wall thickness (mm)

• Pipe material grade

• Unique pipe number (shall reflect correlation between pipe and the respective inspection

document)

• Heat number

• Joint length

All marking shall be easily identifiable and in such a condition that it is readable during the

subsequent activities.

Each pipe shall be clearly identified by means of markings made with indelible white or yellow paint,

on the inside pipe surface at both pipe ends, and a circumferentially painted color band on the inside

surface of each pipe end. In addition, there shall be a colour-coded band indicating pipe wall

thickness. Band colours are to be agreed upon at the time of order placement.

The CONTRACTOR shall ensure that all suppliers and subcontractors provide appropriate protection

for all goods shipped, such as will prevent damage and/or contamination by the elements.


Page 20

Any packing slips, import documents, etc. shall be sealed and securely attached or enclosed with the

shipment.

The pipeline shall be delivered safely, cleanly and free from all oil, grease and other deleterious

materials on pipe surface for every stage of construction. If the pipe is not clean due to oil, grease

and other deleterious materials on pipe surface, it shall be cleaned by solvent cleaning in accordance

with SSPC SP-I.

Transportation, handling, storage and marking procedures (including any supporting analysis and

specification) shall be submitted by CONTRACTOR for review and approval by COMPANY. These

procedures shall include stacking plans for the lay down areas at the mill and also stowage plans for

all types of transport used to ship the pipe to the coating yard. Pipe shall be handled and transported

at all stages of manufacture and delivery in a manner that is in accordance with international

standards so as to ensure the pipes fitness for service and preclude the necessity for remedial works

prior to installation.

6.8 Pipeline Fabrication and Installation

Contractor shall carry out all Pre-Shipping Inspection of materials prior to loading onto pipe-haul

vessels. A load out inspection report shall be carried out. Pipe handling and stacking shall conform to

the requirements of API 5LW and COMPANY approved handling procedure. Damaged materials shall

be repaired by Contractor to an agreed procedure.

Contractor shall provide, maintain and operate adequate horizontal positioning systems to determine

the location of construction and survey vessels at all times. Contractor shall provide all necessary

maps, nautical aids, navigational warnings, transponders and the like required to properly and safely

conduct the work.

The pipelines shall in general, be laid on the theoretical route as shown in the alignment sheets within

the tolerances as specified in Table-6-9.1.

Table 6-9.1 PIPELINE TOLERANCES

Location

Tolerances

Lateral Tolerance with Respect to Nominal

Centreline

Longitudinal Tolerance with Respect to Locations

Specified

Normal lay ± 10 m N/A

Start-up and Lay-down Abs.: ± 2.5 m Abs.: ± 2.5 m

Lay down heading ± 1° N/A

Particular areas As defined in Drawings N/A

For pipelines start-up and lay-down, at the cable crossing, if any and at other particular areas defined

in drawings, an acoustic positioning system shall be used to assist with positioning of the pipelines in

the target areas. Contractor shall exercise extreme care when anchoring with close proximity of the

as-laid pipelines or other facilities.


Page 21

The lay- vessel shall be equipped with a mooring system adequate for all phases of installation

including pipelaying, pipeline initiation, laydown, and abandonment and recovery operations.

Prior to commencement of Off-shore pipeline installation work, Contractor shall prepare all necessary

engineering studies and calculations including all required construction procedures.

For on-shore initiation, Contractor shall prepare procedures for the HDD pipeline lay method. On

completion of the HDD section Contractor shall commence normal pipe lay operations to install the

pipelines.

Pipelines cleanliness objective shall be to prevent the presence of any foreign matter in the pipelines.

All debris produced as a result of the backwelding and internal repairs shall be removed from the

inside of the pipeline.

The shore approaches shall be constructed by using an approved HDD technique.

Contractor shall develop the design pipeline profile, to the criteria stated below, unless otherwise

agreed.


Page 22

Table 6-9.2 PIPELINE DESIGN PROFILE

Element Criteria

Entry HDD location Within a 2m radius of the design location.

HDD exit break out location To suit design profile.

HDD entry angle To suit HDD installation method and pipe stresses.

HDD exit angle To suit HDD installation method and pipe stresses but not more than 4°.

Pipe bend radius To suit HDD installation method and pipe stresses but not less than 1000m.

Pipe stress for installation, testing and operation

Not to exceed design code allowable stress value (DNV OS-F101).

Contractor shall prepare detailed construction procedures for inclusion within the Installation Manual.

CONTRACTOR shall be responsible for the selection and provision of a mechanical protection

coating to the pipeline external corrosion coating. This coating may also be used to provide the

pipeline with additional weight required for optimum down hole installation and also subsea stability (if

the pipes are not concrete coated).

CONTRACTOR shall specify drilling fluids, including type(s) of fluid, quantity(ies) required and

proposals for handling, storing, hydrating, mixing, pumping, recirculating and disposal. The Material

Safety Data Sheets for the drilling fluid composition shall be submitted to COMPANY for approval.

The drilling fluids shall be designed in accordance with the requirements of the Environmental

Performance Standards for EPC Contractors. Oil based fluids shall not be permitted.

The fluids proposed shall comply with all relevant regulations. The proposed methods for final

disposal of fluids shall be in accordance with the Environmental Impact Assessment approved by

COMPANY and the relevant governing environmental authority. Special consideration shall be given

for breaking out at the seaward end where discharge to the sea will be inevitable. CONTRACTOR

shall provide methods to reduce discharge of drilling fluid, such as using water or reduced mud

concentration, subject to approval.

CONTRACTOR’s overall Environmental Management Plan (EMP) shall cover all aspects of the HDD

construction activities at the shore approach site.

The EMP shall specify environmental impacts and mitigation measures in accordance with the

requirements of the Environmental Performance Standard for BOT Contractors, but not limited to, the

following:

Site cleanliness

Site clearings and reinstatement

Plant access and routes to and from site

Vehicle/plant wash down facilities


Page 23

Water supply and storage

Drilling location water and mud spillage management

Storage of mud, recirculation and final disposal of mud, fluids and drill cuttings

HDD mud break out at exit location subsea and associated discharge to sea

HDD mud break out at locations along the drill profile other than exit points

Storage and disposal of contaminated water

Removal of surplus materials

Soil contamination, treatment, removal, and replacement

Noise control

Air emission control

Chemical storage and handling

Fuel storage and handling

Waste oil management

Contractor shall perform all hydro tests as per applicable codes and standards.

At all times during the pipe lay operations, CONTRACTOR shall keep an accurate record of the

sequential, as-laid pipe for the pipeline. As a minimum the following information shall be recorded:

COMPANY name.

Project name.

Line pipe manufacturer’s name.

Purchase order number.

Pipe outside diameter (mm).

Pipe wall thickness (mm).

Pipe material grade.

Heat number.

Joint Length.

Anode or buckle arrestor joint.

Weld identification and details.

Field joint coating details.

Unique pipe identification number.

Contractor shall provide all documentation and correspondence in English Language. Documentation

shall be submitted for Company review and approval.


Page 24

7. ONSHORE RECEIVING FACILITY (ORF)

This section provides an overview of the process & utility equipment required to be installed on the

ORF. Process equipment shall be prefabricated offsite as skidded structures with all the associated

piping and accessories pre-installed as far as possible in order to minimize the construction activity at

site.

The incoming gas is received from the pipeline at the Old Harbour Onshore Receiving Facilities

(ORF). The various Process & Utility equipment proposed to be installed on the ORF at Old Harbour

are outlined below:

1. Pig Receiver

2. Pipeline filters;

3. Fiscal Metering;

4. Cold vent;

5. Instrument air compressor and dryer;

6. Utility water storage tank;

7. Fire water system; and

8. Diesel generator (as required).

From the ORF, the gas will be distributed to the Project’s end-users via user or third party pipeline(s).

Pressure let down, preheating and cold recovery requirements shall be the responsibility of the gas

end users.

7.1 General Requirements

7.1.1 Design Life

The design life of the facility and all associated equipment, component and systems is detailed in the

BoD [1]. The design life shall be achievable with minimal on site maintenance and optimal availability.

All components which for reasons of practicality, safety or cost-efficiency are unable to meet the

required design life shall be identified as soon as possible. Their expected services life shall be

informed to COMPANY and provision made in system design for maintenance to extend component

life or routine change out.

7.1.2 Human Factors Engineering

The CONTRACTOR shall ensure that human capabilities, limitations and needs are considered in the

design and layout of the equipment. The intention is to improve safety, health, efficiency and comfort

of the operator.


Page 25

7.1.3 Units of Measurement

All equipment and documentation shall use units of measurement as per BoD[1]. CONTRACTOR

shall confirm any additional units requirements with COMPANY [TBABC].

• Gas Flow MMscfd

• Nominal pipe size inch

• Hydrocarbon Cricondentherm °C

• Water Content mg/sm3

• Wobbe Index MJ/sm3

• Lower Heating Value (LHV) MJ/sm3

7.1.4 Hazardous Area Classification

All instruments, equipment, materials and installation methods shall comply and fully satisfy the

statutory requirements for the area classification identified on the package specifications / datasheet.

All instruments are to be certified as suitable for use in a Zone 1, Gas Group IIB, and Temperature

Class T3 hazardous area as a minimum.

The installation of all electrical equipment in hazardous area shall comply with the requirements of

IEC 60079-14 “Electrical Installations Design, Selection and Erection” and IEC 60079-10 “Electrical

Apparatus for Explosive Gas Atmosphere - Part 10: Classification of Hazardous areas”.

Electrical equipment that are required to be installed in hazardous area shall have European or

Testing Authorities Certification, i.e. PTB (Germany), BASEEFA (UK), ATEX as approved by

COMPANY.

Hazardous area protection shall be by use of flame proof (EEx’d’) or increased safety (EEx’e’)

housing and ancillaries. Where the EEx’d’ and EEx’e’ executions are either impractical, cost-

prohibitive or not permitted, intrinsically Safe (EEx’i’) circuits can be used as an alternative. The

proposal to use IS type instruments shall require Company approval (in writing) prior to purchase of

the equipment.

7.1.5 Availabil ity and Reliability

The overall availability and reliability of the complete package shall be demonstrated by the

CONTRACTOR. Availability and Reliability will be as specified in BoD [1].

The CONTRACTOR shall furnish their best estimates of Mean Time Between Failures (MTBF) and

Mean Time To Repair (MTTR) for the equipment concerned.

In making assessments of the package availability and reliability, the CONTRACTOR will need to

estimate maintenance and repair times. For the purpose of making such estimates, the

CONTRACTOR may assume that the spares holding is in accordance with the submitted

recommendations unless otherwise stated. In the case of failure modes, which make a significant


Page 26

contribution to the overall unavailability, the CONTRACTOR may be required to demonstrate that

their assumed repair times can be achieved.

7.1.6 Design Document Order of Precedence

In the event of any conflict arising between this Specification and other documents listed herein, refer

comments to the COMPANY for clarification before design or fabrication commences. The order of

precedence that applies is as follows:

Applicable Statutory Codes and Standards

Project Basis of Design [1]

Project Scope of Work document [3]

This Specification

International Codes and Standards

7.1.7 Plot Layout, Piping Specification breaks

The ORF plot layout shall be optimized considering operability and safety in view. The Piping will

consider the Insulation joints, specification breaks suitably and adequately as per good engineering

practices.

7.1.8 Codes and Standards

American Gas Association (AGA)


Gases

AGA Report No. 9 Measurement of Gas by Multipath Ultrasonic Meters

American Petroleum Institute (API)

API RP 520 Part 1 Sizing, Selection, and Installation of Pressure-Relieving Devices in

Refineries; Part 1 – Sizing and Selection

API RP 521 Guide for Pressure Relief and Depressurising Systems

American Society of Mechanical Engineers (ASME)

ASME PTC 19.3 Temperature Measurements


ASME Section II Materials (Parts A, B, C, D)

ASME Section V Non-Destructive Examination

ASME Section IX Qualification Standard for Welding and Brazing Procedures


Page 27

American Welding Society


Engineering Equipment and Materials Users Association (EEMUA)

EEMUA 140 Noise Procedure Specification

International Institution for Standardisation (ISO)

ISO 5168 Measurement of fluid flow - Evaluation of uncertainties

ISO 6327 Gas analysis - Determination of the water dew point of natural gas -

Cooled surface condensation hygrometers

ISO 6976 Natural gas -- Calculation of calorific values, density, relative density

and Wobbe index from composition

ISO 9001 Quality Management Systems – Requirements

7.1.9 Documentation

The CONTRACTOR is responsible to provide all necessary documentation for the equipment items to

have a smooth, trouble free and safe operation which shall include, as a minimum, the documentation

listed below. The CONTRACTOR is responsible for all documentation in strict accordance with the

requirements of this Specification. Further details on documentation requirements, including a full

Vendor Data Requirements List (VDRL), shall be provided.

Fabrication shall not commence until the COMPANY approves the calculations, drawings, and any

other design documentation or procedures.

Drawings and documentation to be provided for the following main project phases as a minimum :

1. COMPANY Approval during Design (including submission for approval and

subsequent re-submissions to incorporate comments).

2. As-Built following factory testing.

3. As built (Following commissioning)

Note: As-built (2 above) drawings to accompany equipment following factory testing. The

CONTRACTOR shall carefully schedule and control this revision of drawings to ensure drawing

accuracy but prevent delay in shipment following factory testing.

7.1.10 Purchase Order Documentation

The following documentation shall as a minimum be included in the CONTRACTOR’s scope of

supply:

• Document List

• Project Schedule

• Inspection and Test Plan


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• Equipment Datasheets (all instruments and equipment)

• General arrangements

• Piping and Instrument Diagrams (P&IDs)

• Termination Diagrams

• Lifting detail drawings

• Weight Data Sheet

• Sizing Calculations

• Test Procedures

• Installation Procedures

• Maintenance Procedures

• Recommended Spares List

• Certification

• Test Results

• Shipping and Handling Procedures

7.1.11 Material Certification

All materials that require certification shall be identifiable against their certification and as a minimum

comply with the following requirements:

• Pressure containing or load bearing parts EN10204, 3.1 No. “B”

• Gaskets and non-load bearing parts EN10204, 2.2

7.1.12 Field Transmitters

Transmitters measuring variables used in calculations performed by the flow computers shall

interface directly with the flow computers using digital communications e.g. HART to avoid

unnecessary inaccuracies from conversion to and from 4-20mA.

7.1.13 Actuated Ball Valves

Valves shall be in accordance with the appropriate piping class and valve material specification.

Actuators shall be pneumatic, powered from instrument air at the pressures defined in BoD [1]

[TBABC].

7.1.14 Spares and Consumables

The CONTRACTOR shall identify the following spares:

• Pre-commissioning, commissioning and start-up spares


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• Recommended spares list for two years operation

Consumables shall be sufficient for initially for 6 months (minimum) operation (including calibration

and test gases) and shall be replenished and stocked as necessary.

7.1.15 Special Tools

The CONTRACTOR shall identify all necessary special tools required to perform routine maintenance

and any other recommended tools for specialised procedures.

7.2 Pig Receiver

Pig Receiver shall be installed in ORF area for the incoming pipeline from SRT. The Pig Receiver

shall be provided to allow pigging of the pipeline. As the export gas is non-corrosive and does not

contain liquids, it is expected that pigging shall only be required on initial commissioning and

afterwards only for intelligent pig surveys as required by the Regulatory Authorities for inspection of

the pipeline.

Pig Receiver shall be designed, fabricated, tested and inspected in accordance with ASME Section

VIII, Div. 1. CONTRACTOR will provide Pig Receiver design data. Refer BoD [1]. The design of the

Pig Receiver will be suitable to meet the throughput and design parameters of the incoming pipeline.

Pig Receiver shall be oriented horizontally and fitted with a vertically hinged quick opening end

closure, pressure locking device and safety devices. Given pigging requirements are envisaged to be

infrequent, the CONTRACTOR, may provide tie-ins for pig receipt and utilize a temporary receiver as

required in preference to installation of a permanent equipment. In the event that a temporary

arrangement is pursued, supply of all equipment for pipeline pigging as needed shall be the

responsibility of the CONTRACTOR.

7.3 Pipeline Filters

The incoming gas shall be filtered to remove particles which may damage the downstream flow

meters. There are two filters with a maximum capacity of [TBABC] mmscfd each, fully spared (one

duty and the other one as standby). Each filter shall be equipped with a pressure differential gauge to

allow for online filter monitoring. A differential pressure transmitter shall initiate an alarm to alert

operator to changeover to the other filter. This will be a manual operation.

A pressure safety valve (PSV) is installed at filter outlet to protect the filter from overpressure; the

relief pressure being set at [TBABC] barg.

The filters shall be vertical pressure vessel, basket or multiple cartridge type [TBABC] with a quick

opening closure for basket change out. The baskets shall be cleanable and reusable. Design data for

the filters shall be provided by CONTRACTOR referring to the Table in BoD [1].

The Gas filters shall be installed initially for meeting the requirement of Phase 1. Refer BoD [1].

Provision will be kept in piping and in plot plan to install one additional filter in future.

The Gas Filters shall be designed to achieve removal of solid particles larger than 1 micron at 100%

filtration efficiency.


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Each filter element shall be sized according to operating and design conditions detailed in the BoD

document [1].

Pressure drop across a filter shall be 1 barg (maximum) at dirty condition.

The gas filter shall be vertical pressure vessel designed as per ASME Section VIII Div. 1.

7.4 Fiscal Metering

Design and manufacture of Fiscal Gas Metering System shall be in accordance with this specification

unless otherwise agreed in subsequent written communication between CONTRACTOR and

COMPANY.

The Fiscal Gas Metering System shall be factory assembled package ready for trouble free safe

operation. CONTRACTOR to refer to BOD for metering skids requirements and provisions to be kept

for future BoD[1].

The fiscal gas metering system shall be complete with, but not limited to, the following equipment and

requirements:

• Fiscal application approved, redundant, multi-path ultrasonic flow meters

• Gas Chromatograph and sampling system

• Hydrocarbon Dewpoint Analyser

• Water Content Analyser

• Isolation and switching valves

• Flow computers

• On skid piping, instrumentation and equipment

• Meter proving

• Protective coating

• Packaging and marking for transport

• Start up and commissioning spare parts

• Special tools

• Consumables (including calibration and carrier gases) for operation

• Documentation, drawings, and certification

7.4.1 Metering Skid Overview

The fiscal gas metering system shall comprise two 100% redundant, parallel, ultrasonic metering runs

complete with flow conditioners, pressure and temperature measurement instrumentation, pipework,

valves and support steelwork and a remote fiscal gas flow metering panel housing independent run

flow computers. The system shall also include a gas chromatograph, hydrocarbon dewpoint


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analyser(s), water content (dewpoint) analyser and the associated sample extraction and conditioning

facilities.

7.4.2 Metering Skid Operation

The flow meters will normally be operated as parallel runs with only one run online at a time.

Changeover between the flow metering runs shall be achievable remotely through commands

initiated from the Process Control System (PCS) [TBABC] and activated through the flow metering

computers. Configuration of the changeover sequence shall ensure that a gas flow path from the inlet

to the outlet of the skid is maintained at all times during changeover.

The parallel ultrasonic metering runs shall be capable of being lined up serially via a skid based

crossover complete with two full bore isolation ball valves, to facilitate cross-checking of meter

indications. Changeover between parallel and series operation of the flow meters shall be achievable

remotely through commands initiated from the Process Control System (PCS) and activated through

the flow metering computers.

The flow meter in service shall determine actual (uncorrected) gas flow by measurement of gas

velocity. Gas compressibility, density and calorific (heating - LHV) values shall be calculated by the

Gas Chromatograph from the measured compositional data. Using this and the flowing pressure and

temperature measurements, the flow computer shall calculate standard volumetric flow rate, energy

and mass flows.

Measurement of the hydrocarbon dewpoint shall be through a dedicated hydrocarbon dewpoint

analyser system interfacing to the PCS.

Measurement of water content shall be through a single water content analyser (water dewpoint

analyser) interfacing to the PCS.

7.4.3 Temperature Instrumentation

A temperature transmitter shall be installed on each metering run.

Temperature measurement and test thermowells shall be located in the metering runs in accordance

with AGA-9. Thermowells shall be located in the top of the pipe.

Thermowell wake frequency and stress calculations shall be performed to ASME PTC-19.3 and

submitted for approval.

7.4.4 Pressure Instrumentation

A gauge pressure transmitter shall be installed on each metering run.

7.4.5 Gas Chromatograph

An industrially hardened process Gas Chromatograph (GC) (as opposed to a laboratory type GC)

shall be fully integrated into the package skid and the associated control electronics may be

incorporated into the Flow Metering Computers Panel or alternately be located on the skid with the

field GC equipment.


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The gas chromatograph shall provide online analysis of gas composition.

The Gas chromatograph shall utilise a fast loop sample system to ensure a representative sample is

obtained. Sample collection and disposal shall be engineered suitably as per good engineering

practices. Sample disposal should be to the process cold vent system if possible. CONTRACTOR

shall advise if venting to atmosphere is required.

Gas chromatographs shall utilise proven technology and have a proven track record.

The process conditions and performance requirements of the gas chromatograph shall be as detailed

in this specification and based on the process data detailed on the Project Data Sheets attached to

the purchase order.

The gas chromatograph shall be capable of compositional analysis of the following, in mol%:

• C1 to C6+

• Nitrogen

• Carbon Dioxide

Calculations of the following are required to ISO 6976, The compressibility is to be calculated to AGA

Report No. 8 which shall be accessible serially:

• Compressibility (Z)

• Lower Heating Value (LHV)

• Wobbe Index (WI)

• Relative Density (ρr)

• Standard Density (ρs)

• Operating Density (ρf)

• Speed of sound in gas at Operating Conditions (Cf)

The algorithm and truncation rounding errors for computations performed by the analyser shall be

less than ±0.0001%. This requirement shall be verifiable.

The use of hydrogen, pure oxygen or gas mixtures having compositions within explosive limits for any

purpose other than as calibration sample is to be avoided.

The analyser shall be supplied as a free-standing unit and shall include all accessories required for

calibration and six months (minimum) operation including carrier and calibration gases.

The analyser shall be supplied factory programmed, tested and calibrated for use on the gas as

specified in the BoD [1]. Access to software configuration routines shall be controllable to restrict

unauthorised modifications. Key lock control is preferred; however, password control is acceptable.

Network connectivity for remote configuration / diagnosis shall be provided. Connectivity shall be

from COMPANY offices via COMPANY networks [TBABC].

The gas chromatograph together with its sample collection system shall be capable of providing the

following performance criteria:


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• Time between samples, including all purge and analysis phases shall be 5 minutes maximum.

• Analyser system shall provide repeatable results within the ambient environmental conditions

as specified in BoD[1]. CONTRACTOR shall advise if an analyser enclosure or shelter is

required and include in the tender.

• The minimum time between automatic calibrations shall be daily. CONTRACTOR shall advise

longest time allowable between automatic calibrations in order to meet the performance

requirements for this application.

• Automatic calibration shall correct for any drift in analyser characteristics.

• The minimum time between inspection and/or manual calibration checks shall be 6 months.

• The analyser shall be capable of providing extensive self-diagnostic facilities, while on-line and

without impacting on the system operation or hazardous area certification status.

• The analyser shall, as a minimum, provide a 4 to 20mA externally-powered optically isolated

analogue signal representing the concentration range of any specific gas component as

selected by the operator. These shall interface with the Purchaser’s PCS (HOLD).

• The analyser shall, as a minimum, provide two user configurable volt-free contacts rated at 24V

DC, 0.5 Amps for use by others.

• The analyser system shall interface with the Purchaser’s PCS utilising serial communications

for unit status, alarm and diagnostic information. The preferred protocol for digital

communication is PROFIBUS however MODBUS is also acceptable.

• The analyser shall calculate and report to a minimum basic accuracy of ± 0.05% of reading the

component concentrations (mol%) of the gas.

• The repeatability of the Gas Chromatograph shall be within the following limits (or better if

required to achieve associated fiscal gas metering performance criteria).

Table 7-4.1 Flow Computer I/O Listing

Component Range (mol %) Standard Deviation (mol %)

0 – 25 0.02

25 – 100 0.05

• The uncertainty of the computed higher heating value (LHV) shall not exceed 0.025% absolute.

• The following alarms shall be reported by the analyser, as a minimum:

− Low calibration gas pressure

− Internal fault (eg oven temperature, electronics failure, power failure, missed

component).

− Loss of sample flow.

− Loss of fast loop return flow.


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− Loss of utilities (eg low carrier gas pressure).

− Pressurisation failure.

− Hardware fault.

− Loss of power.

7.4.6 Calibration and Carrier Gas

CONTRACTOR shall supply all calibration and carrier gases inclusive of cylinders and associated

equipment e.g. valves, hoses.

7.4.7 Hydrocarbon Dewpoint Analyser

A hydrocarbon dewpoint analyser system shall measure the hydrocarbon gas dewpoint temperature.

Actual pressure and temperature design requirements shall be confirmed by CONTRACTOR and

fixed during commissioning.

The analyser sensor shall utilise proven technology e.g. chilled mirror with IR photodiode and have a

proven track record. Preference shall be given to the use of direct measurement instruments rather

than calculated values.

The analyser shall be capable of measuring HC dewpoint over the minimum range 0 to 35 ºC and

have an accuracy of ± 1.5 ºC minimum.

7.4.8 Water Content Analyser

Water content analyser systems shall measure the water content in the hydrocarbon gas stream.

The primary output from the analyser shall be water content (mg/sm3).

The analyser shall have an accuracy of ±2 ºC dewpoint temperature for dewpoint measuring

instruments or ±10% of measured value for water content measuring instruments.

7.4.9 Analyser Shelter

To provide additional protection, ensure satisfactory performance of the analysers, and to facilitate

maintenance activities, if required Vendor shall furnish a complete analysers shelter for analyser

systems including analyser sampling system. Analyser shelter may be used when the analysers

comply with the hazardous area classification of the location and the environmental conditions where

they are installed.

7.4.10 Sample Conditioning and Sampling Systems

Sample conditioning systems shall include all components required to condition the process sample

to achieve the performance requirements for the analyser.

Sample systems shall minimise the time lag between the process sample being taken and the

analysis being completed.


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7.4.11 Overall Measurement Uncertainty

The CONTRACTOR shall guarantee the fiscal gas metering system to measure energy flow to within

an uncertainty of < ±1.0%. This guarantee shall be valid for all flow rates between 5% and 100% of

the COMPANY’s nominated maximum “calibrated range” value and at all specified gas pressures,

temperatures and compositions. Refer to BoD [1]. Performance shall be maintained across these

conditions without any requirement for manual adjustment.

CONTRACTOR shall demonstrate uncertainty with calculations. Uncertainty calculations shall be

supplied in accordance with ISO-5168. These calculations shall address measurement uncertainties

for energy, standard volumetric, actual volumetric and mass flow and shall take into account errors

from all system components including; piping geometry, ultrasonic meters, GC, pressure and

temperature transmitters, calculations, IS isolators (if required), A/D converters, rounding errors etc.

7.4.12 Metering Runs Layout

The layout and design of the piping spools and other equipment comprising each of the metering runs

shall be identical in design and layout.

7.4.13 Ultrasonic Flow Meters

Fully spared multi-path, spool type ultrasonic flow meters shall be supplied in accordance with this

specification.

The design and fabrication requirements (meter requirements, performance requirements, individual

meter testing requirements, and installation) of flow meters shall comply with AGA Report No. 9

(Measurement of Gas by Multipath Ultrasonic Meter).

The flow meters shall have internal diameters matching the upstream and downstream metering runs.

All meter body process flanges shall be ASME 600# RF [TBABC] including process connections used

for line pressure measurement.

Flow meter type shall have approval by an independent metrology organisation for use in custody

transfer applications.

Flow meter shall not suffer any damage or performance deterioration due to rapid depressurisation or

pressurisation of the meter runs.

7.4.14 Flow Conditioners

Flow conditioners shall be provided to achieve a fully developed flow profile at the ultrasonic meter.

The flow conditioner type shall be inherently designed to minimise the likelihood of clogging and

fouling.

Flow conditioners shall be flanged spool type, not insertion sleeve type.


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7.4.15 Calibration

All equipment used in the calibration of the Fiscal Gas Metering System shall have current master

calibration certification traceable to primary national standards.

Appropriate calibration certificates shall be supplied for all calibration tests.

The CONTRACTOR shall perform a high pressure natural gas calibration of the ultrasonic flow

meters at a COMPANY approved facility. This calibration shall include each of the flow meters. There

shall be a minimum of 6 calibration points evenly spread across the meter design flow range.

The following dry calibration tests shall be performed in accordance with AGA-9 and the referenced

standards:

• Dimensional Measurements

• Zero-Flow Verification Test (Zero Test)

The ultrasonic flow meters shall be zeroed using nitrogen to verify transit-time measuring system of

each meter. A zero-flow offset factor shall be documented.

Pressure and temperature transmitters shall be calibrated. Temperature transmitters shall be

calibrated with their respective RTD’s.

7.4.16 Factory Acceptance Test (FAT)

The complete Fiscal Gas Metering System shall be subject to a Factory Acceptance Test (FAT) at the

CONTRACTOR’s works in order to verify the design, construction, functional operation and

performance is fully in accordance with the requirements.

The GC interface shall form an integral part of the package FAT.

The FAT shall include, but not be limited to the functional test of all equipment and interfaces.

The equipment shall be shop tested in accordance with and will conform to the requirements of this

specification and National Standards and Codes.

Tests shall be witnessed by COMPANY or COMPANY’s authorised representative as identified in the

project quality control plan.

7.4.17 Systems Integration Testing (SIT)

After the satisfactory completion of FAT for the Package, the Gas custody transferring system and

other sub-systems and their components will be shipped to, assembled and interconnected at a

staging facility nominated by the PCS Supplier and approved by the COMPANY. Where practical, the

SIT may be conducted concurrently with the FAT.

7.4.18 Site Acceptance Tests

The SAT shall be based on a sub-set of the FAT procedures supplemented by tests which can be

carried out only at site, for location, logistical or technical reasons.


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The tests shall be carried out in accordance with a testing procedure specification prepared by the

Vendor and agreed by the Company in advance of commencement.

The purpose of the SAT is to establish that the package equipment has been shipped without

damage, has been correctly installed, and operates reliably to specification in its final environment.

The SAT procedure shall be carried out in accordance with the requirements defined in the following

sections.

The SAT objectives are listed as follows:

• Ensure that all deliverable items -hardware, software, documentation, media, interconnecting

cables, etc -are present and acceptable.

• The correct functioning of the supplied package in accordance with the applicable functional

specifications, including all interfaces to other equipment and sub-systems connected to the

final power supply and earthing system.

• The system operates under load conditions over the test period at or better than design

availability.

• The system can tolerate failure of individual modules and sub-systems and be recovered to

full function following repair and re-instatement of such items.

• That all timer settings and alarm/trip set-points that may have been modified for the purposes

of FAT have been re-configured to their correct values.

• That all remedial punch-list work agreed at the FAT has been satisfactorily completed by the

Supplier and the system meets its design specification in full.

• The operator interface is both safe and operable with respect to the presentation of data and

alarms and the implementation of control.

The SAT shall confirm correct installation and configuration of all equipment. Any equipment added or

replaced since the FAT shall be fully tested. This shall include but not be limited to the following

activities:

• Power distribution and earthing checks.

• Check for ancillary equipment interference.

• Check noise levels versus specification.

• Check operation and performance of all connected sub-systems. In particular those not

previously tested at FAT.

Any software which has been subject to remedial work since FAT should be thoroughly retested

including any potential impacts on unmodified software. Similarly any software added since FAT

should be fully tested.


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7.4.19 Commissioning and Startup

The COMPANY’s final acceptance of the equipment will be subject to a performance test once the

equipment has been installed and commissioned at site.

7.5 Flow Metering Computers Panel

7.5.1 Panel Design – General

The flow metering computers panel design shall be in accordance with normal oil and gas

requirements for cabinets in air conditioned rooms.

7.5.2 Power Supplies

Power supply to the Chromatograph shall be consistent with manufacturer requirements [TBABC].

As far as possible, the power supplies for the all metering runs shall remain segregated.

7.5.3 Flow Computers

One flow computer shall be supplied per metering run.

Each flow computer shall provide the following I/O and interfaces with the devices listed:

Table 7-5.1 Flow Computer I/O Listing

Device Signals Communications

Ultrasonic Flow Transmitter • Flow Pulse

• Status, Diagnostics, Signal

Validity

RS-485 PROFIBUS or Modbus

RTU

Pressure Transmitter • Pressure 4 – 20mA / HART

Temperature Transmitter • Temperature 4 – 20mA / HART

Gas Chromatograph (GC) • Gas composition, Calorific

Value, Compressibility,

Standard, flowing and

relative density as per

section 6.9.4

• Compounds to C6


RTU


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Device Signals Communications

• GC Status Digital Volt Free Contact,

Normally Closed, Open on

Alarm

Process Control System (PCS) • All instantaneous and

totalised flow values, all field

transmitter instantaneous

values


RTU

• common fault Digital Volt Free Contact,

Normally Closed, Open on

Alarm

Output to Totaliser

(Provided on Flow Computer)

• Totalised Actual

(uncompensated) Volumetric

Flow

• Totalised Energy Flow

Digital Display on Flow

Computer Facia

Configuration Laptop

(Supplied by Others)

• Configuration Interface RS-485 PROFIBUS or Modbus

RTU

Printer (Supplied by Others) • Refer section 6.9.5 Local

All configuration software and associated manuals for the flow computers shall be provided for

installation on a laptop PC. All necessary interface cabling and other hardware required for

configuration shall be supplied.

At least three levels of security coded access shall be provided on the flow computer:

Table 7-5.2 Security Access Levels

• Operator Ability to read programmed data and print reports on demand.

• Technician As per Operator plus ability to manipulate parameters required for routine

maintenance and calibration.

• Engineering As per Technician plus ability to change all constants and system

configuration.

For audit purposes, it shall be possible to verify all flow calculation constants and configuration

parameters whilst the meter is in service.


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7.5.4 Calculations

The following calculated values will be provided by the GC:

• Gas compressibility to AGA-8 (Detail Characterisation Method)

• Gas Lower Heating Value to ISO-6976

• Gas Wobbe Index to ISO-6976

• Gas Density (Operating / Standard / relative), to ISO-6976

• Speed of sound of gas at operating conditions

The CONTRACTOR may elect to perform some of these calculations within the flow computers.

Each flow computer shall calculate the following parameters:


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Table 7-5.3 Flow Computer Calculated Parameters

Units

Instantaneous Totalised

Actual volumetric gas flow rate acfh acf

Standard volumetric gas flow rate MMscfd MMscf

Gas mass flow kg/hr kg

Gas energy flow [M]J/hr [M]J

Refer to the BOD [1] for units.

Full calculation execution shall be achieved every 5 seconds.

7.5.5 Software

Licenses for all proprietary software shall be provided to the COMPANY for the entire life of project.

7.5.6 Reporting

Each flow computer on the Fiscal Gas Metering package shall be configured to produce automatic,

periodic and on-demand reports as required to ensure all system data, alarms and events are

recorded for gas sales, system analysis and troubleshooting purposes. As a minimum, the system

shall be configured to log the following reports to disk, to printer and for interrogation by the PCS as

noted:


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Table 7-5.4 Report Logging

Report Title Report Interval

To D

isk

To P

rinte

r (O

ptio

nal

conn

ectio

n by

oth

ers)

For i

nter

roga

tion

by P

CS

Description

Export Flow Report

Hourly All totalised flow data for the period plus an update of the ongoing station total totalised flows.

Flow weighted average readings for all flow measurement data (pressure, temperature etc) and for all calculated parameters (density, heating value, compressibility etc) for the period.

Gas Quality Analysis

Hourly Flow weighted average readings for all GC analysis data for the period – to be implemented by the GC system.

Daily Export Flow Report

24 Hourly, 6:00am Each Day

Optional All totalised flow data for the period plus an update of the ongoing station total totalised flows.

Flow weighted average readings for all flow measurement data (pressure, temperature etc) and for all calculated parameters (LHV, compressibility etc) for the period.

System Event Log

Continuous On Demand

Time stamped listing of all defined system events including manually entered changes.

System Alarm Log

Continuous On Demand

Time stamped listing of all defined system alarms.

Detailed system reporting features and data shall be developed between the CONTRACTOR and the

COMPANY during the system design.

7.5.7 Data Logging and Storage

All report data shall be stored in non-volatile memory within the flow computer for a minimum of

[TBABC]:

Table 7-5.5 Duration of Data Logging

Report Min Storage Time


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Hourly reports 65 days

Daily reports 130 days

Monthly reports (if applicable) 130 days

Alarm and event reports 35 days

Access to the logged data shall be password protected.

Data shall be capable of being exported into MS Excel format.

7.6 Piping

All piping shall be terminated and anchored at the skid edge for flanged tie-in to ORF’s off-skid piping

and shall be securely supported and not induce excessive loads on equipment within the skid. The

supports shall either be adequate for transportation or alternatively provided with temporary bracing.

All piping connections to ORFs piping including inlet, outlet, utility, and drain lines shall extend to and

be terminated at the edge of the skid. All termination points shall be clearly identified by permanently

fixed, durable labels. Piping terminations and nozzles shall be held to the dimensions shown on the

Project Drawings.

Safety shall be of prime importance during the development of the skid mounted package equipment

and piping layouts. The skid shall be designed as safe as practically possible for the personnel using,

installing, maintaining, and testing the equipment.

7.7 Utilities

7.7.1 Cold Vent

A cold vent [TBABC] shall be provided to safely dispose hydrocarbon to atmosphere under

maintenance or emergency relief. The location and length of the vent shall take into account the

hydrocarbon LEL limits acceptable on the facility in the event of venting and or relief cases and the

resultant heat radiation in the event of inadvertent ignition of vent gases. The Vent Stack shall be

sized for safe venting of pipeline gas, if required due to any Emergency. Vent stack will be self-

supporting type and will be provided with a Knock-Out Vessel and a Sonic Vent. Refer to the BoD

document [1] for additional details.

7.7.2 Instrument Air Compressor and Dryer

As a part of utilities requirements for the ORF, an instrument air system consisting of the following

components shall be installed:

- Fully spared electric motor driven rotary screw compressors

- Fully spared dual air dryer package (heatless type)

- Pre & post filters


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- Instrument air receiver

Refer to BOD [1].

7.7.3 Util ity Water System and Fire Water System

The utility water system and Fire Water System shall be designed to meet the requirements of ORF

as per local applicable Codes and International Codes. Refer to BOD[1]

Fire Pumps for ORF shall be designed, fabricated, inspected and tested in accordance with NFPA 20

and local Jamaican Specifications. Jockey Pumps will keep the fire header pressurised all the time.

Both the fire pumps shall be diesel engine driven. Jockey pumps shall be electric motor driven. Fire

pumps and jockey pumps will be designed as horizontal type pump. Fire Pump Package will be

installed under a shed and shall be designed for outdoor installation. Fire water pumps will use water

from Fire Water Storage Tank.

Equipment sparing requirements shall be determined by the CONTRACTOR subject to Reliability,

Availability and Maintenance (RAM) assessment.

7.7.4 Diesel Generator (as required)

The ORF shall receive 400-V, 50-Hz, 3 Phase electrical power. For back up Power supply Diesel

Generator shall be provided. Refer to the BOD [1] for further details.

7.7.5 Heating, Ventilation and Air- Conditioning (HVAC)

HVAC and pressurization systems shall be provided as required for the control rooms, electrical

substations [TBABC].


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8. REFERENCES

[1] Basis of Design 402010-00260-00-GE-BOD-0001

[2] Pipeline and ORF Operating Philosophy 402010-00260-00-PR-PHL-0001

[3] Request for Quotation, Pipeline and ORF Scope of Work 402010-00260-00-GE-SOW-0005

Attachment 06 - Regas Plant Functional Specification


Jamaica LNG Project Regasification Plant Functional Specification

402010-00260-00-PR-SPC-0001

25th August 2011


JAMAICA LNG PROJECT REGASIFICATION PLANT FUNCTIONAL SPECIFICATION

Page ii

CONTENTS 1. Introduction ........................................................................................................... 4

1.1 Background ......................................................................................................................... 4 1.2 Purpose ............................................................................................................................... 4 1.3 Objective ............................................................................................................................. 4 1.4 Abbreviations ...................................................................................................................... 5 1.5 Definitions ........................................................................................................................... 6

2. DESIGN Basis Information .................................................................................... 7

2.1 Operating Philosophy ......................................................................................................... 7 2.2 Availability ........................................................................................................................... 7 2.3 Design Life .......................................................................................................................... 7 2.4 Design Conditions ............................................................................................................... 7 2.5 Classification, Codes and Regulations ............................................................................... 7 2.6 LNG Regasification and Gas Export ................................................................................... 7 2.7 Typical LNG Composition Data .......................................................................................... 7 2.8 Gas Pressure & Temperature at Delivery Points ................................................................ 7

3. HSE REQUIREMENTS ....................................................................................... 10

3.1 Health and Safety ............................................................................................................. 10 3.2 Environment ...................................................................................................................... 10

3.2.1 Equipment Design Parameters ...................................................................................................... 10 4. LNG CARGO CONTAINMENT AND TRANSFER .............................................. 11

5. REGASIFICATION PLANT ................................................................................. 12

5.1 General Requirements ...................................................................................................... 12 5.2 Process Scheme ............................................................................................................... 12

5.2.1 LNG Feed to Regasification Plant .................................................................................................. 12

5.2.2 LNG Vaporization ........................................................................................................................... 12 5.3 Equipment Pressure and Temperature Rating ................................................................. 12

6. Gas export system .............................................................................................. 14

6.1 Gas Metering .................................................................................................................... 14 6.2 Pig Launcher ..................................................................................................................... 14



Page 3

6.3 Gas Pipeline ...................................................................................................................... 14 6.4 Process Equipment ........................................................................................................... 14

6.4.1 Equipment Pressure and Temperature Rating ............................................................................... 15 7. Flare System ....................................................................................................... 16

7.1 Relief ................................................................................................................................. 16 7.2 Blowdown .......................................................................................................................... 16 7.3 Process Equipment ........................................................................................................... 16

7.3.1 Equipment Pressure Rating ........................................................................................................... 17 8. POWER GENERATION AND ELECTRICAL SYSTEMS .................................... 18

9. UTILITY SYSTEMS ............................................................................................. 19

9.1 Seawater system .............................................................................................................. 19 9.2 Other utilities ..................................................................................................................... 19

10. Construction, Commissioning, trials and Acceptance ......................................... 20

11. References .......................................................................................................... 21



Page 4

1. INTRODUCTION

1.1 Background
















1.2 Purpose

The purpose of this document is to provide a functional specification for the Regasification Plant for

the Jamaica LNG Project.

1.3 Objective

CONTRACTOR shall provide a regasification system in conformance with the functional performance

requirements detailed in this specification. CONTRACTOR shall additionally demonstrate design

compliance with Basis of Design (BoD) [1], Operational Philosophy [3], SRT Scope of Work [4] and

other relevant specification requirements. The regasification system shall be designed to fully

integrate with the SRT, cargo storage and loading, power generation and utility systems, mooring

system, pipeline and ORF and centralized control and instrumentation systems.



Page 5

1.4 Abbreviations




BFD Block Flow Diagram

BoD Basis of Design


CAPEX Capital Expenses

FSRU Floating Storage and Regasification Unit (the hull itself)

FVO First valve On


HP High Pressure

LAT Low Astronomical Tide



LP Low Pressure

LVO Last Valve Off

MMscf Millions Standard cubic feet

MMscfd Millions Standard cubic feet per day

MTPA Millions of Tonne Per Annum

OPEX Operating Expenses



USD US Dollars

WP WorleyParsons



Page 6

1.5 Definitions




COMPANY Government of Jamaica, acting on behalf of the Jamaica Gas Trust

CONTRACTOR SRT BOOT CONTRACTOR








Page 7

2. DESIGN BASIS INFORMATION

2.1 Operating Philosophy

Details of the regasification system operating philosophy are provided in Operating Philosophy

document [3].

2.2 Availability

Regasification system availability requirements are as set out in the BoD document [1].

2.3 Design Life

Regasification system design life will be as detailed in the BoD document [1].


Regasification system design conditions will be as detailed in the BoD document [1].

2.5 Classification, Codes and Regulations

The regasification facilities on the SRT shall be designed and operated in accordance with, but not

limited to, the latest edition including additions and amendments of the API and ASME codes and

regulations listed in the Basis of Design [1].

In case of a discrepancy in the requirements in the codes and standards, the more onerous

requirement shall prevail.

The regasification system shall comply with the above standards and shall be classified with DnV or

an approved equivalent, IACS classifications society.

Refer to the FSRU Functional Specification [2] for further details of applicable codes and standards.

2.6 LNG Regasification and Gas Export

LNG Regasification and gas export rate requirements are as detailed in the BoD document [1].

2.7 Typical LNG Composition Data

Refer to Section 7 of the BoD document [1] for typical LNG supply compositions.

2.8 Gas Pressure & Temperature at Delivery Points

Vaporized LNG shall be delivered to the inlet of the gas export pipeline under pressure and

temperature control.



Page 8

The inlet operating pressure of the gas export pipelines is dictated by the end-user supply pressure

requirements. For details of Gas Pressure and Temperature refer to BoD document [1].


Page 9

Legend:

MeteringGas Heater

BOG Compressor

Booster Compressor Gas

Liquid

In Tank Pumps Suction Vessel

Booster Pumps

LNG Vapourisers

NG Trim Heaters Metering

To Old Harbour Metering

Turbo Generator

Electric Power

L N G C

LNG

Vapour Return

Fuel Gas

Figure 2.1: Block Flow Diagram: Storage, Regasification & Gas Export Systems



Page 10

3. HSE REQUIREMENTS

3.1 Health and Safety

Refer to the FSRU Functional Specification [2] for details of regasification system health and

safety requirements.

3.2 Environment

Environmental, seismic and metocean conditions are set out in the BOD document [1].

3.2.1 Equipment Design Parameters

Floating equipment shall be subject to accelerations and movement due to sea states. Should the

regasification system be situated in a floating location, it shall be design for marine motion

accordingly. The appropriate design parameters are summarized in the BoD [1].



Page 11

4. LNG CARGO CONTAINMENT AND TRANSFER

Refer to the FSRU Functional Specification [2] for LNG cargo containment and transfer details.



Page 12

5. REGASIFICATION PLANT

5.1 General Requirements

The regasification unit and gas export system shall be capable of achieving throughput rates and

turndown in accordance with Section 2.6. The regasification plant design is to be integrated with

the SRT cargo handling, power generation, general auxiliary, piping and control systems. A major

emphasis of the selection and design of the units, in particular the vaporizer system, is to ensure

equipment availability, reliability and tolerance to – in the case of a floating location - marine

motions in both operational and extreme weather conditions.

5.2 Process Scheme

5.2.1 LNG Feed to Regasification Plant

The LNG shall be fed from the Cargo Tanks to the Regasification Plant using pumps in series; the

LNG Cargo Pumps followed by the HP LNG Pumps (also known as the LNG Booster Pumps).

The LNG Cargo pumps provide the required suction head for the HP LNG Pumps. The HP LNG

Pumps shall boost the pressure of the LNG suitable to meet regas export pressure to shore.

Variable speed HP LNG Pumps may be considered to achieve variation in regas pressure. Refer

to Section 2.8 for further details of pipeline inlet pressure delivery requirements.

5.2.2 LNG Vaporization

The selected LNG vaporization technology shall be designed with consideration for marine

motions where appropriate i.e. as dictated by the regasification unit location.

Final equipment requirements shall be confirmed by the CONTRACTOR. Equipment sparing shall

be adequate to ensure compliance with overall SRT system availability requirements as detailed in

the Project BoD [1]. The CONTRACTOR shall complete a detailed RAM study to substantiate the

claimed regasification unit availability.

5.3 Equipment Pressure and Temperature Rating

As the maximum operating gas export pressure is 80 barg inclusive of a margin for future demand

increases, a design pressure of 95 barg shall be considered. All equipment downstream of the HP

LNG Pumps shall therefore be ANSI Class 600 rating.

Equipment Pressure Rating Design Temperature (°C)

LNG Cargo Pumps (per tank) 150# -170/+65



Page 13

Equipment Pressure Rating Design Temperature (°C)

HP LNG Pumps 600# -170/+65

LNG Vaporisers 600# -170/+65

LP Boil off Gas Compressors 600# -170/+65

HP Boil off Gas Compressors 600# -170/+65

Gas-LNG Counter Current Cooler 600# -170/+65

CONTRACTOR to confirm equipment requirements and corresponding design conditions.



Page 14

6. GAS EXPORT SYSTEM

The Jamaica LNG Project will deliver regasified LNG (i.e. NG) from the vaporization trains to two

independent gas export systems supplying end-users at Rocky Point and Old Harbour. It is noted

that provision should be made for a third (future) export system for delivery of NG to the (future)

Port Esquivel ORF and (future) onshore pipeline distribution grid.

The pipeline and regas equipment shall be designed to ANSI Class 600 pressure rating.

Equipment and piping shall be sized for the envisaged system operating pressure of 40 barg.

A single gas export manifold will deliver regasified LNG to the inlet of the export systems.

Each gas export system shall consist of the following:

• Gas metering

• Pig Launcher

• Gas pipeline to shore

Analysis of the export gas, such as composition, calorific value and Wobbe index, shall not be

performed at the SRT.

Odorisation of the gas shall not be required under the current project scope.

6.1 Gas Metering

Gas metering is expected to be of custody-transfer accuracy. Each metering skid shall consist of

two gas meters, one master meter and one service meter. It is envisaged that the gas metering

systems upstream and downstream of the export pipeline (refer to Figure 2.1) shall comprise the

pipeline inventory management and leak detection system.

6.2 Pig Launcher

Each pig launcher shall be provided, either as installed or as allocated space, to enable pigging of

all rigid pipeline components in the export system consistent with pipeline licensing and statutory

requirements. As the export gas is dry and non-corrosive, it is expected that pigging shall only be

required on initial commissioning and afterwards only for intelligent pig surveys as required by the

Regulatory Authority.

6.3 Gas Pipeline

For gas pipeline from SRT to Old Harbour, refer to BoD document [1] and ORF and Pipeline

Functional Specification [3]

6.4 Process Equipment

The following process equipment shall be required as part of each gas export system:



Page 15

Equipment Total required Number operating

Pig Launcher 1 1

Where the design does not lend itself to installation of a permanent pig launcher i.e. in the event of

plot constraints, the CONTRACTOR shall as a minimum provide appropriate tie-ins & fittings to

enable mobilization and connection of temporary pig launching equipment as required.

6.4.1 Equipment Pressure and Temperature Rating

The pipeline, Pig Launcher, connecting piping and fittings, including the LVO, shall be designed

and rated to ANSI Class 600 and shall have a design temperature of -10oC to +65

oC.



Page 16

7. FLARE SYSTEM

A flare system is required to dispose of process vapors and liquids in the event of an emergency

from relief valves and blowdown systems. The flare system shall comply with API STD 521 and

shall be separate from the LNG tank vents (marine systems).

Flare system capacity shall be sufficient for additional relief and blowdown requirements

associated with anticipated future regasification system expansion to accommodate increased NG

supply demands. Refer to Section 2.6 for further details.

Flare tip supply and maintenance provisions shall be considered in the overall system RAM study.

7.1 Relief

The relief contingencies possible at the regasification plant shall depend on the vaporizing

technology employed.

The major relief event is expected to be caused by a blocked discharge on the LNG Vaporizers,

which may be equivalent to the maximum production capacity of the SRT. A vaporizer tube failure

or blocked discharge of the BOG compression system would also be a significant relief event.

7.2 Blowdown

Blowdown and release of gas and liquid to the flare system is not expected to be a common

occurrence. The process is designed to retain all fluids within the equipment under all operating

conditions.

Blowdown is expected to occur mainly due to events external to the process, e.g. fire and gas

alarm, maintenance. Blowdown shall be constrained to hydrocarbon bearing equipment such as

vaporizers, LNG pumps, BOG compression and gas export.

Emergency blowdown shall comply with the requirements of API STD 521 and sent to the flare

system for disposal. Blowdown of liquid sources shall be minimized; blowdown of vapor streams

is preferred.

7.3 Process Equipment

Final equipment requirements shall be confirmed by the CONTRACTOR. Equipment sparing shall

be adequate to ensure compliance with overall SRT system availability requirements as detailed in

the Project BoD [1]. The CONTRACTOR shall complete a detailed RAM study to substantiate the

claimed regasification unit availability.



Page 17

7.3.1 Equipment Pressure Rating

The flare headers, closed drain headers, all associated piping and all flare process equipment

shall be ANSI Class 150.

Relief lines from high pressure equipment shall need to be ANSI Class 600 up to the first isolation

valve. The remainder of these lines can be Class 150.

The flare headers and piping, closed drain headers and piping and all flare process equipment

upstream of the Flare Gas Heaters shall have a design temperature of -170oC to +65

oC. Piping

downstream of the Flare Heaters shall have a design temperature of -10oC to +65

oC.



Page 18

8. POWER GENERATION AND ELECTRICAL SYSTEMS

Refer to the FSRU Functional Specification [2] for power generation and electrical system details.

Emergency Power Generation capacity shall be adequately sized to meet back start after a

cyclone or any other emergency, natural disaster or otherwise.



Page 19

9. UTILITY SYSTEMS

Refer to FSRU Functional Specification [2], in addition:

9.1 Seawater system

The seawater system required for the Regasification Plant shall depend on the LNG vaporization


As a minimum, the SRT shall have a seawater system that supports the LNG loading and storage

facilities. If the regasification Plant uses the IFV technology, additional seawater pumps and

treatment shall be required.

9.2 Other utilities

The following utilities are envisaged but not detailed:

• N2 generators – flare purging, compressor/pump seal purging, marine systems

• HPU unit for actuated valves

• Plant and instrument air systems

• HVAC for non-LQ pressurised spaces

Additional utility requirements shall be defined by the supplier.



Page 20

10. CONSTRUCTION, COMMISSIONING, TRIALS AND ACCEPTANCE

Refer to the FSRU Functional Specification [2].



Page 21

11. REFERENCES

[1] WorleyParsons, “Basis of Design”, 402010-00260-00-GE-BOD-0001

[2] WorleyParsons, “LNG FSRU Functional Specification – Permanently Moored”, 402010-

00260-00-MA-SPC-0002

[3] WorleyParsons, “FSRU Operating Philosophy” 402010-00260-MA-00-PHL-0001,

[4] WorleyParsons, “SRT Scope of Work” 402010-00260-00-GE-SOW-0004

[5] WorleyParsons, ‘Pipeline and ORF Functional Specification” 402010-00260-00-PR-SPC-

0002

Attachment 07 - FSRU Functional Specification

GOVERNMENT OF JAMAICA - OFFICE OF THE CABINET JAMAICA LNG PROJECT JETTY MOORED FSRU FUNCTIONAL SPECIFICATION

Page i

Jamaica LNG Project Jetty Moored FSRU Functional Specification

402010-00260 – 00-MA-SPC-0005

24 August 2011


Page ii

CONTENTS

1. INTRODUCTION ................................................................................................................ 1

1.1 Background ......................................................................................................................... 1

1.2 Purpose ............................................................................................................................... 1

1.3 Objective ............................................................................................................................. 1

1.4 Abbreviations ...................................................................................................................... 2

1.5 Definitions ........................................................................................................................... 3

2. DESIGN BASIS INFORMATION ........................................................................................ 5

2.1 Prohibited Materials/Systems ............................................................................................. 5

2.2 Design and Operations Philosophy .................................................................................... 5

2.3 Availability ........................................................................................................................... 7

2.4 Design Life .......................................................................................................................... 7

2.5 Design Conditions ............................................................................................................... 7

2.6 Classification, Codes and Standards .................................................................................. 7

2.6.1 Classification Requirements .................................................................................. 7

2.6.2 Codes and Regulations .......................................................................................... 7

2.7 Near-shore Facilities Location ............................................................................................ 7

2.8 Health and Safety ............................................................................................................... 7

2.9 Metocean Data .................................................................................................................... 8

2.10 Geophysical and Geotechnical Data .............................................................................. 9

2.11 Overpressure Protection ................................................................................................ 9

2.12 Cargo Handling Criteria .................................................................................................. 9

2.13 LNG Storage Tanks ........................................................................................................ 9

2.14 LNG Loading .................................................................................................................. 9

2.15 Gas Pressure & Temperature at Delivery Point ........................................................... 10

2.16 Boil Off Gas Return ...................................................................................................... 10

2.17 LNG Cargo Transfer System ........................................................................................ 11

2.18 Vapor Return to Cargo Tanks ...................................................................................... 11

2.19 Environment ................................................................................................................. 11


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2.20 Trim .............................................................................................................................. 11

2.21 Design Loads and Motions ........................................................................................... 11

2.22 Black Start .................................................................................................................... 12

3. DETAILED ENGINEERING .............................................................................................. 13

3.1 Motion Analysis ................................................................................................................. 13

3.2 Waterway Suitability Assessment ..................................................................................... 13

3.3 Availability Analysis Methodology ..................................................................................... 14

3.4 Hurricane Plan .................................................................................................................. 14

3.5 Fatigue Analysis ................................................................................................................ 14

3.6 Noise and Vibration Analysis ............................................................................................ 15

3.7 Sloshing Analysis .............................................................................................................. 16

3.8 Electrical System Analysis ................................................................................................ 16

3.9 Structural Analysis ............................................................................................................ 17

4. DESIGNATED VESSEL REFURBISHMENT REQUIREMENTS ..................................... 18

4.1 Overview ........................................................................................................................... 18

4.2 Delivery of Designated Vessel .......................................................................................... 19

4.3 General Shipyard Considerations ..................................................................................... 19

4.4 Refurbishment ................................................................................................................... 20

4.4.1 General ................................................................................................................ 20

4.4.2 Inspection and Repair Plan .................................................................................. 20

4.4.3 Systems Operational Trials .................................................................................. 21

4.4.4 Structural Repairs ................................................................................................ 21

4.5 Steel Renewal Requirement ............................................................................................. 21

4.6 Renewal of Steel below the Renewal Thickness .............................................................. 22

4.7 Addition or Modifications to Gussets and Brackets .......................................................... 23

4.8 Machinery and Equipment Repairs ................................................................................... 23

4.9 Pumps ............................................................................................................................... 24

4.10 Electric Motors .............................................................................................................. 24

4.11 Fans and Blowers ......................................................................................................... 24

4.12 Diesel Engines ............................................................................................................. 24


Page iv

4.13 Inert Gas Equipment .................................................................................................... 24

4.14 Boilers ........................................................................................................................... 25

4.15 Steam Turbines ............................................................................................................ 25

4.16 Distilling Plant ............................................................................................................... 25

4.17 Heat Exchangers .......................................................................................................... 26

4.18 Electrical Switchboards, MCCs and Distribution Boards ............................................. 26

4.19 Instrumentation, Controls and Consoles ...................................................................... 26

4.20 Deck Cranes ................................................................................................................. 26

4.21 Other Equipment and Machinery ................................................................................. 27

4.22 Classification Surveys .................................................................................................. 27

4.23 Electrical System Inspections and Refurbishment ....................................................... 27

4.24 Main Propulsion, Steering Gear and Rudder ............................................................... 27

4.25 Piping Repairs .............................................................................................................. 28

4.26 Electrical Repairs ......................................................................................................... 28

4.27 Coating Repairs ............................................................................................................ 29

4.28 Insulation ...................................................................................................................... 29

5. CONVERSION ENGINEERING DESIGN REQUIREMENTS .......................................... 30

5.1 General ............................................................................................................................. 30

5.2 Hull .................................................................................................................................... 30

5.2.1 Hull Side Strengthening ....................................................................................... 30

5.2.2 Bulkheads ............................................................................................................ 31

5.3 Cathodic Protection .......................................................................................................... 31

5.3.1 Underwater Hull ................................................................................................... 31

5.3.2 Ballast Tanks ........................................................................................................ 31

5.3.3 Sea Chests ........................................................................................................... 31

5.4 Structural Considerations ................................................................................................. 32

5.4.1 Structural Materials .............................................................................................. 32

5.4.2 Welding Details .................................................................................................... 32

5.4.3 Weld Repairs and Assembly Defects .................................................................. 32

5.5 Forming ............................................................................................................................. 33


Page v

5.6 Structural Units ................................................................................................................. 33

5.7 Temporary Attachments ................................................................................................... 33

5.8 Alignment .......................................................................................................................... 33

5.9 Modifications to Existing Structure .................................................................................... 34

5.10 New Foundations ......................................................................................................... 34

5.11 Piping Materials ............................................................................................................ 34

5.12 Welding Details ............................................................................................................ 35

5.13 Weld Repairs and Assembly Defects ........................................................................... 35

5.14 Piping System Valves ................................................................................................... 35

5.15 Piping System Instrumentation .................................................................................... 36

5.16 Filter and Strainer Arrangement ................................................................................... 36

5.17 Pump Arrangements .................................................................................................... 37

5.18 Pipe Supports ............................................................................................................... 37

5.19 Deck and Bulkhead Penetrations ................................................................................. 37

5.20 Pipe Expansion and Movement ................................................................................... 37

5.21 Vents and Drains .......................................................................................................... 37

5.22 Bonding and Grounding ............................................................................................... 38

5.23 Flow Velocity Limits ...................................................................................................... 38

5.24 Piping Modifications ..................................................................................................... 38

5.25 Electrical Requirements ............................................................................................... 38

5.25.1 Cable Types ......................................................................................................... 38

5.25.2 Cable Glands and Multi-Cable Transits ............................................................... 39

5.25.3 Junction Boxes ..................................................................................................... 39

5.25.4 Fuses ................................................................................................................... 40

5.25.5 Local Motor Control Boxes ................................................................................... 40

5.25.6 Motors .................................................................................................................. 40

5.25.7 Light Fittings ......................................................................................................... 40

5.25.8 Cable Routing ...................................................................................................... 41

5.25.9 Cable Supports .................................................................................................... 41

5.25.10 Cable Protection .................................................................................................. 41


Page vi

5.25.11 Cable Terminations .............................................................................................. 41

5.25.12 Cable Deck and Bulkhead Penetrations .............................................................. 42

5.25.13 Joining of Cables ................................................................................................. 42

5.25.14 Conduits ............................................................................................................... 42

5.25.15 Panel Mounting .................................................................................................... 42

5.25.16 Grounding ............................................................................................................ 42

5.25.17 Hazardous Area Considerations .......................................................................... 43

5.25.18 Electrical Modifications ........................................................................................ 43

5.26 Modifications to Existing Equipment ............................................................................ 44

5.27 Installation of New Equipment ...................................................................................... 44

5.28 Coatings ....................................................................................................................... 45

5.29 Typical Non-Destructive Examination Requirements ................................................... 45

5.30 New and Repaired Piping Systems .............................................................................. 46

5.31 Tank Dome Expansion Bellows ................................................................................... 46

5.32 LNG Cargo Transfer System ........................................................................................ 46

5.33 Spill Protection ............................................................................................................. 47

5.34 Marine & Utility Systems .............................................................................................. 48

5.34.1 Mooring Winches and Equipment ........................................................................ 48

5.34.2 Mooring Line Modification .................................................................................... 48

5.35 Power Generation and Electrical Systems ................................................................... 48

5.36 Accommodation & Personnel Equipment ..................................................................... 48

5.37 Noise and Vibration Levels........................................................................................... 49

5.38 HVAC Equipment ......................................................................................................... 50

5.39 Fire Fighting ................................................................................................................. 51

6. FSRU COMPONENTS ..................................................................................................... 52

6.1 Regasification Plant .......................................................................................................... 52

6.2 Flare System ..................................................................................................................... 52

7. MOORING SYSTEM......................................................................................................... 53

7.1 Jetty Mooring .................................................................................................................... 53

7.2 Temporary Mooring........................................................................................................... 53


Page vii

7.3 Functional Requirements .................................................................................................. 53

7.3.1 Mooring Equipment .............................................................................................. 53

7.3.2 Mooring Lines....................................................................................................... 54

7.3.3 Rope Reeler ......................................................................................................... 54

8. TESTING, PRE-COMMISSIONING AND COMMISSIONING IN SHIPYARD .................. 55

8.1 General ............................................................................................................................. 55

8.2 Testing and Pre-Commissioning ....................................................................................... 55

8.3 Commissioning ................................................................................................................. 56

8.4 Deadweight Survey/Stability Book .................................................................................... 57

8.5 Tank Hydrotests ................................................................................................................ 57

8.6 Tank Cool Down ............................................................................................................... 57

9. CLASSIFICATION AND CERTIFICATION REQUIREMENTS ......................................... 59

9.1 Certifying Authorities ......................................................................................................... 59

9.2 Completion of Current Special Survey.............................................................................. 59

9.3 Certification Requirements ............................................................................................... 59

10. PROVISIONAL ACCEPTANCE ........................................................................................ 61

11. FSRU TRANSIT TO JETTY MOORING ........................................................................... 62

11.1 General ......................................................................................................................... 62

11.2 Preparation for Voyage ................................................................................................ 62

11.3 Transit Voyage ............................................................................................................. 64

11.4 Arrival at Worksite ........................................................................................................ 64

12. NEAR-SHORE COMMISSIONING ................................................................................... 65

12.1 General ......................................................................................................................... 65

12.2 Mooring System Commissioning .................................................................................. 65

12.3 Installation Pressure Test ............................................................................................. 65

12.4 Testing and Set-up of FSRU Interfaces ....................................................................... 65

12.5 Testing and Set-up of Communications ....................................................................... 65

12.6 Testing of Marine Systems ........................................................................................... 65

13. MECHANICAL COMPLETION ......................................................................................... 67

14. ACCEPTANCE ................................................................................................................. 68


Page viii

14.1 Final Offshore Commissioning ..................................................................................... 68

14.2 Trials ............................................................................................................................. 68

15. AS-BUILT INFORMATION ............................................................................................... 70

16. NEW BUILD ENGINEERING DESIGN REQUIREMENTS ............................................... 71

16.1 General ......................................................................................................................... 71

16.2 Hull ............................................................................................................................... 71

16.2.1 Hull Design ........................................................................................................... 71

16.2.2 Bow & Stern Design ............................................................................................. 71

16.2.3 Hull Materials ....................................................................................................... 71

16.2.4 Surface Preparations, Coatings and Material Protection ..................................... 72

16.2.5 Miscellaneous Hull Work ...................................................................................... 72

16.2.6 Sea Chests ........................................................................................................... 72

16.2.7 Markings ............................................................................................................... 73

16.3 LNG Storage Tanks ...................................................................................................... 73

16.3.1 Moss Sphere ........................................................................................................ 73

16.3.2 SPB ...................................................................................................................... 75

16.3.3 Membrane Tanks ................................................................................................. 76

16.4 LNG Cargo Containment and Transfer ........................................................................ 77

16.4.1 General ................................................................................................................ 77

16.4.2 Boil Off Gas Return .............................................................................................. 77

16.4.3 LNG Cargo Transfer System ............................................................................... 77

16.5 Power Generation and Electrical Systems ................................................................... 77

16.5.1 General Power Generation Equipment ................................................................ 77

16.5.2 Fuel System ......................................................................................................... 78

16.5.3 Electrical Equipment Summary & Performance ................................................... 78

16.6 Marine & Utility Systems .............................................................................................. 79

16.6.1 Ballast System ..................................................................................................... 79

16.6.2 Fire Pumps ........................................................................................................... 80

16.6.3 Deck Wash Down System ................................................................................... 80

16.6.4 Seawater Systems ............................................................................................... 80


Page ix

16.6.5 Fresh Water Systems .......................................................................................... 80

16.6.6 Compressed Air Systems .................................................................................... 81

16.6.7 Inert Gas & Nitrogen Generators ......................................................................... 81

16.6.8 Automation Systems for Machinery ..................................................................... 81

16.6.9 Lubricating Oil System ......................................................................................... 81

16.6.10 Fuel Oil System .................................................................................................... 82

16.6.11 Laboratory ............................................................................................................ 82

16.6.12 Marine Growth Suppression Systems ................................................................. 83

16.6.13 Anchoring Equipment ........................................................................................... 83

16.6.14 Lifting Equipment ................................................................................................. 83

16.6.15 Mooring Equipment .............................................................................................. 84

16.6.16 Maintenance Areas .............................................................................................. 84

16.6.17 Garbage Disposal & Sewage Treatment ............................................................. 84

16.6.18 Produced Water, Bilge & Slops, Storage & Treatment ........................................ 85

16.6.19 Surface Preparations, Coatings and Material Protection ..................................... 85

16.6.20 Piping and Equipment Insulation ......................................................................... 86

16.7 Control, ESD, Navigation & Communications .............................................................. 86

16.7.1 General Description of Control System ............................................................... 86

16.7.2 Control System Components ............................................................................... 86

16.7.3 Control System Reliability .................................................................................... 87

16.7.4 Safety Instrumented System ................................................................................ 87

16.7.5 Fire & Gas System ............................................................................................... 88

16.7.6 Distributed Control System .................................................................................. 88

16.7.7 Navigation and Searching Equipment ................................................................. 89

16.7.8 Communication Equipment .................................................................................. 90

16.7.9 Closed Circuit Television (CCTV) ........................................................................ 90

16.8 Accommodation & Personnel Equipment ..................................................................... 91

16.8.1 Performance and Functional Requirements ........................................................ 91

16.8.2 Accommodation Configuration ............................................................................. 91

16.8.3 Accommodation Block & Temporary Safe Refuge Design Requirements .......... 92


Page x

16.8.4 Utilities & HVAC ................................................................................................... 93

16.8.5 Lifesaving Equipment ........................................................................................... 93

16.8.6 Medical Facilities and Equipment ........................................................................ 94

16.9 Fire Fighting ................................................................................................................. 94

16.9.1 Loose Fire Fighting Equipment, Firemen‘s Outfit ................................................ 94

16.9.2 Secondary Temporary Safe Refuge .................................................................... 94

16.10 Seawater System ......................................................................................................... 95

16.11 Other Utilities ................................................................................................................ 95

16.12 Main Propulsion System ............................................................................................... 95

17. REFERENCES ................................................................................................................. 96

Appendices

APPENDIX 1 - DESIGN PREMISE

APPENDIX 2 - COATINGS FOR STRUCTURES, PIPING AND EQUIPMENT

APPENDIX 3 - PIPING AND EQUIPMENT INSULATION

TO BE ADVISED BY CONTRACTOR

[TBABC 001] RAM analysis .................................................................................................................... 7

[TBABC 002] Location of near-shore facilities ........................................................................................ 7

[TBABC 003] Availability/uptime methodology ...................................................................................... 14

[TBABC 004] Hurricane plan ................................................................................................................. 14

[TBABC 005] Noise level measurement plan ........................................................................................ 16

[TBABC 006] Sloshing analysis ............................................................................................................ 16

[TBABC 007] Draft contract and commercial documents ..................................................................... 18

[TBABC 008] Commissioning plan ........................................................................................................ 59

[TBABC 009] Survey plan ..................................................................................................................... 60


Page 1

1. INTRODUCTION

1.1 Background



supply. The strategy aims at introducing imported natural gas into Jamaica‘s energy supply mix to











Regasification Terminal (SRT) and natural gas export system in Jamaica (‗the PROJECT‘) on a Build-


1.2 Purpose

The purpose of this document is to provide a functional specification for the Jamaican LNG FSRU.

1.3 Objective

CONTRACTOR shall provide a FSRU as specified in this functional performance specification. This

document requires that CONTRACTOR demonstrates the functional performance as described in this

functional performance specification and in the operational philosophy document. CONTRACTOR is

also required to demonstrate the system performance in accordance with criteria established in the

basis of design [1], the operational philosophy [4] and the regasification functional specification [2]

document i.e. the FSRU shall be designed to fully integrate the:

a) Regasification system as described in the functional regasification plant specification [2];

b) Jetty mooring system and associated shipboard equipment;

c) The FSRU shall integrate with the jetty and pipeline to shore and the shore based ORF (it is

CONTRACTOR‘s responsibility that the interfaces are managed and integrated into the design

and construction activities);

d) The FSRU shall meet the minimum criteria and code and standards as set out in the Design

Premise document, Appendix 1 - Design Premise;

e) The FSRU shall meet the operational functionality that is described in the FSRU Operating

Philosophy [4] and further in the sections below;


Page 2

f) CONTRACTOR shall apply good offshore oil & gas industry and shipbuilding industry practice

when undertaking the design, construction, commissioning and installation of the FSRU; and

g) The FSRU shall be able to be operated as IMO, class and flag state compliant seagoing ship

that can disconnect from the jetty prior to adverse weather conditions.

1.4 Abbreviations




1oo2D One (1) Out Of Two (2), Diagnostics

AAVs Ambient Air Vaporisers

ABS American Bureau of Shipping

AFD Approved for Design

ANSI American National Standards Institute


ASME American Society for Mechanical Engineers

BOD Basis of Design



EPCI Engineering, Procurement, Construction and Installation

ESD Emergency Shut Down



HMI Human Machine Interface

HPU Hydraulic Power Unit

IDs Identifications

IFVs Intermediate Fluid Vaporiser



Page 3




mmscf Millions Standard cubic feet

mmscfd Millions Standard cubic feet per day

NDE Non Destructive Examination

NDT Non Destructive Testing


PQR Procedure Qualification Record

PRS Pressure Reducing Station

RT Radiography Testing



TBC To Be Confirmed

UPS Uninterruptible power Supply

WP WorleyParsons

WPS Welding Procedure Specification

1.5 Definitions








Page 4

The words ―will‖, ―may‖, ―should‖, ―shall‖ and ―must‖ have specific meaning as follows:-

―Will‖ is used normally in connection with an action by the COMPANY rather than by CONTRACTOR.

―May‖ is used where alternatives are equally acceptable.

―Should‖ is used where a provision is preferred.

―Shall‖ is used where a provision is mandatory.


Page 5


2.1 Prohibited Materials/Systems

The following materials/systems shall not be used in the FSRU:

a) Halon-based fire-fighting systems;

b) CFC-based refrigeration systems;

c) Asbestos, or asbestos-based materials;

d) Type 304 stainless steel;

e) Cadmium-based materials;

f) Coal tar epoxy or anti-fouling paints containing TBT; and

g) The extent of high tensile steel shall be minimises as far as practicable.

2.2 Design and Operations Philosophy

The FSRU is based upon a ship shaped hull moored to a concrete jetty hard berth. The FSRU shall

be able to receive and send out LNG simultaneously to provide a constant flow LNG to the

regasfication facility.

This specification covers two possible LNG FSRU options, these are:

a) Conversion of an existing moss sphere or membrane LNG Carrier or readily available FSRU,

capable of storing 125,000-m³ to 180,000-m³ with a working capacity of 98.5% of the gross

storage capacity; the exact size will depend on the solution provided by the CONTRACTOR.

Design solutions that provide storage of greater than 150,000-m³ of LNG will be considered

favourably. For membrane storage tank, refer to section 16.3.

i) If this option is considered the requirements in sections 2 to 15 are to be applied. This

option shall require that CONTRACTOR conduct a detailed inspection and/or survey of

the designated vessel. Equipment retainable for use is to be refurbished by

CONTRACTOR as detailed in section 4.

ii) CONTRACTOR shall document any shortfall between the existing/retained equipment,

sections 5 and 5.39, and the relevant equipment that is specified in the new built FSRU

option specifications provided in sections in 16. CONTRACTOR shall submit the

resultant documentation to COMPANY for review and approval.


Page 6

b) New build FSRU based on a moss sphere design or SPB tank with total required storage

volume of 180,000-m³ (1)

.

i) If this option is considered the requirements in section 16 are to be applied, in addition to

the requirements stipulated in sections 2 to 15.

The FSRU as covered in this scope of work includes the following main design features:

a) Design life as specified in the BOD, without dry docking.

b) The FSRU is to have the ability to disconnect from its berth and travel under its own power

when required to do so.

c) LNG Storage on board the FSRU with a target storage capacity of 180,000-m³, in IMO type B

tanks.

d) Mooring system to be fully compatible with the jetty mooring system given in [1] including

provision of associated systems and fairleads and chocks to suit quick release hooks with a

minimum 180-tonne rating.

e) Accommodation shall be located at the stern of the vessel. A main machinery space with

power generation shall be provided below the accommodation unit.

f) The unit shall be designed and equipped for loading LNG and offloading NG via standard jetty

based loading arms as described in [1].

g) The regasification plant and associated piping, control and safety systems is located towards

the bow of the FSRU.

h) Hull shell side strengthening to withstand the operational loads from fenders.

i) Offshore rated, heavy-duty deck crane(s) for equipment maintenance, loads and materials

manipulation.

j) Combustion-type inert gas system and membrane nitrogen generation & storage system.

k) LNG regasification plant, to allow performance of all operations required by the Technical

Specification.

l) Redundant cargo fiscal custody control transfer system, based on cargo tank level measuring

(radar ullage).

m) Accommodation for operations and maintenance staff, COMPANY‘s personnel and visitors.

n) Safety, environmental and lifesaving systems, including totally enclosed lifeboat sized in

accordance with the applicable regulations for the total design complement of personnel on

board the FSRU.

o) Potable water generation capabilities to ensure ample water supply to cover personnel,

catering and industrial needs with hundred percent redundant generation capacity.

1 180,000-m³ at 97.5% tank filling level


Page 7

p) Integrated emergency shutdown system.

q) Independent electrical power supply with integrated power management system.

r) Backup and emergency electric power to maintain essential work, safety systems, cargo tank

pressure maintenance and cargo offloading operations during imported power interruptions.

s) Vessel operations control and vessel communications system.

t) Rolling motion reduction mechanisms in the form of continuous bilge keels.

u) Safety Assessment Analysis.

v) RAM Analysis to confirm availability [TBABC 001].

2.3 Availability

SRT availability requirements are as set out in the BOD document [1].

2.4 Design Life

SRT design life is set out in the BOD document [1]. The FSRU shall be moored at site without dry-

docking and subject only to in-water surveys.


SRT design conditions are detailed in the BOD document [1].

2.6 Classification, Codes and Standards

2.6.1 Classification Requirements

The FSRU shall comply with API standards and classified with DNV or an approved equivalent IACS

classifications society. Details are included in the BOD [1] and section 9.

2.6.2 Codes and Regulations

The FSRU is to be built in accordance with, the codes and regulations mentioned in the BOD [1] and

Appendix 1 - Design Premise.

2.7 Near-shore Facilities Location

[TBABC 002]


Safety shall be of primary importance in the design of all systems associated with the FSRU.


Page 8

The rapid detection of any release of LNG gas or liquids, or other hazardous chemicals on the

installation is vital, as is the rapid detection and extinguishment or containment of any resultant

fire/explosion by either active or passive means in order to minimise the escalation potential.

A Safety Instrumented System (SIS) shall be implemented to provide a comprehensive coverage

which shall monitor all potential hazards within the facility, and automatically initiate appropriate

shutdown and containment measures. A comprehensive fire and gas detection system shall form

part of the SIS. The exposure of personnel in the gas processing areas of the facility shall be

minimised by the use of automated control and monitoring technology and CCTV coverage.

An LNG spillage protection system shall be implemented to protect low temperature embrittlement of

topside and ship structures resulting from accidental LNG liquid leaks. The system design shall be in

accordance with all DNV requirements and based on outcomes of studies that shall be required to

determine the maximum volume of LNG discharge during individual single accidental leaks.

Diverse means of escape shall be provided. The facility shall be provided with a temporary safe

refuge and alternative muster/refuge areas as considered necessary, following a safety assessment

in accordance with COMPANY requirements. The philosophy to be adopted for evacuating the facility


facility unsafe.

2.9 Metocean Data

Detailed metocean data is to be prepared by CONTRACTOR. Indicative metocean details are

contained in the BOD [1].

CONTRACTOR shall use a reputable metocean data company to obtain detailed metocean data for

the FSRU location, CONTRACTOR shall obtain as a minimum the following data:

a) Windsea and swell hind cast data for the FSRU location

b) Cross correlation between windsea and swell and the persistence of these

c) Annual wind, wave (windsea and swell) and current distribution

d) 1-year return condition, wind, wave and current

e) 10-year return condition, wind, wave and current

f) 100-year return condition, wind, wave and current

g) Hs vs. Tp

h) Hs vs. Direction

i) Wind vs. Direction

j) Current vs. Direction

k) Cross correlation between the wind and seas and the persistence of these

l) Cross correlation between the current and seas and the persistence of these

m) Squall Winds.


Page 9

The data shall be of sufficient detail to allow fatigue assessment and the mooring and offloading

availability analysis.

2.10 Geophysical and Geotechnical Data

Only preliminary geophysical geotechnical data is currently available for the proposed site locations.

Refer to the BOD [1] for details.




instrument malfunction or fire:

a) All design shall be in accordance with the latest editions of API RP 520 and 521;

b) Process vent gases shall be disposed of via the on-board flare system.

2.12 Cargo Handling Criteria

Cargo handling criteria is outlined in the Design Premise, Appendix 1 - Design Premise and sections

2.13 to 2.18 below.

All LNG operations shall follow guidelines and procedures as given in SIGTTO LNG Operational

Practice [6].

LNG gas trails shall be performed in accordance with SIGTTO ―Guide for Planning Gas Trials for LNG

Vessels‖ [7].

2.13 LNG Storage Tanks

A minimum of 50,000-m³ buffer storage should be built into the FSRU to ensure uninterrupted gas

supply. LNG storage tanks shall be preferable: Moss spherical tanks or SPB tanks. Alternatively

membrane tanks of GTT No. 96 type super reinforced type also see limitations of membrane tank use

in section 16.3.3.

2.14 LNG Loading

The SRT is to be capable of accepting LNG from LNG carriers (LNGC) ranging in size from 125,000-

m³ to 180,000-m³. A one day turn around is assumed for LNG loading, hence the system must be

designed to load at a rate of 10,000-m³/hr.

The FSRU shall be capable of receiving 100% load of 157,000-m³ at one continuous offloading

operation.

The manifold system shall allow for loading of all cargo tanks individually but also simultaneously from

any LNG loading arm. This shall be facilitated by valves and should not require removing of spool

peaces. Each loading arm shall be able to be disconnected individually without compromising the

ability to load LNG.


Page 10

a) The LNGC manifold shall accommodate a double blocked valve system to allow for the Liquid

Header to Vapour Header, Liquid Header to HD Compressor to be isolated and loading arms to

be isolated. Without the need to remove spool pieces.

b) Integration of surge drum.

The manifold system shall be configured to allow all vessel operations to take place if one tank is

taken out of service, and or one tank is in the process of being warmed-up or cooled down.

The manifold shall allow for a recirculation of LNG and NG to maintain individual systems at cryogenic

temperatures at all times.

Interface with the shipping contractor/team during the design phase is necessary to confirm the

manifold connection sizes.

OCIMF also recommend the manifold arrangement as:

L – L – V – H

L = Liquid, V = Vapour, H = Hybrid (both Liquid and Vapour)

Note: Final manifold arrangement to be specified by CONTRACTOR during detailed design, in-line

with CONTRACTOR's specification for loading arms.

A further consideration of the system is maintaining cold temperatures during holding mode. During

holding mode, heat leak into the loading lines would generate vapour which could lead to over-

pressure/thermal relief or at worst stratification and hence bowing in the lines. To avoid this (or time

consuming repeated emptying of the lines between loading operations) a vapour management

system shall be installed.

The system shall provide for a single loading and dual loading line capability. Therefore, an

additional, smaller recirculation header is required to enable LNG circulation for the single loading

line. In a dual loading line system circulation is to be carried out down one header and returned in the

other, removing the need for an additional line.

The system shall be operated in general to maintain the hybrid arm as spare.

Hydraulic surge shall be considered for the LNG loading system. The system shall therefore provide

a surge drum to protect against excessive surge pressure. CONTRACTOR is to perform a detailed

transient analysis.

2.15 Gas Pressure & Temperature at Delivery Point

The pipeline inlet temperature and pressures are given in the BOD [1].

2.16 Boil Off Gas Return

Boil-off gas (BOG) from the storage tanks shall be sent to the LP BOG compressor located in the

process plant area. The boil off gas shall be used for fuel gas, re-injected into the LNG at the suction

of the HP LNG Pumps or sent out as product delivery into the pipeline.


Page 11

Return of boil off gas to the LNGC during loading cannot be guaranteed and hence the FSRU boil-off

gas compression system needs to accommodate the total vapour displacement capacity. However,

consideration needs to be given to the re-vapourisation capacity of the LNGC which may dictate a

longer load-out under these conditions. Hence, the use of the FSRU duty and stand-by compressor

operating simultaneously under these conditions may be deemed acceptable.

HP boil off gas compressor system shall be included to facilitate injection of boil-off gas to

regasification line for send out.

2.17 LNG Cargo Transfer System

The cargo pump system shall deliver LNG to the regasification plant. The cargo pumps shall feed the

HP LNG pumps, located in the regasification plant area. Each cargo pump system shall consist of

vertical, centrifugal, submersible cryogenic pumps capable of delivering LNG to supply the peak the

sales gas rate.

2.18 Vapor Return to Cargo Tanks

A vapour return line from upstream of the gas metering skid back to the cargo tanks shall be

incorporated. This line can be used as a vapour make-up for the cargo tanks in the event of

insufficient boil-off gas as well as to purge and cool the cargo tanks in preparation for loading LNG

after tank inspections.

The warm gas from metering shall be cooled to a maximum of -130°C for vapour balancing and

purging. This is achieved in part by throttling the pressure of the gas (Joule-Thomson cooling effect)

from pipeline pressure to tank pressure and partly by counter-current cooling in an exchanger with

cold LNG from the cargo tanks.

2.19 Environment

Environmental, seismic and metocean conditions are set out in the BOD [1].

2.20 Trim

It is expected that the FSRU shall be operated on even trim or trimmed. Operational trim shall be not

more than 3° and maximum trim excursion shall be limited to 5-m. CONTRACTOR shall consider the

trim conditions in all two-phase system to ensure that liquids do not collect in headers and that vapour

locks do not occur.

2.21 Design Loads and Motions

The FSRU equipment, equipment foundations and sea fastenings are to withstand the minimum peak

accelerations along the length of the FSRU as described included in the BOD [1] or developed from

numerical analysis or model testing, as described in section 3.1.


Page 12

2.22 Black Start

Emergency power generation shall be sized to meet black start which may happen after a cyclone or

any such eventuality causing whole SRT shut down.


Page 13

3. DETAILED ENGINEERING

3.1 Motion Analysis

Motion responses of the FSRU during the operation and sailing phases shall be analyzed using a 3D

diffraction theory.

FSRU motions shall be analyzed to confirm the adequacy of the FSRU design connected to the

mooring system to perform safely and efficiently offloading operations of LNG and to survive extreme

design environment condition. Analysis based on the proposed vessel hull form shall be conducted to

determine the following:


b) Mooring system performance in survival and various operating and fatigue design conditions;

c) Loads on the mooring lines;

d) Loads on mooring system equipment;

e) Rolling reduction requirements; and

f) Operating limits for mooring and offloading operations (including permissible excursion

envelopes of the loading arms).

3.2 Waterway Suitability Assessment

CONTRACTOR shall conduct Waterway Suitability Assessment (WSA) in accordance with the

navigation and vessel inspection circular NVIC 05-05.

When conducting a WSA of FSRU, the assessment shall include;

a) LNGC type,

b) The FSRU location,

c) The navigational path, and

d) The nearest neighbors along the navigational path and at the terminal.

There are four classes of attributes that affect overall risks. These attributes are:

a) The context of the FSRU – location, site specific conditions;

b) Potential targets and threats – potential accidental events, credible intentional events, and ship

or infrastructure targets;

c) Risk management goals – identification of levels of consequences to be avoided, such as

injuries and property damage, LNG supply reliability required; and

d) Protection system capabilities – Safety and security measures, early warning, and emergency

response/recovery measures.


Page 14

These attributes must be evaluated to determine if the protection systems in place can effectively

meet the risk management goals identified for a specific terminal. If the initial risk assessment

determines that the identified risk management goals are not met, then potential modifications in

location and site conditions, import operations, safety and security measures, or hazardous marine

export operations, are to be reviewed to assess the ability to meet the objectives. Changes in factors

including the context of the FSRU, threats or threat-levels, risk management goals, or risk

management and safety systems could impact the basis for the original evaluation, making a

reassessment of the risks necessary.

3.3 Availability Analysis Methodology

CONTRACTOR shall prepare a detailed methodology statement describing the procedures to

undertake the availability and uptime analysis [TBABC 003]

3.4 Hurricane Plan

CONTRACTOR shall prepare a detailed hurricane plan [TBABC 004]. Such plan shall include

consideration of the following general factors [8]:

a) Vessel characteristics;

b) Berth and anchorage conditions;

c) Most recent tropical cyclone warning advisory;

d) Tropical cyclone climatology; and

e) Surge Characteristics.

In all cases, the timing of the evasion is affected by [8]:

a) The time required making preparations to get underway;

b) The time required reaching open water and gaining sea room;

c) The forward speed of the tropical cyclone; and

d) The radius of hazardous winds and seas that can adversely impact a vessel's ability to reach

open water.

3.5 Fatigue Analysis

DNV Spectral Fatigue Analysis CSA-FLS or IACS Classification Society equivalent shall be provided

for critical details with high stress concentration. Special attention shall be given to the interface

structure with the mooting system, as well as the cargo tank and its support structure. The fatigue

analysis shall be carried out for three loading conditions:

a) Full load condition (at deepest draft condition);

b) Normal ballast condition (at lightest draft condition); and

c) An intermediate loading condition.


Page 15

Note: Conditions a) and b) with a weighted factor of 0.25 and c) with one of 0.5.

In addition to environmentally induced loads, the fatigue analysis shall take into account low cycle

effects due to loading and unloading during the service life, as appropriate. The calculation of

cumulative fatigue damage shall include fatigue damages resulting from tow and from in-service

conditions. The fatigue damage due to the tow cyclic loading shall be based on actual tow route,

season and ballast condition, and shall take into account a towing speed of 8-knots.

The stress levels of the primary members and the supporting reaction forces shall be calculated by

FEM analysis using a 3D global model of the entire FSRU and local FE models of local and support

structural details. The input, modeling techniques and results of FEM analyses shall be submitted for

Classification Society review and approval.

The following loads shall be applied to a global finite element model:

a) Inertia loads of vessel structure and cargo;

b) Hydrodynamic pressure including change of hydrostatic pressure due to ship motion; and

c) Mooring system loads.

3.6 Noise and Vibration Analysis

CONTRACTOR shall undertake noise and vibration analysis as part of the detailed design. The

objective of this study shall be to demonstrate that the noise levels throughout all potentially manned

areas of the installation conform to the specified limits for personnel exposure. Suitable mitigation

measures shall be put in place where this is not achievable.

The selected candidate vessel shall be subjected to a vibration assessment of the existing design and

where necessary modifications shall be made to ensure vibration is limited to the levels that shall:

a) Not result in discomfort or annoyance to the crew;

b) Not damage or cause malfunction of the machinery, equipment and facilities onboard at any

operating conditions and during the course of the Contract.

As a minimum, vibrations onboard the FSRU shall be kept below the levels specified in ISO 6954

(1984). CONTRACTOR and Engineering Subcontractor shall follow ISO 4867/4868 and "Guidance

Notes on Acceptable Vibration Levels and Their Measurement" by ABS or equivalent IACS

Classification Society for vibration analysis of the equipment associated with regasification plant.

Relevant procedures and criteria used for the vibration analyses shall be submitted for Classification

Society review and approval.

Engineering subcontractor shall also perform structural analysis to the locations where the deck

equipment shall be installed, including but not limited to: the regasification plants, and deck cranes

and vibration analysis to the listed equipment in operations. This analysis shall be used to ensure

vibration free operations under any draft and operating condition of the FSRU. T he results of the

vibration analyses shall be submitted for Classification Society review and approval.

During conversion assessment of noise levels shall also be performed on the vessel. Particular

attention shall be paid to contain noise transmission from machinery rooms, regasification plants, and


Page 16

other machinery spaces with high noise mechanical equipment. Such areas shall be assessed and if

required suitable steps shall be taken to contain and minimize noise levels outside those

compartments to the levels lower than the allowable limits. Noise levels in cabins and office space in

the accommodation area shall be kept below 60 dB.

A Noise Level Measurement Plan, including measurements of sound insulation index, shall be

submitted for review by COMPANY [TBABC 005]. Noise levels shall be measured at suitable points

in the above spaces in accordance with ISO 2923 initially in shipyard and later during gas trials at the

jetty mooring with all machinery in normal operations, including loading and discharging of cargo.

3.7 Sloshing Analysis

CONTRACTOR shall perform a sloshing analysis [TBABC 006] to ensure that the cargo storage tanks

shall have sufficient strength to withstand dynamic sloshing loads resulting from unlimited partial

loading of the tanks during operations at the jetty mooring environment and when evading hazardous

tropical cyclone weather in all loading conditions. It shall also be ensured that sloshing effects in

cargo tanks shall not have any adverse result on the stability of the FSRU. The results of this

analysis shall be submitted to COMPANY and to Classification Society for review and approval.

CONTRACTOR shall take appropriate measures to ascertain that all tanks shall be capable of being

loaded and discharged simultaneously. The FSRU‘s cargo storage tanks shall have adequate design

to ensure that sloshing poses no limitations on the levels of LNG products carried in the cargo\tanks

at any normal operational condition. The boundaries of cargo tanks shall be modified (if necessary)

to withstand dynamic sloshing loads resulting from unlimited partial loading of the cargo tanks,

including mid tank longitudinal bulkhead.

3.8 Electrical System Analysis

CONTRACTOR shall prepare an electrical system analysis and protection relay setting schedule

during detailed design to verify that equipment is adequately rated/sized to comply with normal and

peak operating conditions and to withstand the effects of short circuit currents.

The analysis shall include:

a) Load Flows (maximum and minimum);

b) Short circuit currents (three phase);

c) Voltage drop on large motor starting; and

d) Transient performance on sudden loss of imported power.

The analysis shall be computer based used verified software, preferably universally available and

also include the capability to provide a protection relay setting schedule.

The analysis and protection setting schedule shall comply with the requirements of Classification

Society.


Page 17

3.9 Structural Analysis

Highly loaded structures shall be subject to local structural analysis. Stresses shall be analysed using

classical structural formulae or finite element analysis or other computer analysis tools at

CONTRACTOR‘s option, depending on the nature of the structure or loading. Actual analysis tools to

be used shall be agreed with COMPANY on a case-by-case basis.

As a minimum, the following structural items shall be analysed by finite element analysis:

a) Foundations beneath loading manifold.

b) Investigate the forces, stresses and bending moments transferred to the FSRU manifold

pipework. All forces shall comply with Recommendations for Manifolds for Liquefied Gas

Carriers OCIMF/SIGTTO.

c) Topsides stools and flare tower/vent system.

The following structural items may be analysed by other computer analysis tools:

a) Winch and hoist foundations; and

b) Anchoring and mooring/towing bitts.

All structural analysis calculations shall be approved by Classification Society, and shall be submitted

to COMPANY for acceptance.


Page 18

4. DESIGNATED VESSEL REFURBISHMENT REQUIREMENTS

4.1 Overview

CONTRACTOR shall be responsible for the detailed engineering and shipyard specifications for the

FSRU refurbishment and conversion work. CONTRACTOR shall also prepare the draft contract and

commercial documents for the shipyard Invitation to Tender (ITT), in accordance with

CONTRACTOR‘s Project Execution Plan after it has been accepted by COMPANY [TBABC 007].

As soon as practical, CONTRACTOR shall complete the scopes of work and specifications for the

FSRU, utilizing the results of the pre-acquisition inspections and any further inspections made during

lay-up. These shall be as follows:

a) Scopes of work for detailed inspections and assessments of the vessel structure, systems and

machinery shall be specified, covering the nature and extent of visual inspections, of on-board

strip down, or removal and strip down, all in accordance with CONTRACTOR‘s accepted

Project Execution Plan, and following the general requirements as further. This work shall be

specified to be quoted on a lump sum basis;

b) Estimated tonnage for steel renewals, broken down by category, shall be projected for the

FSRU on the basis of the pre-acquisition inspections, and specified to be quoted on a lump

sum basis;

c) Estimated quantities of pipe system renewals, broken down by system, shall be projected for

the FSRU on the basis of the pre-acquisition inspections, and specified to be quoted on a lump

sum basis;

d) Estimated quantities of electrical system renewals shall be projected for the FSRU on the basis

of the pre-acquisition inspections, and specified to be quoted on a lump sum basis; and

e) Additional work which is not known at the time of the shipyard bid submissions, and shall only

be identified as a result of the detailed inspections and assessments shall be specified to be

paid on a unit rate basis as far as practical, or on an at-cost basis otherwise.

The complete shipyard Invitation to Tender (ITT) package, comprising the bidding instructions, the

draft contract and exhibits, technical specifications and scopes of work shall be subject to COMPANY

review and acceptance prior to issue.

CONTRACTOR shall bid, evaluate and recommend award of the shipyard contract to COMPANY in

accordance with its bid evaluation and Project Execution Plans, which have been accepted by

COMPANY. CONTRACTOR shall keep COMPANY completely informed of all aspects of its bid and

evaluation activities and provide COMPANY with copies of all documentation, calculations, etc.

CONTRACTOR shall also advise COMPANY of the delivery requirements of the FSRU. Award of

shipyard contract shall be subject to review and acceptance by COMPANY.


Page 19

4.2 Delivery of Designated Vessel

Before the designated vessel‘s arrival at the selected shipyard, the vessel‘s prior owner shall offload

all cargo tanks and shall carry out all tank cleaning activities required for port entry. The vessel‘s prior

owner shall arrange and pay for port chemist inspection and for issue of the gas free certificates.

The designated vessel shall be handed over to CONTRACTOR in an operational state with bunker,

lube oil and potable water tanks partially full, and with existing stores and spare parts. Upon formal

acceptance of the designated vessel by the shipyard, the riding crew shall be dismissed

approximately one week after the vessel‘s arrival and CONTRACTOR shall assume responsibility for

the designated vessel.

CONTRACTOR shall arrange for all bunker, lube oil and water tanks to be emptied and gas freed and

for disposal of the liquids. Net proceeds from the sale of the liquids shall be reimbursed to

COMPANY at cost.

CONTRACTOR shall also remove and store ashore all spare parts, engine room stores and deck

stores.

Upon completion of the above, CONTRACTOR shall commence the shipyard phase; the physical

implementation of the refurbishment and conversion works required to transform the designated

vessel into a FSRU.

4.3 General Shipyard Considerations

The shipyard contractor shall perform all refurbishment and construction or conversion works for the

FSRU in accordance with the functional requirements and design criteria defined. This shall be

conducted in strict accordance with CONTRACTOR‘s approved design and engineering drawings and

shipyard specifications.

The shipyard contractor shall prepare shop drawings and shipyard procedures based on the

CONTRACTOR‘s specifications, tests and inspection procedures and plans, and any other

fabrication/construction documentation required to perform shipyard work and as required by

Classification Society.

CONTRACTOR and the shipyard contractor shall carry out all inspections and tests required by

Classification Society and/or Certifying Agency for the refurbishment, construction and/or conversion

works. CONTRACTOR shall be fully responsible for identifying the scope of inspections and tests

and for ensuring that Classification Society Surveyor attend and approve all such tests and

inspections.

CONTRACTOR shall ensure that the shipyard contractor maintains the FSRU in a clean and safe

condition throughout all aspects of work, inclusive of adjacent quayside(s) and fabrication facilities.

If the work is being performed in an area subject to freezing conditions, CONTRACTOR shall ensure

that the shipyard contractor removes any ice and snow to maintain safe working conditions and

provides temporary heating as required to prevent freezing of any fluids contained in the FSRU‘s

systems or equipment.


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The shipyard contractor shall provide security systems and personnel, and firewatch personnel for the

FSRU, and any areas where work is being carried out to ensure the safety and integrity of the FSRU

and that safety codes are enforced, fire risks reduced, and the prevention of access of unauthorized

personnel.

Where new equipment is stored for extended duration, where existing equipment is retained on shore

for extended duration, or after the equipment is installed on board, CONTRACTOR shall ensure that

preservation techniques are implemented to maintain the condition of such equipment. These shall

include:

a) Mounting heat lamps over electrical equipment;

b) Regularly turning over rotating equipment;

c) Filling equipment with preservation oil;

d) Blanking off open pipe ends, filter inlets and other such openings;

e) Boxing-in, or temporarily removing, fragile components;

f) Covering equipment with fireproof cloth; and

g) Following the equipment manufacturer‘s preservation guidelines.

The following sections 4.4 and 5 address the requirements for refurbishment, and conversion of the

FSRU. Although these works are described separately, CONTRACTOR shall ensure that all aspects

of the work are scheduled to optimize the disposition of shipyard labor and resources, by combining

activities where feasible and practical. In particular, CONTRACTOR shall combine as far as practical

refurbishment and conversion work on the same systems and structures to avoid unnecessary

repetition of preparation and support activities.

4.4 Refurbishment

4.4.1 General

This section addresses the general requirements for refurbishment work required to the FSRU to

clear all current outstanding obligations of Classification Society and to allow the FSRU to operate

continuously for the designed service life without dry docking or excessive breakdown.

The current capabilities and limitations of the systems and structure of the FSRU shall be determined,

and shall identify all refurbishments required to upgrade it to meet the functional requirements

detailed in section 5, 5.39 and 16. The shipyard shall be contracted to carry out the refurbishment

activities identified and in accordance with the basic requirements defined below.

4.4.2 Inspection and Repair Plan

Before commencement of refurbishment activities, all redundant structures, equipment and systems

of the FSRU shall be identified. Using the scope of work developed during preparation of the

shipyard contract documents inspection plan shall be developed for all of the remaining structures,

equipment and systems (i.e., those to be re-used, in whole or in part, for the vessel‘s service as the

FSRU), detailing all items to be inspected, and a schedule for performing the inspection work.


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CONTRACTOR and Classification Society shall carry out these inspections and the actual repair

scope and specifications shall be developed accordingly. COMPANY may attend some or all of these

inspections at its discretion. The developed repair scope and specifications shall be submitted to

COMPANY for review and acceptance.

4.4.3 Systems Operational Trials

Before deactivation of existing systems of the FSRU, each system shall be operationally tested to

identify any general deficiencies in performance of the system compared with design requirements,

and to identify any running problems with particular items of equipment. Fuels and

lubricating/hydraulic oils shall be sampled and analyzed to assist in the evaluation of system

performance.

4.4.4 Structural Repairs

CONTRACTOR shall conduct a detailed close-up visual survey and thickness gauging survey of all

hull structure, internally and externally. The procedures for the surveys shall be in accordance with

the requirements defined in the steel renewal requirement section below and shall be carried out in all

tanks, compartments and spaces, and covering the entire hull sides, hull bottom and deck (i.e. not

just in selected tanks or in selected areas). All coatings and scale shall be removed by sweep

blasting (i.e. blast for removal only, not for SA 2½ profile), or hydroblasting, before conducting the

inspections. The effectiveness of the method used to expose the steel shall be demonstrated prior to

commencing the inspections.

All new or renewed structure free edges shall comprise of beveling edges with 45° angle to provide a

good surface for coating.

4.5 Steel Renewal Requirement

CONTRACTOR shall demonstrate that the vessel complies with the CAP-1 requirements, with the

minimum steel renewal specifications as follows.

The specification of steel renewal is based on:

a) No part of the hull shall encounter substantial corrosion during the design life of the FSRU.

b) All parts of the hull shall comply with the net scantling requirement at the end of the FSRU

design life.

Steel renewal should take into account both local corrosion (pitting and grooving) and overall

corrosion.

Substantial corrosion margin is defined as 75% of the allowable corrosion margin as specified in the

inspection criteria of the classification society rules. Plates or stiffeners which show substantial

corrosion must be inspected more intensively and more often than normal vessel structure.

Further the renewal criteria shall also ensure that the thickness shall not fall below the net criteria as

found from scantling calculations or 3D FE calculations.

Combining both criteria, the renewal thickness is found from applying the following:


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a) The thickness at substantial corrosion is calculated from the as built thickness (Guidance note:

where original owner corrosion margins are specified, these shall be subtracted from the as

built thickness before calculating the substantial corrosion thickness).

b) The net required thickness is determined from direct calculations, taking into account the site

specific environmental loads.

c) To the larger value of a) and b) above, the expected corrosion loss is added (FSRU design life

multiplied by the yearly corrosion loss).

Transit cases (the voyage from the construction yard to the FSRU site and future removal) do not

need to be considered for the steel renewal thickness. The existing class notation shall cover the

scantling strength for worldwide trading.

Areas of cracking and distortion shall be repaired and/or modified, generally following the principles of

suggested repairs and modifications to structural details, as given in the ―catalogue of structural

detailing‖ section in the above referenced Guidance Manual. Repair/modification procedures shall be

developed on a case-by-case basis.

The extent of repairs and the repair procedures to be used shall be approved by Classification

Society. The implementation of the repair works shall be surveyed and approved by Classification

Society Surveyor. All deficiencies recorded during the pre-acquisition inspection, any outstanding

Classification Society obligations, and all deficiencies found during the shipyard inspections shall be

cleared, with no remaining, or new, outstanding obligations.

CONTRACTOR shall carry out comprehensive visual inspections of all secondary steelwork, to

identify damaged or corroded areas and components. The scope of repairs shall be identified on a

case-by-case basis. Where considered necessary by Classification Society, the repairs shall be

witnessed and approved by its Surveyor.

4.6 Renewal of Steel below the Renewal Thickness

All plating with thickness below the calculated renewal thickness shall be replaced.

For plating of stiffeners for which no renewal thickness has been indicated (secondary steel and

brackets) the renewal thickness can be derived from the as built plate thickness (no net thickness

check is required).

Table 4.1: Allowable Pitting Depth

Intensity of Pitting Maximum of Wastage in Pit

5% or less 33.3%

10% 32.0%

15% 30.5%

20% 29.0%


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25% 27.5%

30% 26.0%

40% 23.0%

50% or over 20.0%

All areas subject to pitting in excess of the allowable value should be repaired by welding or steel

renewal.

Shallow pits (depth less than the allowable value) shall be treated with a solvent free epoxy system

that is specially formulated to act as a hard epoxy filler and also form a barrier against further

corrosion.

Maximum depth of grooves in stiffener webs is restricted to 1/4 of the associated member thickness.

Maximum depth of grooves along butt welds is 1-mm.

Maximum depth of grooves in excess of the allowable value should be repaired by welding or steel

renewal. Shallow grooves (depth less than the allowable value) shall be treated with an epoxy

coating.

4.7 Addition or Modifications to Gussets and Brackets

Where brackets are replaced they should be replaced by enlarged brackets, such that the bracket toe

is separated at least 50-mm from the original toe position (thus it is assured that there is no previous

fatigue built up at the new toe position).

When flat bar stiffeners on longitudinal - transverse web (or bulkhead) connections should be

replaced, they must be replaced by soft toe brackets, with a backing bracket at the reverse side.

Dimensions shall be advised by engineering.

4.8 Machinery and Equipment Repairs

All existing machinery and equipment shall be assessed for criticality and risk. Piping runs for

systems shall be classified under COMPANY‘s guidelines determined whether inspected or shall be

opened up and inspected as per classification society requirements if due under the FSRU‘s

Machinery Survey program. If not due, survey of these items shall be addressed during Offshore

Operations, and the due dates shall be carried forward into the schedule for the Continuous

Machinery Survey program.

These inspections shall be carried out by CONTRACTOR and Classification Society, and the scope

of repairs and/or renewals and/or refurbishment shall be identified on a case-by-case basis,

dependent on the findings of the operational trials and inspections, and based on comparison of

measured parameters with manufacturer‘s acceptance/rejection criteria for wear-down, tolerances or

other deviations from as-built condition. COMPANY may attend some or all of these inspections at its

discretion. The developed refurbishment scope and specifications shall be submitted to COMPANY

for review and acceptance.


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COMPANY‘s requirements for inspection and refurbishment are described below. Where these

exceed Classification Society‘s requirements, COMPANY‘s shall prevail.

4.9 Pumps

Ballast, stripping, and utility system pumps shall be inspected and with COMPANY‘s concurrence,

removed from the vessel and stripped down to their component parts. Shafts, wear rings, impellers

and other rotating components shall be visually inspected for pitting, distortion, damage and other

defects, and measured against manufacturer‘s dimensional data. Rotating parts shall be dynamically

balanced before re-assembly. Casing structures shall be inspected for pitting, cracks, and other

defects. Irrespective of apparent condition, all bearings, gaskets and seals shall be renewed. All

pump bodies shall be bench pressure-tested following re-assembly, then re-coated as specified in

Appendix 2 - Coatings for Structures, Piping and Equipment.

4.10 Electric Motors

Electric motors shall be inspected and with COMPANY‘s concurrence, removed and stripped down.

Rotor windings shall be visually inspected for tightness, damage or deterioration, and checked for

electrical insulation and continuity. Stator windings shall be similarly checked. Commutator rings,

bushes and electrical terminations shall be checked for wear, damage and burning. Rotor shafts shall

be measured against manufacturer‘s dimensional data. Windings shall be checked for insulation, and

if necessary revarnished and/or rebaked. Irrespective of apparent condition, all bearings and seals

shall be renewed. Motor casings shall be re-coated externally. Refer to Appendix 2 - Coatings for

Structures, Piping and Equipment for full coating details.

4.11 Fans and Blowers

Fans and blowers shall be inspected and with COMPANY‘s concurrence, removed and stripped

down. Shafts and blades shall be visually inspected for pitting, distortion, damage and other defects,

and measured against manufacturer‘s dimensional data. Cast blade roots shall be MPI or UT

checked for cracking. Irrespective of apparent condition, all bearings shall be renewed. All fan and

blower assemblies shall be dynamically balanced after repair, and recoated internally and externally.

Refer to Appendix 2 - Coatings for Structures, Piping and Equipment for full coating details.

4.12 Diesel Engines

Diesel engines shall be inspected and with COMPANY‘s concurrence, overhauled in accordance with

the manufacturer‘s documented overhaul procedures. The nature of each overhaul shall be based

upon the running hours of each engine and the status of the overhauls carried out while the FSRU

was still performing its original duty as a LNGC or RLNGC.

4.13 Inert Gas Equipment

Inert gas generators, boiler flue gas components, P/V breaker and deck seal shall be inspected and

with COMPANY‘s concurrence, stripped down. Burner components shall be visually inspected for

deterioration, damage and other defects. If the equipment is suitable to be retained for the


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conversion, such equipment shall be refurbished to the details provided below. However, if the

equipment is not satisfactory for the conversion, CONTRACTOR shall determine the optimum way of

upgrading the system or providing additional generators. The total output of the gas and nitrogen

generation system and must meet the requirements specified in section 16.6.7.

Existing burner controls shall be cleaned, inspected and tested for correct operation.

For any retained inert gas generators, the combustion chamber and scrubber tower shall be

inspected for deterioration and pitting, and the water jackets shall be flushed clean. All internal

components shall be inspected and cleaned.

The P/V breaker and deck seal shall be drained and inspected internally and externally for damage

and deterioration. Internal paint coatings shall be repaired before re-assembly as specified in

Appendix 2 - Coatings for Structures, Piping and Equipment.

4.14 Boilers

Boilers shall be inspected and with COMPANY‘s concurrence, stripped down as far as practical.

Boiler and burner components shall be visually inspected for deterioration, damage and other defects.

Burner controls shall be inspected and tested for correct operation. Firebricks shall be examined for

damage and cracking. The shipyard contractor shall use a specialist organization to perform boiler

chemical cleaning and re-pacification on both boilers following completion of boiler contractor‘s work.

Water tube bundles shall be visually inspected on both fire side and water side for damage and

fouling, acid cleaned as necessary and pressure tested for leaks. Where an excessive number of

leaks or excessive fouling is found, the complete system shall be re-tubed rather than attempting to

salvage an essentially defective system.

The boiler manufacturer‘s technical representative and CONTRACTOR shall carry out all such

inspections and shall prepare detailed condition assessments and repair specifications to achieve the

design life of the FSRU. The shipyard contractor shall supply labor and equipment including lifting

equipment, lighting and ventilation necessary.

4.15 Steam Turbines

With the exception of the propulsion turbine, turbines shall be inspected and with COMPANY‘s

concurrence, removed from the vessel to the workshop and stripped down to their component parts.

Turbine components shall be visually inspected for pitting, deterioration, damage and other defects.

Irrespective of apparent condition, all bearings and seals shall be renewed, and the turbine rotors

shall be rebalanced.

4.16 Distilling Plant

Distilling plants and/or water makers shall be inspected and with COMPANY‘s concurrence, stripped

down as far as practical and the plant components visually inspected for corrosion, pitting

deterioration, damage and other defects. Heat exchanger bundles shall be inspected for damage and

fouling, acid cleaned as necessary, and pressure tested for leaks. Where an excessive number of

leaks or excessive fouling is found, the complete system shall be re-tubed or replaced rather than

attempting to salvage an essentially defective system.


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4.17 Heat Exchangers

Intercoolers and heaters shall be inspected and with COMPANY‘s concurrence, stripped down as far

as practical. Components shall be visually inspected for corrosion, pitting deterioration, damage, and

other defects. Heat exchanger bundles shall be inspected for damage and fouling, acid cleaned as

necessary, and pressure tested for leaks. Where an excessive number of leaks or excessive fouling

is found, the complete system shall be re-tubed or replaced rather than attempting to salvage an

essentially defective system.

4.18 Electrical Switchboards, MCCs and Distribution Boards

Power and lighting switchboards and distribution boards, and motor control centers shall be

inspected. Bus-bars shall be checked for correct mounting and bolt tightness. Connections,

terminations and switches shall be checked for damage and burning. Circuit breakers shall be

inspected and with COMPANY‘s concurrence, removed and serviced, calibrated and reset.

Operation of switchboard and MCC control circuits shall be verified and components serviced or

renewed as appropriate.

4.19 Instrumentation, Controls and Consoles

Existing instrumentation (pressure gauges, temperature gauges, flow meters, etc.) shall be inspected

and tested and with COMPANY‘s concurrence, either overhauled or renewed as appropriate. All new

such instrumentation shall be calibrated prior to installation. All calibration equipment shall be

suitably certified by an approved certifying agency.

Control systems for existing major and/or critical systems (cargo control, inert gas, boiler, emergency

fire pump, emergency generator) shall be inspected and refurbished.

Related control panels shall be opened up and gauges, switches, cables, relays, terminations, and

other components checked for deterioration, damage and correct operation. Operational simulations

shall be carried out to verify correct operation.

4.20 Deck Cranes

Existing deck cranes and hoists shall be inspected and with COMPANY concurrence, stripped down

as far as practical. Winches shall be fully disassembled and drums checked for damage, wear and

distortion. Electric motors shall be inspected and refurbished as previously described. All

components shall be measured against manufacturer‘s dimensional data.

Hydraulic motors and control and actuation systems shall be inspected and refurbished as found

necessary.

Electrical control systems shall be checked as described for the other control systems on board the

vessel.

Boom, pedestal, winch foundations, pivot points and other major structural locations shall be sweep

blasted and checked for cracks. Structural repairs shall be carried out as found necessary in

accordance with repair procedures and weld procedures approved by the crane manufacturer.


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Irrespective of condition, all bearings, brakes and wires shall be renewed.

CONTRACTOR shall undertake a materials handling study to advice upgrades of cranes. The cranes

shall be rated to operate at 100% capacity in the 10-year return condition on station in accordance

with Classification Society offshore lifting appliances code and regulations.

CONTRACTOR and crane‘s manufacturer‘s technical representative shall also carry out all such

inspections and shall prepare detailed condition assessments and repair specifications to achieve the

design life of the FSRU.

Irrespective of the extent of repairs carried out, all deck cranes shall be statically and dynamically

load tested using test weights sized (relative to the Safe Working Load) in accordance with

Classification Society requirements, upon completion of repairs and re-assembly. Load tests shall be

witnessed by Classification Society and COMPANY, approved by Classification Society and recorded

in the lifting gear registry.

At least one new offshore rated crane with approximately 60-tonne capacity shall be provided for the

regasification unit.

4.21 Other Equipment and Machinery

The materials handling study shall confirm the exact location and capacity to enable the crane to

maneuver HP LNG pumps, tube runners, LNG and regasification valves. Items of existing equipment

and machinery not explicitly addressed above shall be inspected and with COMPANY‘s concurrence,

stripped down, inspected and refurbished to similar levels of detail.

4.22 Classification Surveys

Classification Society surveys are carried out on classed equipment in order to complete the

requirements for the current special survey and provide the maximum time once the FSRU is

installed, until the next special survey is due (e.g. dry-dock the FSRU later rather than earlier during

the shipyard work). To avoid two separate sets of inspections, CONTRACTOR should arrange for

Classification Society Surveyor to attend the relevant refurbishment inspections of existing machinery

and equipment as described above, to allow these inspections to cover the Class survey

requirements.

4.23 Electrical System Inspections and Refurbishment

As part of the overall pre-commissioning and commissioning activities, all cable systems shall be

continuity and insulation tested, and all cabinets and boxes shall be tested. Any deficiencies

identified as a result of this testing shall be repaired.

4.24 Main Propulsion, Steering Gear and Rudder

Propulsion and associated systems shall be dismantled, inspected and refurbished or replaced where

necessary.


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4.25 Piping Repairs

All existing piping runs that are to be retained shall be assessed for criticality and risk as per the

Project Execution Plan. Piping runs for systems shall be classified under COMPANY‘s guidelines

determined whether inspected or shall be opened up and inspected as per Classification Society

requirements if due under the FSRU‘s Machinery Survey program. If not due, survey of these items

shall be addressed during Offshore Operations, and the due dates shall be carried forward into the

schedule for the Continuous Machinery Survey program.

CONTRACTOR shall carry out comprehensive visual inspections of the critical piping runs, as defined

above, to identify damaged or corroded areas and components. As a minimum, inspections shall

address pipe spools, pipe supports and clamps, pipe fittings and instrumentation, and any existing

grounding and earth straps. Selected pipe spools shall be removed from all piping systems to the

extent necessary to determine internal condition (fouling, pitting, wastage, etc.). The scope of repairs

and/or renewals shall be identified on a case-by-case basis. Where considered necessary by

Classification Society, the repairs shall be witnessed and approved by its Surveyor.

Valves shall be removed from all retained piping systems, inspected and with COMPANY‘s

concurrence, stripped down to their component parts. Valve components shall be visually inspected

for pitting, distortion, damage and other defects, and lapped or rebuilt as necessary. Valves shall be

bench pressure-tested following re-assembly.

Control valves and shutdown valves shall be stripped down, overhauled and calibrated. After re-

assembly, valves shall be operationally tested for correct operation before installation.

All solenoids shall be stripped down, overhauled and tested for correct operation before installation.

Pressure relief/safety valves shall be stripped down, overhauled, tested and set to the correct

operating pressure, before installation.

All sea valves shall be explicitly identified and tested in the presence of Classification Society

Surveyor, who shall stamp the valves as per the society‘s normal practice.

All existing flexible hoses (hydraulic, pneumatic, oil transfer etc.,), and all existing seawater system

non-metallic bellows/expansion joints shall be renewed irrespective of condition.

When piping systems are assembled, or re-assembled, new gaskets shall be used for all joints.

Existing gaskets shall not be re-used.

As part of the overall pre-commissioning and commissioning activities, all piping systems shall be

hydrotested and flushed. Any deficiencies identified as a result of this testing shall be repaired.

4.26 Electrical Repairs

CONTRACTOR shall carry out comprehensive visual inspections of all cable runs which are to be

retained, to identify damaged areas and general condition of sheathing, armor, cable trays and

supports, and terminations. Junction boxes, terminal connectors, earth straps, and cables shall be

cleaned and/or renewed as found necessary. The scope of repairs and/or renewals shall be identified

on a case-by-case basis. Where considered necessary by Classification Society, the repairs shall be

witnessed and approved by its Surveyor.


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Defective cables are to be replaced in its entirety. If new cabling is laid, cables shall provide for 25%

future growth.

CONTRACTOR shall carry out comprehensive visual inspections of all junction boxes and distribution

boards, to identify damaged fittings and instruments, defective connections and wiring, and damages

to box and cabinet structures and their mountings. The scope of repairs and/or renewals shall be

identified on a case-by-case basis. Where considered necessary by Classification Society, the

repairs shall be witnessed and approved by its Surveyor.

Engineering Subcontractor shall be responsible for the detailed design associated with the installation

of the electrical system and modifications to the FSRU to ensure safe, functional and maintainable

operation of all equipment

The electrical distribution system shall incorporate a coordinated, selective tripping scheme to

minimize personnel and equipment hazards, and also maintain power to those areas of the FSRU not

directly affected by the fault.

All protective devices, including relays and current transformers (CT‘s) shall be adequately rated to

withstand the prospective short circuit current which can flow or be induced at the point of installation.

A Breaker Protection Coordination study shall be prepared and submitted to COMPANY for approval.

All equipment shall be capable of withstanding the effects of short circuit currents and consequential

voltages arising in the event of equipment or short circuit faults. A margin of not less than +10% shall

be allowed between the calculated fault level and the specified short circuit rating of the equipment.

Existing equipment shall be evaluated (during the course of detailed design) and any discrepancies

with the requirements shall be set out in the specification.

4.27 Coating Repairs

Coating shall be repaired to satisfy the requirements detailed in section 16.2.4, 16.6.19 and Appendix

2 - Coatings for Structures, Piping and Equipment.

4.28 Insulation

Both cold and hot insulation shall be evaluated and shall be reinstalled if damaged or deteriorated to

meet the heat gain (cold) and heat loss (hot) specifications.


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5. CONVERSION ENGINEERING DESIGN REQUIREMENTS

5.1 General

This section addresses the general requirements associated with converting an existing LNG carrier

to be a FSRU and together with the systems needed to accommodate the FSRU requirements.

The current capabilities and limitations of the systems and structure of the FSRU shall be determined

and all conversion work required to upgrade it to meet the FSRU‘s requirements are to be identified.

The shipyard shall be contracted to carry-out conversion work that has been identified and in

accordance with the basic requirements defined below.

5.2 Hull

5.2.1 Hull Side Strengthening

The hull areas in way of mooring fenders and supply boats landing areas shall be specially

considered and adequately reinforced to withstand the operational loads and in accordance with the

requirements of Classification Society.

The side of the hull used for mooring shall be analyzed to ensure structural safety for all conceivable

mooring conditions of the FSRU. The approach velocity in either case is to be considered as a

minimum 25-cm/sec. The resulting reaction stresses in the plating and stiffening of the side-shell

support structure at 50% fender deformation as calculated by linear elastic analysis shall not exceed

0.8 times the structural material yield strength.

Calculations shall also be required to assess the lateral torsional buckling of stiffeners under the

lateral pressure loads applied on the contact area in the approach scenarios considered.

The hull-strengthening belt is defined as the fender areas and other potential contact areas of hull.

The width and extent of the fender area hull-strengthening belt is defined below.

The required scantlings in the fender area and supply vessels hull-strengthening belt shall include

corrosion and abrasion allowances in addition to the plate thickness calculated. The approval from

Classification Society shall not consider the extra scantling for corrosion allowance.

In addition, the hull side plate adjacent to fuel tanks or boundary to fuel tanks is to be capable of

absorbing the energy of the impact caused by a support vessel of 5000-tonnes displacement coming

into contact at a velocity of 2-m/s. The vertical extent of the collision zone is to be based on FSRU

draft variation from ballast (lightest condition) to full loaded condition, the depth and draft of standard

supply vessels. This can be achieved by creating void spaces inside the fuel tanks, or by

reinforcement. CONTRACTOR shall propose an acceptable alternative to COMPANY for review and

approval.


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5.2.2 Bulkheads

Hull bulkheads shall extend to the uppermost deck; strength is to be assessed to withstand this

hydrostatic head.

5.3 Cathodic Protection

5.3.1 Underwater Hull

Should CONTRACTOR provide a vessel for conversion that has an Impressed Current Cathodic

Protection (ICCP) system, it shall be overhauled or restored and modified to working order. For either

a conversion or a new-build, the ICCP system shall be designed such that potentials at the edge of

the dielectric shields shall not be more negative than -1.2-V (Ag/AgCl Seawater) at anytime during the

service life. This criterion is needed to prevent cathodic disbondment of coatings and to prevent

excess hydrogen charging that may limit fatigue life.

A hybrid system combining ICCP and sacrificial anodes may be proposed so long as the above

voltage limitation criteria can be met. In addition sacrificial anodes shall be assessed and replaced as

necessary to protect parts with complicated geometry such as sea chests and water ballast tanks and

any new complex installations as part of the conversion.

The system shall take the jetty ICCP system into consideration.

5.3.2 Ballast Tanks

Bolting type sacrificial anodes shall be applied for the water ballast tanks. An anode utilization factor

of 90% shall be applied for anode design. COMPANY prefers the application of zinc anodes for use in

the water ballast tanks, however shall review the use of aluminum if CONTRACTOR can prove that

the alloy technology is sufficient to mitigate oxidization and reducing the effectiveness.

5.3.3 Sea Chests

The existing sacrificial anodes in sea water inlet chests shall be removed and new aluminum alloy

anodes shall be installed for complete Cathodic Protection.

The anode design life shall be equivalent to the design life of the FSRU under the design current of

100-mA/m².

CONTRACTOR shall:

a) Facilitate the removal of the remnants of existing anodes and their supports;

b) Supply all replacement anodes;

c) Supply and installation of new anode supports in sea water inlet chests and stern tube areas;

d) Supply of all ancillary hardware items such as brackets, clamps, bolts, etc. as far as necessary

for the installation and which are not within the usual scope of anodes supplier;

e) Install new anodes, after application of coatings;


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f) Provide tools and consumables as well as scaffolding lighting and ventilation;

g) Fittings to ensure electrical continuous path between anodes and tank structures, included with

each clamp.

5.4 Structural Considerations

5.4.1 Structural Materials

All steel plate and profiles (flat bar, angle bar, offset bulb plates, T-bar, etc.), shall be supplied by

CONTRACTOR, and shall be new. The use of used materials is prohibited. Steel plate and profiles

shall be approved and certified by Classification Society, original Classification Society certificates, or

certified copies, shall be made available to Classification Society and COMPANY for all materials

used for the FSRU.

In general, all steel plate and profiles shall be ordinary grade steel, to Classification Society‘s Grade B

designation, or better. The use of high tensile steel shall be avoided or minimized, unless required for

compatibility with existing structures.

The degree of corrosion on surfaces of all new steel materials shall conform to rust grades A or B, as

defined by ISO 8501-1:1998, or better. Use of steel materials showing rust grades C or D is

prohibited.

5.4.2 Welding Details

All weld details shall comply with Classification Society Rules, as a minimum. Where COMPANY‘s

requirements noted below exceed Classification Society requirements, the most stringent shall apply.

Fillet Welds

Intermittent or skip welding is only permitted on internal structure that is not exposed to fluids or

weather. All welds on external structure (irrespective of whether such structure is primary, secondary

or cosmetic) shall be double continuous. All hull structure welds inside hull tanks, inside potable

water tanks, or in way of the machinery space bilges shall be double continuous.

Doubler Plates

Doubler plates larger than 200 x 200-mm and all doubler plates with a thickness greater than the

baseplate thickness are, in general, not permissible and require COMPANY approval.

Butt Welds

Butt welds in plating shall be located at least 300-mm apart and 100-mm away from the weld of the

nearest parallel structural member.

5.4.3 Weld Repairs and Assembly Defects

Where weld repairs are required, repairs shall be limited to two attempts on the same joint. Further

repairs shall be carried out by cropping out the affected area and welding in an insert patch.


Page 33

Where the root opening of a butt weld is too large, the weld edges may be buttered or a temporary

backing bar may be used. Where the gap is too large, the plating shall be cut back and an insert

plate welded in. The use of permanent backing bars to correct such defects is prohibited unless

specifically accepted by the classification society.

Where the root opening of a fillet weld is too large, the weld size shall be increased accordingly, up to

a maximum root opening of 5-mm. For root gaps larger than this, a filler plate may be used subject to

the loading not being parallel with the abutting plate. In this case or where the gap is considered too

large, the plating shall be cut back, and an insert plate welded in. The use of permanent backing bars

or lap plates to correct such defects is prohibited unless specifically accepted by the classification

society.

Plate edge laminations found after trimming to size shall either be ground out and the cavity welded,

or removed by cropping out and an insert plate welded in.

5.5 Forming

Steel plates and profiles shall be pre-formed as far as possible before welding to minimize locked-in

stresses. Forming may be carried out by rolling, flanging, pressing, etc., all in accordance with

CONTRACTOR‘s normal practice, subject to bend radii, material elongation and thinning being within

limits acceptable to Classification Society. Flame straightening of plates and profiles to correct weld

or fabrication distortion shall not be carried out except with specific approval of Classification Society.

5.6 Structural Units

Structural units may be prefabricated in accordance to CONTRACTOR‘s normal practice to suit

material sizes and limitations on materials handling facilities. The accuracy of construction of

prefabricated units shall to be closely monitored by CONTRACTOR to minimize the extent of fairing

required during fit-up to adjacent units.

5.7 Temporary Attachments

During fabrication, structural assemblies or plate panels may be restrained in position using

strongbacks, brackets, turnbuckles, etc., in accordance with CONTRACTOR‘s normal practice.

Such temporary attachments shall be removed by chipping or burning off 3-mm from the surface of

the base surface to which it is attached, then grinding flush. Temporary attachments shall not be

knocked off.

5.8 Alignment

In general, components of assemblies shall be aligned to the molded lines shown on the construction

drawings. Any offset from the molded line shall be less than half the thickness of the thinner plate in

the case of butt joints, or less than half the thickness of the joining plate in the case of T or cruciform

joints.

Structures that are to be horizontal or vertical with respect to the vessel's baseline shall be aligned to

within ± 2º.


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Bedplates of foundations shall be fabricated within the tolerances for flatness, level, and twist stated

on the vendor‘s installation drawings of the equipment concerned.

Where an existing, redundant structure is removed, all cut areas shall be ground smooth and coated

to avoid deterioration in service.

IACS Construction Standards No. 47 Shipbuilding & Repair Quality Standard applies in regards to

tolerances.

5.9 Modifications to Existing Structure

To minimize the extent of modifications to existing hull structure, and hence the risk of creating stress

concentrations and structural problems, all new structure shall be integrated as far as practical with

existing hull structure.

Support legs of all new raised platforms or vertical erections on the main deck should be aligned with

crossings of longitudinal and transverse tank bulkheads. Where this is impractical, legs should be

aligned with crossings of tank bulkheads (longitudinal or transverse as appropriate) with main deck

girders.

Where completed assemblies are erected onto existing vessel structure, the structural members of

the assembly shall be aligned with existing vessel‘s stiffeners, frames or bulkheads, as shown on the

structural design drawings. CONTRACTOR shall verify the actual locations and spacing of such

structure in way of new assemblies and adjust the dimensions on the construction drawings

accordingly.

5.10 New Foundations

Foundations for new equipment shall be designed based on the footprint data that is provided by the

equipment vendor and any installation and interface data supplied. Principal support plating for each

foundation shall be aligned with under deck stiffening where practical, with intercostal carlings

installed where not.

Where equipment requires a level and flat bedplate surface, CONTRACTOR shall determine whether

to machine the bedplates flat or to use leveling chocks (Chockfast orange or equivalent). Where

surfaces are machined this shall be carried out after all welding of the foundation to avoid the effects

of weld induced distortion. Where foundations are supported on Chockfast, means shall be provided

to restrain the equipment against lateral movement.

5.11 Piping Materials

All existing shipboard piping shall be in accordance with IACS Construction Standards No. 47

Shipbuilding & Repair Quality Standard. All new systems piping shall be in accordance with offshore

standards (API, ASME or equivalent)

All piping materials (pipe, flanges, bolts, elbows, tees, pipe supports, pipe clamps, etc.), shall be

supplied by CONTRACTOR, and shall be new. Use of used materials is prohibited. Pipes and pipe

fittings shall be approved and certified by Classification Society. Original Classification Society


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certificates, or certified copies, shall be made available to Classification Society and COMPANY for all

materials used.

For steel piping materials, the degree of surface corrosion shall conform to rust grades A or B, as

defined by ISO 8501-1:1998, or better. Use of steel materials showing rust grades C or D is

prohibited.

5.12 Welding Details

All weld details shall comply with Classification Society rules as a minimum. Where COMPANY‘s

requirements noted below exceed Classification Society requirements, the most stringent shall apply.

All pipes butt-welded shall be fitted up with the inside surfaces of the pipes aligned within the

tolerances given in the applicable weld procedure. If, consequently, the outside surfaces are not

aligned, the weld shall be tapered between each pipe section.

Where pipes of different wall thickness are joined, and one pipe is greater than 1½ times the

thickness of the other, the thicker pipe shall be tapered to the smaller pipe diameter with a slope of

1:4 on the side that would otherwise be out of line.

Weldolets, sockolets and threadolets are acceptable for small diameter piping branches and for

instrument piping connections. Preparation of the main pipe shall be strictly in accordance with the

weldolet/threadolet vendor‘s requirements.

Circumferential butt welds shall be spaced no less than 150-mm apart.

Branch welds shall be spaced at least 150-mm from the nearest other branch weld or circumferential

butt weld.

5.13 Weld Repairs and Assembly Defects

Where weld repairs are required, repairs shall be limited to two attempts on the same joint. Further

repairs shall be carried out by cropping out the affected area and welding in a new pipe length, noting

the limitations on weld spacing specified.

Where the root opening of a pipe butt weld is too large, the weld edges may be buttered. Where the

gap is too large, the pipe shall be cut back and a new pipe section welded in.

5.14 Piping System Valves

A sufficient number of isolation valves shall be designed into each system to allow proper isolation of

branches and equipment, and control of liquid flows. Equipment isolation valves shall be double

flanged rather than wafer type. In-line system valves may be flanged or wafer type, at

CONTRACTOR‘s discretion.

All valves shall be readily accessible from the normal traffic areas. Where valves are located under

floor plates, these valves shall be completely below floor plate level, and the floor plates shall be fitted

with hinged covers in way of the valve handles. Where valves cannot be positioned within reach of

normal traffic areas, reach rods shall be fitted to the valve handle, or access platforms shall be

provided.


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5.15 Piping System Instrumentation

Sufficient instrumentation shall be designed into each system to allow proper monitoring of the

system operation and to allow troubleshooting.

Instrument connections on piping shall consist of threaded stub pieces or threadolets welded to the

pipe. For the purposes of testing and inspection, the threadolets shall be considered part of the main

pipe section. All instrument connections shall be fitted with 3-way ball or needle valves screwed

directly onto the threadolet.

Instruments shall be connected to the valves via 316L stainless steel tubing. This tubing shall,

wherever possible, be continuously supported on trays, racks or bar supports. Where this is not

possible, tubes may be supported at intervals no greater than 1-m. Where instrument tubing is run on

the exposed weather decks, the tubing shall be located to avoid damage by dropped objects or by

personnel walking on it. In these cases, the tubing may be supported on pipe supports of other piping

systems, and run adjacent to and below the other piping.

Thermometers shall be mounted in thermowells. Remote temperature sensors shall be mounted via

tube, as defined above.

All local instrumentation displays shall be located within clear sight of the normal traffic areas,

irrespective of the location of the connection point to the piping system. Instrumentation displays

shall be grouped logically by system and equipment.

Full-scale deflection on each pressure gauge shall be approximately 1.5 times the maximum system

pressure at the gauge location.

Full-scale thermometer readings shall be approximately 2 times the maximum system temperature at

the thermometer location.

Remote instrumentation and alarms shall be grouped on the appropriate alarm and control panels in

the Engine Control Room and/or Central Control Room.

All instruments and gauges shall be calibrated prior to final installation.

5.16 Filter and Strainer Arrangement

Where filters and strainers are incorporated into pipe runs, these shall be fitted with isolation valves at

their inlets and outlets, and shall be fitted either with individual suction and discharge pressure

gauges or a differential pressure gauge across the suction and discharge.

Strainer basket mesh or perforation size shall be no greater than the diameter of the smallest fluid

passage in the equipment being served. Unless noted otherwise, the clear open area of each strainer

element shall be at least two times the area of the pipe upon which it is mounted. Strainers shall be

installed with adequate access around them to permit straightforward removal of covers and baskets.

Strainers shall be equipped with means for venting and draining. Drip pans shall be used under

hydrocarbon system strainers piped to the engine room dirty oil tank. Water strainers shall drain to

bilge or deck, as appropriate.


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5.17 Pump Arrangements

All pumps shall be fitted with isolation valves at their suctions and separate stop and check valves at

their discharges. Pressure gauges shall be connected to all pump suctions and discharges. These

gauges shall be grouped onto a common mounting plate per pump and installed within clear sight of

the pump discharge control valve. Minimum flow bypass with control shall be provided for LNG

Booster Pumps and for other pumps as deemed necessary to meet turn down requirements.

Minimum flow bypass with control shall be provided for LNG booster pumps and for other pumps as

deemed necessary to meet turn down requirements.

5.18 Pipe Supports

Pipe supports shall be located at all changes of direction to resist thrust forces, and on either side of

substantial fittings or pumps to avoid the weight of the pipes being supported by the fittings. Pipe

supports shall also be installed at regular locations along pipe lengths. The spacing and design of

pipe supports shall be in accordance with Classification Society approved shipyard booklet of

standard pipe details. Teflon pads shall be fitted between all pipe supports and the pipe.

Stress calculations shall be carried out for major and/or critical ship systems subject to substantial

thermal, static or hydrodynamic loads.

5.19 Deck and Bulkhead Penetrations

Pipes shall pass through watertight bulkheads and decks via welded penetrations. Pipe penetration

design shall be in accordance with Classification Society approved shipyard booklet of standard pipe

details

5.20 Pipe Expansion and Movement

Expansion joints or loops shall be incorporated in pipe runs where pipes are subject to thermal

expansion or to movement due to hull deflection. In these cases, sliding pipe supports shall be

installed on either side of the expansion joint or loop. Pipe clamps shall be configured to allow free

movement, and adjacent piping shall be properly anchored. Sliding supports and pipe anchors shall

be in accordance with Classification Society approved shipyard booklet of standard pipe details.

All piping connected to diesel engines or any other equipment subject to vibration shall be connected

through flexible hoses or flexjoints. Piping shall be properly supported in way of the connection to

avoid the pipe loads being taken by the hose or flexjoint. Alignment between the pipe and the

equipment connection shall be within the manufacturer‘s defined tolerances for the hose or flexjoint.

5.21 Vents and Drains

All piping systems shall be provided with vents at the high points and drains at the low points. In each

case, these shall comprise threaded stub pieces or threadolets welded on the pipe, with square or

hexagonal headed threaded plugs.


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5.22 Bonding and Grounding

For piping containing hydrocarbons and liquid fuels, flanges shall be electrically bonded together and

pipe spools shall be grounded to the ship‘s structure. Hoses shall be electrically continuous.

5.23 Flow Velocity Limits

The pipe diameters shall be determined to limit flow velocity to industry standard values for various

fluids. CONTRACTOR shall take due note of any velocity limits of the valves to be used and specify

these so that the valve liners are rated to above the maximum loading velocity.

5.24 Piping Modifications

Where existing systems are made redundant, either completely or partially, redundant piping should

preferably be removed from the vessel. Where this is not practical, pipe spools should be removed in

way of redundant equipment and closed with welded caps or blind flanges.

Where existing piping systems are extended or modified, or where new systems are installed,

CONTRACTOR shall note the following:

a) Tie-ins to existing pipe runs should be configured to avoid compromising the performance of

the original system;

b) Where existing pipe spools are modified, such modifications should be carried out with the

spool removed from the piping system to avoid contamination of the system with cutting and

welding debris;

c) Pipe supports in way of tie-ins shall be modified and/or additional supports provided to allow for

changes in thrust loading;

d) New pipe spools shall be fitted with anchor points and movement/expansion means to allow for

thermal movement and/or vessel hogging and sagging;

e) Where new pipe supports are required, attention shall be given to the safety of welding such

items to existing structure, in particular with respect to the flammability of materials on the

opposite side of the structure. Where necessary, the back side of the structure shall be cleared

of lagging, linings, cables and other items likely to be damaged prior to starting welding or

cutting operations.

5.25 Electrical Requirements

5.25.1 Cable Types

In general, electric cable shall be JIS marine cable (JIS C3410) or equivalent, approved by

Classification Society.

660V cable shall be used for AC 440V circuits, and 250V cable for AC 220V and DC 24V circuits.


Page 39

Cables shall be accordance with the following requirements, depending on the locations in which they

are to be used. Where an individual cable passes through different locations, the cable specification

relating to the most onerous area shall be used throughout.

Area 1 Accommodation Spaces and Air Conditioned Machinery Spaces

Conductors shall be high conductivity annealed copper. Cable cores over 1.5 square millimeters

cross section shall be stranded. Power circuits shall be single, double or triple core cables.

Communications and control circuits shall be multi-core with 10% spare cores for future extensions

and modifications. For power circuits the minimum conductor size shall be 1.5 square millimeters.

Cable insulation shall be ethylene propylene rubber insulated (EPR) or cross-linked polyethylene

(XLP).

Cables shall be sheathed overall with PVC.

All cables shall be at least flame retardant in accordance with IEC Publication 332-3.

The current rating of each cable shall be higher than the highest continuous load that may be carried

by the cable. No diversity factors may be applied.

Area 2 Non Air Conditioned Machinery Spaces and Weather Decks

Cables shall have the same properties as required for those cables in Area 1 and, in addition, shall be

protected by steel single wire armoring, steel tape armoring or metal braid basket weave armoring,

with overall sheathing of impervious PVC to protect the armoring against corrosion in these humid

spaces.

The minimum conductor size for power cables on the weather decks shall be 2.5 square millimeter.

All cables running along the main deck shall be continuous. Joints are prohibited.

Area 3 Galley, Laundry and Air Conditioning and Fan Rooms

Cables shall have the same properties as those for Area 1 with the addition of an overall impervious

PVC sheath to protect against water ingress.

5.25.2 Cable Glands and Multi -Cable Transits

All cable glands and multi-cable transits shall be approved by the classification society, and shall be

watertight and fire rated, as appropriate. Cable glands used on weather decks shall be of corrosion

resistant materials and compatible with the materials of the junction or terminal boxes to avoid

galvanic corrosion.

5.25.3 Junction Boxes

The electrical layout shall be designed to minimize the use of junction boxes. Junction boxes on the

weather decks shall be watertight and suitably certified for the location. In general, boxes should be

cast steel or brass. Junction boxes within the accommodation or the machinery spaces may be of

rigid plastic.


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Terminal blocks within the junction boxes shall be mounted on flame retardant, moisture resistant

material of permanent high dielectric strength and high insulation resistance. Terminals shall be

sufficiently spaced to prevent short circuits between cores or between the cores and earth.

5.25.4 Fuses

Fuses shall comply with IEC Publication 269, ―Low Voltage Fuse with High Breaking Capacity,‖ or an

equivalent standard.

Fuse links and fuse bases shall to be marked with particulars of the rated current and voltage.

Re-wireable fuses are not acceptable.

5.25.5 Local Motor Control Boxes

Where local starting of motors is required, this shall be by a control box mounted near the motor at an

accessible location. This shall be wired into the motor starter in the appropriate motor control center.

Each box shall be IP23 minimum, made of plastic or corrosion resistant metal. Each box shall be

equipped with a green start push button, a red stop push button and a white running lamp.

Each box shall be fitted with a plastic engraved identification plate screwed to the box front, naming

the motor duty and its tag number.

5.25.6 Motors

All motors shall be totally enclosed fan cooled, squirrel cage induction type. Motor windings shall be

impregnated against salt water, salt air, oil fumes and fungus. Metal parts shall be of corrosion

resisting materials or treated against corrosion. Motors shall be standardized at Class F insulation

unless higher temperature insulation is required by the classification society.

All motors on the weather decks or in machinery spaces shall be equipped with single phase space

heaters, interlocked to automatically switch out when the motor is energized and switch in when the

motor is dead.

5.25.7 Light Fittings

Light fittings shall comply with Underwriters Laboratory publication UL595 - Marine Type Electric

Lighting Fixtures, or equivalent standard.

Light fittings on the weather decks shall be watertight, and explosion proof where located in

hazardous areas. Light fittings inside the engine room, machinery spaces and engine room and deck

stores shall be drip proof. Lights shall be twin tube fluorescent.

Light fittings in the accommodation deckheads shall be recessed twin tube fluorescent type, with

opaque diffusers. Fittings shall be mounted flush with the surrounding deckhead panels.

Decorative light fittings in the accommodation and desk lamps shall be incandescent.


Page 41

5.25.8 Cable Routing

Electric cables shall be routed on cable trays and supports. Cables are to be routed clear of areas of

high temperature and high humidity.

Cables are to be run such that any bends do not exceed the minimum bending radius limits defined in

IEC 92-352: ―Choice and Installation of Cables for Low Voltage Power Systems‖, or the cable

manufacturer‘s cable specifications, whichever is greater.

Intrinsically safe circuits shall be physically separated from all other circuits. Cables for intrinsically

safe circuits shall be routed on separate trays wherever possible. Where this is not possible, the

cables shall be physically separated from all other non-intrinsically safe cables by at least 100-mm.

Under no circumstances shall intrinsically safe cables be secured under the same clip as other

cables, or pass through a multi cable transit or cable duct being used for non intrinsically safe circuits.

All intrinsically safe cables, or conduits carrying intrinsically safe cables, shall be marked with blue

colored tape or binding along their whole length at intervals of not more than two meters.

Where cables are run in the accommodation, wiring shall be concealed behind the deckhead and

bulkhead paneling. Where it is not possible to conceal the wiring, then the cable is to be covered with

plastic decorative covers.

5.25.9 Cable Supports

Cables run in groups shall be routed on cable trays. Cables in the machinery spaces and in the

accommodation shall be fixed to the trays with mild steel banding straps with PVC coating. Cables on

weather decks shall be fixed with stainless steel banding straps. PVC cable hangers and clips shall

not be used outside where they would be subject to ultra violet degradation.

5.25.10 Cable Protection

Where cables are exposed to possible mechanical damage, cable trays shall be covered with bolted,

removable steel plate panels. Individual cables shall be run in pipe conduits or flexible cable

conduits.

Cables laid under the tank top walkways in the machinery spaces shall be protected as defined

above.

5.25.11 Cable Terminations

Power wiring terminations shall be accomplished using ring-tongue or lug terminals tightly clamped

onto the ends of the cores. The terminals shall be clamped to the equipment termination blocks or

the switchboard/MCC termination rails as appropriate, using stainless steel bolts and lock nuts. Pinch

screw connections are not acceptable.

Control wiring terminations shall accomplished using spade-type terminals crimped onto the ends of

the cores. The terminals shall be clamped to the termination blocks as defined above.

All cable connections shall be dimensioned such that the heat generated by the maximum current

flow through them does not exceed the temperature rating of the cable insulation.


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No more than two wires shall be connected together at any one termination point.

5.25.12 Cable Deck and Bulkhead Penetrations

Cable penetrations through watertight decks shall be through kickpipes at least 250-mm high with

watertight glands at the top, or through a riser box fitted with multi-cable transits (MCT‘s). In general,

the latter should be restricted to penetrations in locations not exposed to weather.

Cable penetrations through watertight bulkheads shall be through cable glands or MCT‘s.

Where cables penetrate non-watertight decks or bulkheads, cables may pass through openings in the

structure fitted with welded coamings, or through cable pipes.

Where cables penetrate A-0 or A-60 decks or bulkheads, fire-rated multi cable transit glands (MCT)

only shall be used, except for single cables in which case single fireproof cable glands can be used.

Openings and cable pipes are prohibited for this application.

5.25.13 Joining of Cables

In general, cables shall only be joined using classification society approved junction boxes.

Cable splices shall not normally be used. Where splices are desired, these shall be limited to safe

areas not subject to salt-water ingress. Use of splices shall be at the discretion of Classification

Society. Where approval is given, then the splice jointing shall be from Classification Society

approved supplier, and the splicing work shall be approved by Classification Society.

5.25.14 Conduits

Cable conduits shall, in general, be galvanized steel pipes. The ends of the pipes shall be cut square

and reamed free of burrs. Where the conduits are not terminated in cable glands, plastic bushings or

other means of protecting the cable sheaths from abrasion shall be fitted into the exposed ends of

each conduit. Conduits shall be earthed to the ship‘s structure.

Electrical conduits in seawater ballast tanks, or other spaces where seawater is normally present,

shall be made of aluminum-brass pipe.

5.25.15 Panel Mounting

Switchboard, distribution panels, junction boxes and similar items shall be mounted as follows:

a) Panels shall be bolted to their supports;

b) A minimum of four mounting bolts shall be used; and

c) Large panels mounted on deck foundations shall be braced at the top to minimize loads on the

base mounting bolts when in a seaway.

5.25.16 Grounding

Metallic sheaths or braids of armored cable shall be earthed to the hull at both ends of the cable.

Where armored cable enters a terminal or junction box, the armor shall be continued into the box and


Page 43

earthed to the box by a clamp and connector. The cable gland alone shall not be accepted as a

grounding connection. Where this is impractical, the armor shall be grounded to the steel structure at

the nearest cable strap. All grounding connections shall be cleaned at the point of contact before

connection.

Special communications and control cables shall be grounded in strict accordance with the equipment

manufacturer‘s installation requirements.

Switchboard and MCC cubicles, distribution panels and other electrical metal enclosures shall be

grounded to the hull of the vessel using bonding wire or braid with lugs at each end, which shall be

bolted to a grounding stud on the frame of the enclosure and bolted to a stud welded to the ship‘s

structure. The mounting bolts of the enclosure alone shall not be accepted as a grounding

connection.

Electric motors shall be grounded to the hull of the vessel using bonding wire or braid with lugs at

each end, which shall be bolted to a grounding stud on the frame of the motor and bolted to a stud

welded to the ship‘s structure. The foundation mounting bolts of the motor alone shall not be

accepted as a grounding connection.

Enclosures of starter boxes and distribution panels shall be bonded to the ship‘s structure with braid

or wire, as above, and the door(s) shall be bonded to the enclosure with braid or wire. The door

hinges alone shall not be accepted as a grounding connection.

5.25.17 Hazardous Area Considerations

Hazardous area zones shall be agreed with Classification Society and Certifying Authority. All

electrical installations in such zones shall comply with Classification Society requirements for

electrical installation in hazardous areas and with API RP 14F ―Recommended Practice for Design

and Installation of Electrical Systems for Offshore Production Platforms."

5.25.18 Electrical Modifications

Where existing systems are made redundant, all redundant electrical cabling and equipment should

preferably be removed from the vessel. Where this is not practical, cables should be cropped back to

a convenient location at both ends, and clearly tagged as being redundant. Redundant breakers and

switches in distribution boxes and MCC's should be isolated and old nameplates removed.

Where new cables are installed, CONTRACTOR shall note the following:

a) Power, signal and intrinsically safe cables shall be run in separate cable trays or conduits in

accordance with IEC requirements;

b) New cables shall be pulled without damaging existing cables, and without damaging

themselves on existing cable straps or other obstructions. CONTRACTOR shall evaluate the

cable pulling routes and provide protective coverings where necessary;

c) Where new handling equipment is installed, cable runs shall be provided with mechanical

protection in way of the working arcs of the handling equipment; and


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d) Where new cable trays and conduits are required, attention shall be given to the safety of

welding such items to existing structure.

e) Cable shall allow for 25% spare capacity for future growth.

5.26 Modifications to Existing Equipment

Where existing equipment does not perform to the level required for service, CONTRACTOR shall

determine the most appropriate means of rectifying such deficiencies, e.g., upgrading specific

components of the equipment, replacing the equipment with a new higher performance item,

supplementing the system with additional equipment, and/or modifying the configuration of the

system. However, where equipment is upgraded, replaced and/or supplemented, the preparation of

mass flow and pressure calculations to demonstrate that the newly configured system is capable of

satisfactory operation, without compromising the operation of the existing equipment.

CONTRACTOR shall also note that enhancing items of equipment may require upgrading of utility

services and control systems and shall be responsible for identifying all such consequential activities

and implementing changes accordingly.

Wherever practical, redundant equipment should be removed from the vessel.

5.27 Installation of New Equipment

All new equipment procured shall be transported from the shipyard storage facilities and installed on

FSRU, as and when required.

CONTRACTOR shall determine appropriate sequencing of work to ensure that new equipment is not

installed at too early a stage such that it is at risk of damage. In particular, equipment shall not be

installed in areas subject to grit blasting unless the equipment is satisfactorily protected against grit

contamination.

All foundations shall be fully coated before installation of equipment thereon, including the support

surfaces.

All equipment manufacturers' instructions regarding lifting and handling are to be taken into account

and use of spreader bars where necessary.

CONTRACTOR shall take due account of manufacturer‘s requirements regarding alignment and

leveling prior to bolting in place. All bolts shall be of the correct sizes and types as specified in the

manufacturer‘s installation instructions.

All interfaces with other vessel services are to be determined, and ensured that interconnecting

pipework and cabling is installed such that they are properly supported off the equipment to avoid

stressing the interconnections and that interfaces take due allowance for vibration and movement of

the equipment. Flexible joints shall be utilized in pipe interconnections where recommended by the

equipment manufacturer. All cable interfaces shall be looped before entering the junction boxes.


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5.28 Coatings

Coating activities shall be carried out progressively during the shipyard phase, scheduled and

sequenced to suit the other activities. CONTRACTOR shall minimize the extent of damage to new

coatings due to subsequent work and shall also schedule coating activities to take account of

maximum allowable overcoating times for certain types of coating.

All coatings damaged in the course of repair, refurbishment and conversion work shall be repaired.

CONTRACTOR shall determine on a case-by-case basis whether to touch up damaged coatings or to

remove coatings to logical boundaries and to recoat. Refer to Appendix 2 - Coatings for Structures,

Piping and Equipment for full details on all relevant coating details.

5.29 Typical Non-Destructive Examination Requirements

New and Repaired Structural Assemblies (Including Temporary Access Openings)

a) Visual Examinations

i) All new and repaired welded joints.

b) Radiographic and/or Ultrasonic Examinations

i) For plate seam welds: All weld intersections, all areas where the seam crosses stiffening

members, all corners, plus 10% of the remaining extent of weld seam at locations to be

defined by COMPANY and/or Classification Society.

ii) For stiffeners: All butt joints.

iii) For small circular insert patches (less than 300-mm diameter): Complete perimeter.

iv) For areas identified as fatigue ―hot spots‖ by the fatigue analysis.

v) Additional areas at Classification Society‗s discretion.

c) Magnetic Particle and/or Dye Penetrant Examination

i) For all suspect fabrication welds, at the discretion of COMPANY and Classification

Society, to verify lack of surface cracks or fusion.

ii) For all arc strikes after grinding, to verify removal of cracks.

iii) For all areas subject to RT/UT examination, as specified above.

iv) Additional areas at Classification Society‘s discretion.

All examinations shall be carried out in accordance with internationally recognized test procedures,

acceptable to Classification Society. Repairs to defective welds and repeat examinations until the

defects are proven cleared shall be at CONTRACTOR‘s expense.

Acceptance/rejection criteria shall be in accordance with the appropriate sections of the ABS ―Rules

for Nondestructive Examination of Hull Welds‖, or equivalent rules of Classification Society if more

onerous.


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5.30 New and Repaired Piping Systems

a) Visual examinations

i) All new and repaired welded joints

b) Radiographic and/or ultrasonic examinations - All Piping Systems

i) A minimum of 5% of all circumferential and flange welds; or

ii) One shot on one weld in each twenty welds for each pipe welder engaged in the work,

whichever is greater.

c) Magnetic particle and/or dye penetrant examination

i) For all arc strikes after grinding, to verify removal of cracks.

ii) For all suspect fabrication welds, at the discretion of COMPANY and Classification

Society, to verify lack of surface cracks or fusion.

iii) All thrust restraints, lugs, and anchor points directly welded to pipe surfaces, to verify

lack of surface cracks.

iv) All suspect slip-on-flange fillet welds, at the discretion of COMPANY and Classification

Society.

v) Additional areas at Classification Society‘s discretion.

All examinations shall be carried out in accordance with internationally recognized test procedures,

acceptable to Classification Society. Repairs to defective welds, and repeat examinations until the

defects are cleared, shall be at CONTRACTOR‘s expense.

Acceptance/rejection criteria shall be in accordance with ASME/ANSI B31.3/ANSI B31.8 whichever is

appropriate.

5.31 Tank Dome Expansion Bellows

The shipyard contractor shall supply personnel, materials and equipment; including lift gear for the

removal, disposal of existing bellow pieces and installation of the new. The shipyard contractor shall

also clean and prepare surfaces of mating flanges and retaining pieces. Testing is to be carried out in

the presence of Classification Society‘s Surveyor and/or COMPANY.

5.32 LNG Cargo Transfer System

The cargo pump system shall include one duty and one standby submersible cryogenic pump for

each storage tank.

CONTRACTOR shall determine whether the existing pumps can satisfy the LNG cargo transfer

system requirements. If existing pumps is to be retained, CONTRACTOR shall refurbish the pumps

and conduct modifications to be able to be changed out in-situ.


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5.33 Spill Protection

CONTRACTOR shall provide stainless steel drip trays on all blind flanges, in way of manifold and

loading arms and in areas where it is required to remove spill pieces for operational duty warm up and

cool down.

Fresh water supply shall be provided to drip trays and drain to rinse spill to slosh tanks. Spill trays

tanks shall be sized 120% of maximum spill volume.

The FSRU shall comprise cryogenic spill protection.

The LNG spill philosophy is by vaporization which shall be aided by a zoned deluge systems and

minimization of possible spillage volumes (this requires that the CONTRACTOR provides an

integrated LNG leak detection system, spill trays under valves and equipment, sleeves around

flanges, etc). In general the process areas shall comprise a spill deck below the process decks with

loop seal and drain arrangement and longitudinal baffles (to avoid over flow during roll motion). The

use of spill walls should be avoided since these walls reduce the air circulation and therefore prevent

the rapid vaporization of LNG. The piping layout shall be developed with spill mitigation and

collection being a key design criterion. The use of fiber reinforced concrete deck coverings is not

permissible on strength decks (i.e. main deck/upper deck) unless it is removable for inspection.

The following areas shall as a minimum comprise the following spill protection.

a) Process area:

i) Local collection trays under potential sources of leaks

ii) Stainless steel collection deck integrated into main process deck.

iii) Local protection at main deck level as determined by a spillage study conducted by the

CONTRACTOR

iv) Local deflectors to protect foremost LNG tank external cover.

v) Use of flange guards and local deflectors to minimize extent of liquid sprays.

vi) Drain system to safety collect rain water and LNG spills should they occur.

vii) Zoned deluge system.

b) Loading area:


ii) Stainless steel collection tray at main deck under loading arms and flanged piping.

iii) LNG spills directed overboard and hull protected by water deluge.

iv) The deluge system shall be operated during LNG transfer operations. At other times the

deluge system shall be automatically activated on detection of a spill as the piping

manifold remains liquid filled.

c) Dome Tops and other areas containing flanged LNG piping:



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ii) Stainless steel collection tray under flanged piping and instruments containing LNG.

iii) Drain system to safety collect rain water and LNG spills should they occur.

5.34 Marine & Utility Systems

5.34.1 Mooring Winches and Equipment

Mooring winches may be retained and re-used if suitable. CONTRACTOR shall refurbish retainable

mooring winches. CONTRACTOR shall test refurbished mooring winches and equipment on shore.

Testing is to be carried out in the presence of Classification Society‘s Surveyor and/or COMPANY.

See section 7 for details.

5.34.2 Mooring Line Modification

The shipyard contractor shall remove and dispose of existing mooring rope and install new mooring

lines onto winch drums in accordance with mooring line vendor‘s recommendations.

5.35 Power Generation and Electrical Systems

The existing steam turbine and diesel generators may be retained if these are in suitable condition

and have sufficient capacity. Retained generators are to be dismantled and refurbished. Burners are

to be overhauled and down rated to provide 100% of the stream requirement. However, if generators

are needed to be replaced or additional generators are necessary, CONTRACTOR shall determine

the optimum way of upgrading the system or adding additional power generators. CONTRACTOR

shall determine the most appropriate type of drivers (steam turbine and/or diesel), based on steam

and fuel availability.

The total output of the power generation and electrical systems shall meet the requirements as

specified in section 16.5.

5.36 Accommodation & Personnel Equipment

Dependent upon its condition and configuration, the existing accommodation block of the FSRU may

be retained and modified, or removed in its entirety and a new prefabricated accommodation block

installed in its place. The choice of option to follow shall be proposed by CONTRACTOR and agreed

by COMPANY. Factors that will affect the choice shall include, but not be limited to:

a) Presence of asbestos;

b) Suitability of accommodation layout to be economically modified to accept the additional

complement;

c) Structural condition and extent of deterioration of steelwork, in particular wet spaces (showers,

toilets and wash rooms) and galley areas.

In either case, the following general requirements shall apply:


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Bulkhead and deck structures shall comply with Classification Society rules and formulae for

superstructures;

a) The forward bulkhead, and the side bulkheads to the extent required by the classification

society, shall be A-60 rated. All windows in these areas shall be rated to A-60 and certified as

such by an internationally recognized certification agency. No doorways shall be permitted in

the forward bulkhead. In the case of an existing accommodation block that is not rated to A-60

as specified, CONTRACTOR may elect to provide a deluge system in lieu of upgrading the

existing structural fire protection, subject to approval by Classification Society;

b) Preferably, wet spaces shall be separated from surrounding accommodation spaces by welded

steel bulkheads rather than floating panels. However, floating panels and/or molded plastic

shower cubicles may be considered at COMPANY‘s discretion, subject to adequate means

being provided to prevent water leakage or corrosion damage;

c) Disposition of welded steel bulkheads and decks shall comply with the requirements of SOLAS,

with respect to fire rating of bulkheads, decks and stairwells;

d) Bulkheads surrounding the Central Control Room shall be steel and all surrounding bulkheads,

deck and deckhead shall be rated to A-60.

For the existing accommodation block, modifications shall be made as required to ensure it complies

with the above requirements. Where a new accommodation block is provided, this shall be designed

and fabricated in accordance with these requirements.

Where a new accommodation block is to be installed, the existing accommodation should be removed

in its entirety to main deck level leaving the engine room casing in place. If the original configuration

of the FSRU does not permit this (i.e. if the engine room casing is part of, or linked to, the

accommodation block structure), CONTRACTOR shall determine the most appropriate location for

the limit of removal and the nature of any closures in way of the retained structures.

The accommodation block shall be classified as a safe refuge.

The perimeter bulkheads and major internal bulkheads of the new accommodation block shall be

aligned with existing main deck underdeck bulkheads, frames and girders. Such underdeck members

shall be reinforced as necessary to accommodate loads imposed by the accommodation block,

including dynamic loading. The layout of the new block shall align with and incorporate existing

stairwells, cable and pipe trunks to minimize the extent of modifications required to structure and

systems below the main deck.

The configuration of the accommodation is laid out in section 16.8.2

5.37 Noise and Vibration Levels

Vibration levels (throughout the FSRU) are to be judged in accordance with ISO 6954 ―Mechanical

Vibrations and Shock – Guidelines for the Overall Evaluation in Merchant Ships‖ 1984

Noise and vibration levels in all crew spaces (accommodation and work areas) are to comply with ISO

9654:2000 and IMO Resolution a.468.


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The noise level limits shall not exceed the limits given as in Table 5.1 during normal FSRU operating

conditions.

Table 5.1: Noise Level Limits


Continually Manned Machinery Space 85

Non-Continually Manned Machinery Space 108

Machinery Control Rooms 75

Offloading Areas Duty Station 80

Regasification Plant 75

Control Room 65

Offices 65

Hospital 60

Crew Public Spaces 65

Crew Cabins 60

The vibration peak limits shall not exceed the values as given as in Table 5.2 during normal FSRU


Table 5.2: Vibration Level Limits

Vibration Level Limits 1 – 5 Hz 5 – 100 Hz

Upper Levels 214-mm/s² 6-mm/s²

5.38 HVAC Equipment

The shipyard contractor shall be required to replace the existing air conditioning compressor

packages if it is considered insufficient or an R-22 refrigeration system.

If replacement is necessary, the shipyard contractor shall conduct the following:

a) Provide all vendor documentation detailing the manufacturers‘ certificates, spare part manuals,

specifications, and construction drawings for the installation of new equipment.

b) Remove all on board HVAC lubes and R-22 refrigerants and arrange for temporary storage of

all refrigerants at the shipyard contractor‘s facilities, old lubes to be disposed of.

c) Demolition and disposal of the existing main & auxiliary air conditioning compressor packages

including oil pumps and control panels.


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d) Supply, install and commission new R-134a refrigeration equipment complete with all

accessories.

e) The air inlets shall be positioned to avoid the drawings of fumes and gas.

f) All vents shall comply with the IGC code.

g) Airlocks shall be provided to the accommodation.

5.39 Fire Fighting

Appropriate strategies for fire fighting shall be determined on basis of both regasification plant and

LNG tank requirement. Fire fighting systems shall typically include mixtures of water spray/deluge,

dry chemical powder, foam, monitors, water mist, inert gas extinguishing and in rare circumstances

CO2 flooding. Preference would be for:

a) A water mist or alternatively an inert gas extinguishing, or a high expansion foam system, in the

main machinery spaces, alternatively a CO2 flooding system can be considered;

b) A deluge/water spray to cover major fires on LNG tanks, manifold, process vessels, and

mooring system areas;

c) A dry chemical powder system to fight small to medium LNG fires in process/LNG piping areas;

d) Potentially a high expansion foam system over the process area;

e) A fixed low expansion foam fire fighting system for deck and process deck;

f) In living quarters and stores (but not in CCR or switch rooms) sprinkler systems plus

extinguishers and hoses.

However, alternate strategies may be appropriate including selected CO2 flooding in rarely occupied

machinery spaces, oscillating monitors instead of deluge, etc.

In addition the facility shall be equipped with various passive fire fighting systems such as A60 rated

walls around quarters and machinery spaces, possibly a blast wall between cargo tanks and

regasification plant, fire retardant paint on specific areas, etc.

Fire fighting of pool fires:

a) Fire-fighting on the FSRU shall be done using remote controlled monitors. Personnel should

not be exposed to the radiant heat. The fire monitors shall use a combination of water spray

and dry powder (Purple K) in combination that can extinguish jet fires and onboard pool fires.

b) High Expansion foam 500:1 from fixed installed Turbex foam generators shall be provided to

control on-water pool fires near the FSRU location.


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6. FSRU COMPONENTS

6.1 Regasification Plant

The regasification plant design is to be integrated with the FSRU‘s cargo handling, power generation,

general auxiliary, piping and control systems. CONTRACTOR shall provide and incorporate the

regasification systems as described in the regasification functional specification [2].

6.2 Flare System

A flare system is required to dispose of process vapours and liquids in the event of an emergency

from relief valves and blowdown systems. The flare system shall comply with API STD 521 and shall

be separate from the LNG tank vents (marine systems). CONTRACTOR shall provide and

incorporate the flare system systems as described in the regasification functional specification [2].

The height and size of the flare tower shall be determined by radiation modelling.


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7. MOORING SYSTEM

7.1 Jetty Mooring

CONTRACTOR shall upgrade or provide a new, safe and efficient mooring system to the FSRU

mounted on the starboard side of the FSRU. The mooring system shall comply with the vessels

Classification Society requirements.

Closed chocks, fairleads, roller pedestals and other mooring fittings shall be provided and located in

accordance with the mooring arrangements particularly suited for jetty mooring.

Typical jetty mooring arrangement shall include a minimum of 18 mooring lines on the starboard side

with a minimum 180-tonnes capacity, breakload per mooring line, with integral capstan; mooring

tension monitoring with local and remote release options.

The mooring line breaking load shall be determined using the mooring analysis results for the 10-YRP

condition, excluding hurricanes.

CONTRACTOR shall also provide mooring systems to enable a supply vessel to moor along the port

side of the FSRU.

7.2 Temporary Mooring

CONTRACTOR shall also provide temporary mooring systems so that the FSRU can be moored to

the outfitting quay at the shipyard on both the port and starboard sides. Temporary mooring

equipment should be designed for minimal or no maintenance or with a mothballing plan.

7.3 Functional Requirements

7.3.1 Mooring Equipment

The mooring equipment and fittings are to comply with appropriate standards as specified in the BOD

[1].

In case of conflicts between standards, the more onerous requirement shall be used.

In the case of a FSRU conversion, mooring winches can be retained and re-used if the brake and

drum capacity is suitable for the application, but shall be refurbished by CONTRACTOR. Additional

mooring winches shall be installed as necessary. Winch drive and remote control hydraulic systems

are to be drained of hydraulic oil and disposed of at shore facilities. Mooring winches including drive

units and reduction boxes are required to be taken onshore for overhaul as per manufacturer‘s

recommendation. CONTRACTOR shall test refurbished mooring winches and equipment onshore.

Mooring winches and equipment are to be re-installed with new fasteners and the hydraulic system

shall be flushed in accordance with ISO 23309:2007, flushing fluids contamination levels are to be as

per ISO 4406 17/15/12. Testing is to be carried out in the presence of Classification Society‘s

Surveyor and/or COMPANY.


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All refurbished deck mounted mooring equipment shall have surfaces of all rope bearing equipment to

be finished smooth with a 60 grit sanding disc. Following refurbishment of deck mounted equipment,

all equipment shall be first coated with an inorganic zinc silicate primer, and then painted with pure

epoxy hard coating to 250-μm.

7.3.2 Mooring Lines

CONTRACTOR shall provide mooring line stretchers with fittings when recommended by the Mooring

Analysis report, refer section 3.1 Motion Analysis.

In the case of a conversion, existing mooring rope shall not be retained and shall be removed and

disposed of appropriately.

7.3.3 Rope Reeler

CONTRACTOR shall provide a foot operated electric or pneumatic drum motor rope reeler which

shall safely store the mooring lines and the messenger lines when not in use. The rope reeler shall

meet the capacity requirements of the mooring lines.


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8. TESTING, PRE-COMMISSIONING AND COMMISSIONING IN SHIPYARD

8.1 General

Upon completion of refurbishment and conversion activities and/or new built activities for each

system, function testing, pre-commissioning and commissioning (without the introduction of nitrogen

or LNG) of all FSRU systems shall be conducted, irrespective whether they have been worked on

during the course of the repair. COMPANY and/or Classification Society shall witness and accept

function testing, pre-commissioning and commissioning works.

All function testing, pre-commissioning, and Commissioning procedures shall be prepared and

submitted to COMPANY for acceptance no later than two months prior to start of the applicable

activities.

All systems shall be function-tested, pre-commissioned, and commissioned on a system-by-system

basis. CONTRACTOR shall carry out all such trials, and shall be fully responsible for ensuring

attendance of Classification Society surveyor and/or Certifying Authority Surveyor, COMPANY

representatives and any other interested parties.

All skilled personnel, vendor personnel, and all equipment and materials required for performing the

testing, pre-commissioning and commissioning trials is to be provided by CONTRACTOR.

CONTRACTOR shall also provide all commissioning consumables to include but not be limited to

commissioning spares, replacement filters, necessary fuels, oils, water, hydraulic fluids and any other

fluids or parts required during testing, pre-commissioning and commissioning.

As and when systems are commissioned and accepted, these shall be clearly identified as to their

status, locked off, placed under care and maintenance and/or operated as necessary. All filters and

desiccant materials shall be renewed, and commissioning oils shall be drained and replaced with

normal operational oils.

LNG gas trails shall be performed in accordance with SIGTTO ―Guide for Planning Gas Trials for LNG

Vessels‖ [7]. All LNG operations shall follow guidelines and procedures as given in SIGTTO LNG

Operational Practice [6].

8.2 Testing and Pre-Commissioning

Testing and pre-commissioning shall be carried out on all new or modified systems, prior to the

energization or operation of any systems or equipment to prove that all work has been carried out

satisfactorily and that such systems are safe for energizing or operation.

Testing and pre-commissioning shall also be carried out on existing systems to prove that these have

not been compromised in the course of new work and to prove that they are in as-new condition.

Where tests form part of the requirements for Classification Society approval of the systems, and

hence are a pre-requisite for issue of the relevant certificates, Classification Society Surveyor shall


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witness tests. CONTRACTOR shall be fully liable for ensuring that Classification Society Surveyor

attends the tests and for obtaining the necessary approvals.

Before carrying out any testing, all systems shall be checked against the relevant design

documentation to ensure that they have been installed and connected correctly, and that equipment

and fittings have been tagged correctly.

Testing and pre-commissioning works shall be performed in accordance with the accepted Project

Execution Plan.

The results and records of all tests and pre-commissioning inspections shall be compiled into pre-

commissioning dossiers, for each structural item, for each piping system, and each

electrical/instrumentation system as appropriate. The format of the reports may be in accordance

with CONTRACTOR‘s normal formats, subject to the dossiers addressing the following:

a) Description of structure or system, as appropriate;

b) Copies of as-built fabrication drawings and/or diagrams, countersigned by CONTRACTOR,

Classification Society Surveyor and COMPANY certifying that the structure, piping system or

electrical/instrumentation system is installed in a satisfactory manner, is installed in accordance

with the design drawings and requirements, and that the as-built drawings correctly reflect the

as-built situation;

c) Test record sheets for each type of test, completed with test result details, and countersigned

by CONTRACTOR, Classification Society Surveyor and COMPANY; and

d) Calibration certificates for all test equipment used.

8.3 Commissioning

Upon satisfactory completion of pre-commissioning, including COMPANY‘s acceptance of the pre-

commissioning dossiers, commissioning trials shall be carried out to calibrate, test and prove the

operation of systems, plant and equipment.

For classed systems, the commissioning trials shall form part of the testing requirements for issue of

the relevant Classification Society certificates. The Classification Society Surveyor shall witness

these trials. CONTRACTOR shall be fully liable for ensuring that Classification Society Surveyor

attends the trials and for obtaining the necessary approvals.

Most FSRU‘s systems shall be commissioned using the actual service fluids. CONTRACTOR shall

commission the cargo transfer system using nitrogen. Dry out shall be done prior to cool down.

These systems shall be set up as far as practical in the shipyard, and then re-commissioned offshore

using LNG. (NOTE: tenderer to supply commissioning plan [TBABC 008])

The results and records of all commissioning trials shall be compiled into commissioning dossiers, for

each operational system. The format of the reports may be in accordance with CONTRACTOR‘s

normal formats, subject to the dossiers addressing the following:

a) Description of system;

b) List of all trials applicable to that system;


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c) Copies of trial procedure for each trial; and

d) Trial record sheets for each trial completed with recorded parameters and other pertinent

details, and countersigned by CONTRACTOR, subcontractors, Classification Society Surveyor

and/or COMPANY as appropriate.

8.4 Deadweight Survey/Stability Book

A deadweight survey on the FSRU shall commence when the repair, construction or conversion work

on the vessel is substantially complete. The deadweight survey shall include a measurement of the

"as surveyed" displacement and longitudinal center of gravity based on draft readings and specific

gravity measurement of the ambient water.

The timing of the deadweight survey shall be determined on the basis of the extent of outstanding

equipment and material still to be installed, and on the ability to accurately assess the weights and

final locations of such equipment or materials. No later than 30-days prior to the date of the survey,

CONTRACTOR shall submit its proposed survey plan detailing the preparations and procedures for

conducting the deadweight survey to both Classification Society and COMPANY [TBABC 009]. The

plan shall be approved by Classification Society and accepted by COMPANY.

Based on the results of the deadweight survey, the as-built lightship and center of gravity shall be

determined by CONTRACTOR. The as-built lightship weight shall be estimated with an allowance for

uncertainty to be accepted by COMPANY. This data shall be used as input data for the loading

computers and the trim and stability booklet.

8.5 Tank Hydrotests

Ballast and slop tanks, and fore and aft peak tanks shall be hydrotested after completion of all

structural and piping system modification and repair works. This testing shall form part of the test

program required for the completion of Classification Society special survey. At its discretion,

CONTRACTOR may elect to carry out its own hydrotest program prior to commencing repair and

modification work in order to identify any leaks or problems that would not otherwise be identified until

the above referenced special survey test program. However, any such additional testing shall be

deemed to be for CONTRACTOR‘s convenience and shall not be considered to be a substitute for the

final Classification Society hydrotests. COMPANY may waive the requirement for the final hydrotest

in favor of the preliminary test, subject to this preliminary test being acceptable and subject to

Classification Society agreement, in the event that no major steel renewal or structural modifications

are made in the course of the work.

Engine room tanks shall be hydrotested individually, taking account of the functions of each tank,

including any changes from storage tank to void space, or vice versa, as a result of the conversion.

Testing shall be in accordance with classification society requirements for storage tanks and void

spaces, as appropriate.

8.6 Tank Cool Down

The FSRU shall be towed into an anchorage or LNG terminal that is suitable to undertake cooling of

the tanks and gassing up. After all tanks have been cooled down, with the nitrogen system onboard,


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and gassed up with LNG provided from either the terminal or from a LNGC, moored side-by-side, one

tank shall be warmed up and gas freed. The warming up and gas freeing and aerating shall be

performed with the onboard systems to demonstrate functionality.

The latter shall be performed in a designated area where gas freeing operations are permissible in

close vicinity of the construction yard.


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9. CLASSIFICATION AND CERTIFICATION REQUIREMENTS

9.1 Certifying Authorities

CONTRACTOR shall identify all components or systems of the FSRU requiring certified tests and

inspections by recognized third party certifying agencies including Jamaican regulators. The test and

inspection agencies used shall be internationally recognized as providers of the applicable

certification services.

9.2 Completion of Current Special Survey

CONTRACTOR shall complete all structural and mechanical surveys and tests required to complete

the current Special Survey of the FSRU, and also complete all surveys for SOLAS, MARPOL and

Load Line certification, prior to the FSRU leaving the shipyard.

9.3 Certification Requirements

On completion of the repair, life extension, construction or conversion, pre-commissioning and

commissioning work, CONTRACTOR shall obtain and collate all certification required by legislation

and Class rules and regulations, for Classification of the FSRU. All certificates shall be issued before

departure of the FSRU from the shipyard.

The FSRU facility shall be designed, constructed, installed and surveyed in compliance with the DNV

―Rules for Classification of LNG/LPG Floating Production and Storage Units or Installations‖, DNV-

OSS-103 or equivalent.

a) The candidate vessel for conversion must have been built to an IACS members rules for

vessels intended to carry Liquefied Gases in Bulk and to IMO International Code for the

Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (IGC Code)

requirements.

b) The new build FSRU shall be built to an IACS members rules for vessels intended to carry

Liquefied Gases in Bulk and to IMO International Code for the Construction and Equipment of

Ships Carrying Liquefied Gases in Bulk (IGC Code) requirements.

In addition to the certification required for the vessel to operate as a specialized fully refrigerated gas

carrier for hull, machinery and cargo systems, the facility shall typically have the following DNV main

Classification Society notation, or equivalent IACS Classification Society notation2:

() Floating Offshore LNG Re-gasification and Storage Terminal COAT-2 ECO BIS CSA-2 CRANE

POSMOOR

In addition, the following symbols shall be placed after the above main Classification Society notion:

2 The alternative classification society shall be selected depending on the current Classification

Society classing the LNGC vessel and selected by CONTRACTOR to class the FSRU.


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a) DNV CSA-FLS (Spectral Fatigue Analysis based on 60 year, or IACS equivalent;

b) DNV CAP 1 (Condition Assessment Program Level 1, for structural, Machinery and Cargo

Systems), or ABS equivalent.

The FSRU shall perform ―In service‖ continuous hull and machinery surveys after installation and

commissioning, as required for the maintenance of Classification Society.

Surveys Schedule shall be based on DNV, or IACS Classification Society equivalent Preventive

Planned Maintenance and Continuous Machinery and Hull Survey programs to maintain the above

Classification designation.

During the CAP-1 (condition assessment program) evaluation, CONTRACTOR shall use the same

reference standards for the assessment of the cargo piping condition (corrosion allowances,

scantlings etc.) as the ones in effect for the structural part.

CONTRACTOR shall obtain a statement from Classification Society endorsing the condition of the

FSRU at the start of the operations on site as adequate for extended operations for the design life

without dry-docking.

CONTRACTOR shall copy COMPANY on all correspondence between CONTRACTOR and

Classification Society within one week of documents issuance.


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10. PROVISIONAL ACCEPTANCE

The FSRU shall be deemed to be provisionally accepted when the following activities are

satisfactorily completed:

a) Completion of testing, pre-commissioning and commissioning activities;

b) Issue of pre-commissioning dossiers and commissioning dossiers to COMPANY;

c) Review by COMPANY of Classification Society certificates;

d) Acceptance of transit and installation procedures and plans; and

e) General visual inspections of the FSRU to identify and record any damage and/or defect arising

after pre-commissioning.

Upon completion of these activities to COMPANY‘s satisfaction, COMPANY shall issue a Provisional

Acceptance Certificate certifying completion. However, providing COMPANY may, at its discretion,

allow CONTRACTOR to complete specified items of a non-critical nature later, but before mechanical

completion. The FSRU is not permitted to leave from the shipyard before receipt of COMPANY‘s

Provisional Acceptance Certificate.


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11. FSRU TRANSIT TO JETTY MOORING

11.1 General

The FSRU shall travel to the jetty mooring under its own power. CONTRACTOR shall be fully

responsible for all personnel, equipment, facilities, marine vessels and support required for the transit

of the FSRU to the jetty mooring. All marine operations shall comply with the guidelines of

COMPANY‘s Marine Warranty Surveyor.

CONTRACTOR shall be fully responsible for all transit arrangements and procedures, including

provision of all necessary approvals and port clearances, and contracting of tugs and other support

facilities required.

All inspections required by the classification society and COMPANY‘s Marine Warranty Surveyor for

the transit and connection works are to be conducted by CONTRACTOR. CONTRACTOR shall be

also responsible for identifying the scope of inspections and for ensuring that Classification Society

Surveyor and COMPANY‘s Marine Warranty Surveyor attend and approve all such inspections.

11.2 Preparation for Voyage

The following transit and installation procedures for the FSRU shall be prepared:

a) Issuing of daily reports;

b) Weather forecasting, monitoring, and route survey;

c) Crewing and watchkeeping;

d) Transit condition, and deballasting for connection;

e) Procedures for connecting mooring system to the FSRU, including specifications for support

vessels and facilities;

f) Procedures for deploying and connecting the jetty loading arms, including specifications for

support vessels and facilities;

g) Test and commissioning procedures, mechanical completion tests and acceptance tests.

The following emergency response and contingency plans shall be prepared:

a) Weather deterioration and re-routing;

b) Medical emergencies;

c) Person overboard; and

d) Piracy.

These procedures and plans shall be approved by Classification Society and/or COMPANY‘s Marine

Warranty Surveyor at least three months before the scheduled provisional acceptance date, and shall

be submitted to COMPANY for acceptance at least two months before transit. The Provisional


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Acceptance Certificate will not be issued until all procedures and plans are so approved and

accepted.

All applicable system storage tanks on the FSRU shall be safe for the subsequent introduction of LNG

before departure from shipyard.

All potable water tanks shall be chlorinated after completion of all related works. Potable water piping

shall be flushed through with the chlorinated water until tests demonstrate that the potable water

systems are within acceptable levels of contamination. Hygiene certificates shall be issued by an

approved certifying agency. Chlorinated water shall be drained from the tanks and piping, flushed

through with potable water, and refilled with potable water.

All drawings, system diagrams, design documentation, data books, instruction manuals, operation

manuals, statutory manuals, pre-commissioning dossiers, and commissioning dossiers shall be made

available on board the FSRU before its departure from the shipyard. Drawings and certificates shall

be displayed on the FSRU in an approved manner.

The FSRU shall be ballasted to the approved departure condition, and tank soundings taken to

confirm the correct status of all tanks. All personal safety gear, life saving appliances, and navigation

lights shall be explicitly verified as being present and operational immediately before the vessel‘s

departure from the shipyard. All necessary bunkers, provisions and consumables shall be loaded and

checked for correct and safe stowage.

All involved personnel, ashore and afloat, are aware of emergency contacts and contingency plans,

and that offshore personnel have current offshore survival certificates. All offshore personnel shall be

assigned muster stations and lifeboats before departure, and up-to-date station bills shall be posted.

Lifeboat and lifejacket drills shall be conducted before departure.

CONTRACTOR shall ensure that the weather forecast for the duration of the voyage to site and for

the subsequent offshore operations is acceptable. All transit routes are ensured to be acceptable,

and agreed by all parties.

CONTRACTOR shall load the following stores onto the FSRU before its departure from the shipyard:

a) Spare parts requirements for each item of machinery or equipment

b) All conventional hand and power tools required to carry out maintenance and adjustment tasks

on each item of machinery or equipment, as defined in the manufacturer‘s documentation;

c) Special non-standard tools specified by machinery and equipment manufacturer‘s for certain

maintenance or adjustment tasks on their equipment;

d) Medical stores in accordance with Classification Society and Flag State requirements;

e) Full outfit of stewards stores, crockery and cutlery; and

f) Victuals for the duration of the transit, plus one month's operation with the full complement.

The FSRU shall be bunkered with the first load of fuel, lube oil and potable water. This shall be

defined as:

a) Fuel service and settling tanks - Sufficient fuel for the transit and for the period to mechanical

completion, plus fuel for hotel load to cover the period between mechanical completion and


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receipt of first oil, plus a 10% allowance for weather delays, including fuel in lines from filling

connections and to each diesel engine;

b) Potable water tanks - 100% including water in lines from filling connections and to hydrophore.

Hydrophore to be filled to operating level;

c) Lube oil - All diesel engines and turbine sump tanks full to the maximum operating level, and

sufficient additional oil in the lube oil storage tanks to cover projected consumption for the

same duration and operational profile as defined above for fuel.

Preparation of the FSRU for the transit shall be inspected and approved by Classification Society and

COMPANY‘s Marine Warranty Surveyor, immediately before departure.

11.3 Transit Voyage

The jetty installation and connection works shall be confirmed to be progressing on schedule before

commencing the transit of the FSRU.

For the duration of the voyage, CONTRACTOR shall maintain all watchkeeping and safety

procedures in accordance with accepted procedures.

CONTRACTOR may commence inerting all reception and cargo during the voyage such that the

nitrogen levels in the tanks is acceptable for the introduction of LNG at the time of arrival.

11.4 Arrival at Worksite

Upon arrival of FSRU at the jetty mooring, the vessel shall be deballasted as required to its

installation draft and trim. The FSRU shall maintain station in the designated temporary anchorage

area until cleared for connection to the mooring system. CONTRACTOR shall allow for the FSRU to

steam in a holding pattern in the anchorage area rather than anchoring, as it is expected that the

vessel‘s anchor will not permit more than one anchoring operation.


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12. NEAR-SHORE COMMISSIONING

12.1 General

As already noted, all commissioning work shall be completed in the shipyard before transit, leaving

only site specific commissioning to be carried out at the jetty mooring. Site specific commissioning

shall be deemed to be those trials requiring the use of LNG, and those requiring to be proven under

actual operational conditions.

Commissioning shall be carried out after connection of the FSRU to the mooring system.

12.2 Mooring System Commissioning

Upon completion of the flushing and testing of the pipeline, CONTRACTOR shall commission the

mooring system.

CONTRACTOR shall develop offshore commissioning procedures for the mooring system during the

detailed engineering phase in conjunction with its mooring subcontractor.

12.3 Installation Pressure Test

Although the jetty loading arms and FSRU piping has been pressure tested during fabrication, a

further leak test shall be carried out to verify that there has been no compromise of the systems

during deployment and connection, to verify all new connections and to verify integrity of the transfer

system piping.

The offshore pipeline shall be hydrotested in accordance the designated code DNV-OS-F101.

12.4 Testing and Set-up of FSRU Interfaces

Remote telemetry systems for the mooring system, including interfaces between the remote telemetry

system and the FSRU‘s fire and gas system and ESD System, shall be set-up and commissioned

after the FSRU is connected. The manufacturer‘s equipment set-up and commissioning procedures

shall be used as a basis. CONTRACTOR shall develop these into the formal test and commissioning

procedure to be used offshore.

12.5 Testing and Set-up of Communications

The various radios, telephone links, and satellite communications installed on the FSRU shall be set-

up and commissioned after the FSRU is connected.

12.6 Testing of Marine Systems

All marine operational systems shall be tested, and set-up/adjusted as required, in the actual

operational environment, after the FSRU is connected. These shall include the following:

a) Power Generation


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b) Ballast Water Systems

c) Sewage (Grey and Black water systems)

d) HVAC Systems

e) Cooling water systems

f) Fresh water generators;

g) Inert gas generators;

h) Main deck foam system (with foam);

i) Deck cranes;

j) Foghorn;

k) Lifeboats and davits;

l) Rescue boat and davit; and

m) ICCP system.

Where required by Classification Society, these tests and adjustments shall be witnessed and

approved by Classification Society Surveyor.


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13. MECHANICAL COMPLETION

CONTRACTOR shall present the FSRU for mechanical completion to verify the FSRU utility and

cargo systems are operating satisfactorily.

Mechanical completion trials shall comprise the following activities:

Safety Trials

a) Demonstration that all ESD buttons and ESD shutdowns operate as designed;

b) Simulation of emergency situations, by injecting alarm signals into the ESD panel and fire and

gas panel, and demonstration that all alarms and trips operate as designed; and

c) Demonstrations that power generator safety and breaker trips all operate as designed.

Communications

Proper operation of all radios, telephones and satellite links shall be demonstrated to COMPANY,

including proving of communications between the FSRU and marine vessels, and ORF.

Operational Endurance Trial

Upon completion of the safety trials referenced above, CONTRACTOR shall demonstrate that the

FSRU is able to operate continuously for a period of 72-hours, with all equipment and machinery

operating within their manufacturer‘s design parameters.

Certification

The FSRU and mooring system shall be certified as being mechanically complete upon satisfactory

completion of the following activities:

a) Offshore commissioning activities;

b) Safety Trials;

c) Communications Trials;

d) Operational Endurance Trial; and

e) Visual inspection of FSRU, mooring system and ORF to identify and record any damage and/or

defect arising during the offshore operations.

At this point, ORF shall be operated up to allow the export gas to pass into the ORF.

CONTRACTOR shall remove the treated water from the pipelines and dispose of in accordance with

a dewatering procedure that meets the environmental criteria of the relevant approving authority and

its agencies as outlined in the line pipe specification [2].

CONTRACTOR‘s personnel shall be responsible for directing the FSRU operations crew during the

dewatering operations. CONTRACTOR shall be responsible for disposal of the displaced water.


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14. ACCEPTANCE

14.1 Final Offshore Commissioning

Once LNG has been received in the cargo tanks, the cargo pumps shall be re-commissioned using

cargo LNG as the pumped fluid, operational set-points re-calibrated, and the performance parameters

verified against the design performance requirements.

14.2 Trials

CONTRACTOR shall present the FSRU for acceptance when CONTRACTOR is satisfied that the

FSRU vessel utility and cargo systems are operating satisfactorily.

Acceptance trials shall comprise the following activities:

Operational Trial of Offloading System

At this point, the inlet valving located at the ORF will be opened up to allow the export gas to pass

into the ORF. During the flow of the export gas, the export gas pipeline shall be dewatered using a

suitable pig pushed through the pipeline by nitrogen or compressed dry air. Refer to line pipe

specification [2] for further details.

Cargo System Acceptance

The FSRU system shall be operationally proven by continuously pumping LNG from one cargo tank

to another for a period of 6-hours. As a minimum, CONTRACTOR shall record the following

parameters on an hourly basis during the trial:

a) Power and current requirements (if applicable);

b) Motor and pump temperatures;

c) Transfer flow rates tank levels;

d) Minimum suction level at full pump speed;

e) Minimum practical suction level.

CONTRACTOR shall also demonstrate all operational and safety trips and emergency stops.

Regasification System Acceptance

Regasification System acceptance test are to be developed by CONTRACTOR for approval by the

COMPANY, the acceptance test shall include, but shall be limited to the following tests:

The Regasification system shall be proven to operate at a regasification capacity of as detailed in the

BOD [1] for a duration of 12-hours and at 10% capacity for 12-hours. Each individual train shall be

ramped up and down from 10% capacity to 100% capacity. The change over between trains and

changing of capacity shall not result in any interruption of the gas supply or venting/flaring of vapour.

CONTRACTOR shall record the following parameters on an hourly basis during the trial:


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a) Power and current requirements (if applicable);

b) Motor and pump temperatures;

c) Transfer flow rates LNG to NG

d) Transfer flow rates Glycol (if applicable)

e) NG temperature at FSRU export flange

f) Glycol temperature at inlet and outlet of STV (if applicable)

g) Seawater temperature at inlet and outlet FSRU

h) Fuel gas system pressure and temperature at fuel gas heater inlet and outlet

i) Pressure gauges at boil-off gas compressor and HD and LD compressors

j) During this trial noise and vibration measurements are to be taken in accordance with the noise

and vibration standards.

k) The flare system shall be tested by initiating an emergency shut down with one train operating

at 25%

l) Seawater pump flow rate and pressure

Certification

The FSRU, mooring system and pipeline shall be certified as being accepted upon satisfactory

completion of the above two sets of trials.


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15. AS-BUILT INFORMATION

Upon completion of mechanical completion trials of the FSRU, as-built documentation shall be

prepared in accordance with the requirements of the project execution plan. These documents shall

include but not be limited to:

a) Project control dossiers (project close-out report, baseline and as-built schedules, change order

records, safety records, document registers, procurement registers, etc);

b) Overall FSRU operations and maintenance manual;

c) Final issues of engineering documentation (drawings, calculations, procedures, specifications,

etc.);

d) As-built fabrication drawings;

e) Vendor data books for equipment, fittings, components (unpriced purchase orders, drawings,

certificates, data sheets, QA/QC records, operating and maintenance manuals, spare parts lists

and codes, etc.);

f) Material dossiers for structural work (mill certificates, weld and welder qualification records,

weld procedures, weld maps, traceability reports, NDE reports, acceptance certificates, etc.);

g) Material dossiers for piping work (mill certificates, weld and welder qualification records, weld

procedures, weld maps, traceability reports, NDE reports, acceptance certificates, etc.);

h) Material dossiers for electrical work (cable and fittings certificates, continuity and insulation

reports, acceptance certificates, etc.);

i) Punch lists, test records, acceptance certificates);

j) Installation report;

k) Mechanical completion dossier.


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16. NEW BUILD ENGINEERING DESIGN REQUIREMENTS

16.1 General

This section addresses the general requirements associated with the new build FSRU options in

addition to the requirements as given in sections 2 to 15.

16.2 Hull

16.2.1 Hull Design

The FSRU shall have an all welded steel hull designed by a shipbuilder experienced with the

construction of LNG carrier hulls supporting LNG cargo tanks. The vessel shall be built with a single

deck.

All structural design and scantlings shall be in accordance with Classification Society requirements

and shall make use of state-of-the art design techniques including finite element structural analysis &

spectral fatigue calculations. Bending moments, shear and other loads shall be calculated for the full

range of loaded and ballasted conditions. Particular care shall be taken to properly analyze tank and

tank-hull interaction structural and fatigue effects. Structural continuity throughout the unit shall be

maintained as much as possible.

Intact and damaged stability shall be calculated for the same range of loading conditions.

Ballast tanks and system shall be designed to maintain trim as well as a constant draft from no cargo

through fully loaded and any in between cargo tank filling condition.

16.2.2 Bow & Stern Design

The bow and stern shall be shaped to avoid excessive mooring forces. The bow in particular and the

entire FSRU in general, must be designed to ensure green water problems remain

acceptable/manageable, even under extreme storm conditions. It is not expected that the problem be

eliminated, however green water should not occur during normal operating conditions (less than 10-

year conditions), and under extreme storm conditions must remain manageable.

The bow, stern, side and possibly bottom structural surfaces of the FSRU shall need to be designed

against hydrodynamic slam forces. The probability of the hull bottom clearing the water surface

whether at the bow or the stern under extreme sea states shall need to be checked. Any part likely to

emerge at or below design conditions shall need to be appropriately designed for slamming forces.

16.2.3 Hull Materials

Given the extended design and fatigue life requirements, the hull shall preferably be designed from

mild steel. Highly stressed areas such as the upper deck, as well as part of the inner hull in the tank

area may require high strength (HT) steel.


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Steel selection for structural steel directly facing or exposed to LNG tanks or exposed to process

equipment containing LNG shall be in accordance with the requirements of the IGC code with respect

to significant service temperature.

The ambient temperatures shall be as detailed in the BOD [1].

16.2.4 Surface Preparations, Coatings and Material Protection

All new or renewed structure free edges shall comprise of beveling edges with 45° angle to provide a

good surface for coating. All structural steel plates and sections shall be grit-blasted to SA 2½ and

immediately primed using a compatible shop primer (except sea water ballast tanks) before

fabrication commences.

Seawater ballast & slop tanks shall be 100% coated with a light colored, epoxy, non coal-tar system.

Coating shall be tested, selected and applied in accordance with TSCF Guidelines for Ballast Tank

Coating System and Surface Preparation to a design life of the FSRU.

Aluminum or Zinc Alloy sacrificial anodes shall be used in all ballast and slop tanks. Mountings shall

be bolted to allow for replacement in service.

The lifetime of the corrosion protection system for the outside shell shall be equivalent to the design

life of the FSRU. The corrosion protection shall include a combination of non-toxic paint, anodes and

impressed current. Sacrificial anodes shall be used in all sea chests. The material

protection/cathodic protection system used on the FSRU vessel must be compatible with the

protection systems of any adjoining structures.

The outside of the hull shall be 100% coated with a non toxic, not excessively bio-hazardous, but long

lasting light colored coating system capable of protecting the hull for the design life. A non–tin, low

cost, anti-fouling coating shall be required on the hull. However, a high performance system shall be

required around openings, intakes, and outlets, and wherever markings for in-situ inspection are

applied. Refer to Appendix 2 - Coatings for Structures, Piping and Equipment for the details of the

subject requirements.

16.2.5 Miscellaneous Hull Work

Tank hatches are to be provided for all under deck ballast and slop tanks. Hatch covers must be able

to be locked out in the open position when required. All tanks that contain submerged pumping

equipment must be equipped with access hatches or openings that shall facilitate easy and rapid

maintenance/change-out of pumps etc.

A sufficient number of manholes are to be installed for access and ventilation to all cofferdams, below

deck ballast, bunker and freshwater tanks.

All tanks shall be fitted with sufficient ladders and walkways to enable structural inspection for special

surveys without the need for stage erecting in tanks or rafting.

16.2.6 Sea Chests

A low and a high sea chest or trunks are to be provided as required. The sea chest grids are to be

designed to facilitate underwater inspection. Watertight cover plates fabricated from materials that


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shall give neutral buoyancy together with securing devices are to be provided for diver installation.

Sea chests shall be equipped with duplex strainers and filters/strainers shall be back-washable. Low

sea suctions are required to ensure proper submersion of sea chest under all but the worst weather

conditions. All sea chest pipe connections shall be via high integrity gate valves, or equivalent, to

avoid risk of leakage and/or flooding. In addition the sea chests shall be equipped with a remote

hydraulic emergency ship side valve shut off system. A blow out facility is to be provided to be able to

clean out the sea chest from debris.

16.2.7 Markings

In addition to typical classification waterline/draft markings, the vessel‘s wetted hull area is to be

provided with markings to enable in-situ underwater surveys to be carried out in lieu of dry-docking.

These markings shall identify the location of all tank boundaries, and shall comply with Classification

Society‘s requirements in this respect. These markings must be as durable as the in water life of the

hull and shall typically consist of anti-fouling painted surfaces.

16.3 LNG Storage Tanks

16.3.1 Moss Sphere

Storage shall consist of a minimum of four spherical aluminum cargo tanks with a total storage

volume as specified in the BOD [1]. The cargo tanks are to be designed to the maximum pressure

permissible for this type of tank as given by the IMO IGC code, and built as independent type B tanks,

in accordance with the IMO IGC Code. These tanks consist basically of a single wall, insulated

spherical tank, supported by a vertical skirt, connected to the tank around the equator periphery. The

cargo tank material shall be aluminum alloy. Maximum allowable cargo density shall be 0.5-

tonnes/m³.

Each cargo tank shall be located in a separate cargo TBABC with the tank skirt mounted directly on

the foundation deck. The tanks shall be protected above deck by separate tank covers. The

supporting skirt consists of three kinds of materials. The upper part shall be made of aluminum alloy,

the middle part of stainless steel and the lower part of low temperature high tensile steel. The upper

part shall be stiffened by ring web stiffeners and the lower part by vertical stiffeners.

The tank concept is based on the ―leak before failure‖ principle with implementation of a partial

secondary barrier as required by the regulations. A small leak protection system shall be applied to

prevent liquid cargo from coming into direct contact with hull structural members. Each cargo TBABC

shall also be provided with a stainless steel drip pan placed beneath the lowest point of the insulation.

The drip pan shall be insulated with polyurethane foam to prevent the temperature of the inner bottom

to reach an unacceptable level in situations when the pan is filled with LNG. In order to be

considered a part of the tank‘s secondary barrier, the insulation system shall conduct any leaked LNG

from a cargo tank to the associated drip pan through drain lines. A drain eductor line from the drip

pan should be installed leading from the drip pan to the LNG emergency eductor piping system.

The spherical tank dome covering with an A-60 fire-rating and designed for explosion over-pressure

shall be provided. Fire rating off all areas adjacent to the regasification plant shall be J-60.


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The cargo tank and the upper part of the skirt shall be thermally insulated to achieve a specified

maximum boil-off rate of 0.12% per day. Rigid plastic foam with closed cells of polystyrene,

polyurethane or similar shall be used. The insulation panels shall be constructed with inserts of

flexible parts and glass clothes to absorb the tank‘s deflections during thermal and load cycling. The

insulation panels shall be sheeted with an impervious heavy aluminum foil and shall also serve as

partial secondary barrier for the cargo tanks. The insulation to be attached to the tank surface with

designers/manufacturer‘s recommended material for hardware to minimize stresses in the insulation

material. Functionally equivalent systems like e.g. spiral generation shall be acceptable. In order to

limit the temperature gradient in the skirt as well as to reduce heat flux through the skirt‘s surface, the

upper part of the skirt shall also be insulated on both inside and outside using similar materials as

described for the tanks.

One pipe tower made of aluminum alloy shall be provided in each tank. The cargo pipelines, custody

transfer equipment, etc. as well as access ladder with grated platform landing shall be fitted inside the

tower. The pipe tower shall have adequate strength to resist sloshing loads due to partial filling of

cargo and ship motion.

For the FSRU, one dismountable inspection boom set with suitable means of safely moving and

deploying for internal tank inspection shall be provided. Boom parts to be stored in a container in

suitable space on deck.

Manholes shall be fitted on top of each cargo tank dome for access to each tank. The manholes shall

be designed to withstand the maximum allowable working pressure. Size of hatch shall be at least

1000 x 1000-mm.

Each tank shall have a radar type (control and indication) plus either a capacitance type or diverse

type of radar shutdown and level indication system.

Each cargo tank shall have:

a) One dome with a manhole, pipe and instrumentation connections

b) Dome connections:

i) Two discharge lines, (for LNG send out);

ii) One LNG filling line, bottom fill;

iii) One NG vapour return/boil off line;

iv) One LNG spray pump discharge line;

v) One LNG spray pump return line;

vi) Three fixed tubes for sampling of cargo;

vii) Three groups of LNG spray lines for tank cooling purposes;

viii) Appropriate number of safety relief valves and vacuum relief valves;

ix) LNG stripping line – The stripping line shall allow for less than 1.5% cargo volume

stripping.


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16.3.2 SPB

Storage shall consist of a minimum of four prismatic aluminium alloy cargo tanks, built as independent

type B tanks, in accordance with the IMO IGC Code with a total storage volume as specified in the

BOD [1]. These tanks consist basically of a single wall, insulated prismatic tank, strengthened by

internal horizontal platforms and stiffening plates. The cargo tank material shall be aluminium alloy.

Maximum allowable cargo density is detailed in the BOD [1].

Maximum design pressure shall be in accordance with IMO IGC Code. The maximum pressure

permissible by the rules shall be used.

Each cargo tank shall be located in a separate cargo TBABC with the tank support mounted directly

on the double hull. The tanks shall be protected from above by the main deck. The top of the SPB

tanks shall be supported by an anti-rolling chock centrally located and anti-flotation chocks positioned

closer to the outer edges of the tank.

The tank concept is based on the ―leak before failure‖ principle with implementation of a partial

secondary barrier as required by the regulations. A small leak protection system shall be applied to

prevent liquid cargo from coming into direct contact with hull structural members. In order to be

considered a part of the tank‘s secondary barrier, the insulation system shall conduct any leaked LNG

from a cargo tank to the associated drip pan through drain lines. A drain eductor line from the drip

pan should be installed leading from the drip pan to the LNG emergency eductor piping system.

The tank dome covering with an A-60 fire-rating and designed for explosion over-pressure shall be

provided. Fire rating off all areas adjacent to the regasification plant shall be J-60.

The cargo tank shall be thermally insulated to achieve a specified maximum boil-off rate of 0.12% per

day. Rigid plastic foam with closed cells of polystyrene, polyurethane or similar shall be used. The

insulation panels shall be constructed with inserts of flexible parts and glass clothes to absorb the

tank‘s deflections during thermal and load cycling. The insulation panels shall be sheeted with an

impervious heavy aluminium foil and shall also serve as partial secondary barrier for the cargo tanks.

The insulation to be attached to the tank surface with designers/manufacturer‘s recommended

material for hardware to minimize stresses in the insulation material. Functionally equivalent systems

like e.g. spiral generation will be acceptable.

One pipe tower made of aluminium alloy shall be provided in each tank. The cargo pipelines, custody

transfer equipment, etc. as well as access ladder with grated platform landing shall be fitted inside the

tower. The pipe tower shall have adequate strength to resist sloshing loads due to partial filling of

cargo and ship motion.

The inner parts of the tank shall be outfitted with ladders and hand rails to facilitate tank inspections in

situ without the need for scaffolding.

Manholes shall be fitted for access on top of each cargo tank. The manholes shall be designed to

withstand the maximum allowable working pressure. Size of hatch shall be at least 1000 x1000-mm.

Each tank shall have a radar type (control and indication) plus either a capacitance type or diverse

type of radar shutdown and level indication system.

Each cargo tank shall have:


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a) One pipe tower fitted with manhole, pipe and instrumentation connections

b) Pipe Tower connections:

i) Two discharge lines, (for LNG send out);

ii) One LNG filling line, bottom fill;

iii) One NG vapour return/boil off line;

iv) One LNG spray pump discharge line;

v) One LNG spray pump return line;

vi) Three fixed tubes for sampling of cargo;

vii) Three groups of LNG spray lines for tank cooling purposes;

viii) Appropriate number of safety relief valves and vacuum relief valves; and

ix) LNG stripping line – The stripping line shall allow for less than 1.5% cargo volume

stripping.

16.3.3 Membrane Tanks

Membrane systems, which are classified as IMO type integrated tank systems, are permissible, if the

CONTRACTOR can demonstrate the following:

a) The containment system is a super reinforced GT NO 96 system with the primary and

secondary barrier made of minimum thickness of 0.7-mm INVAR;

b) The Containments system shall comprise super reinforced insulation boxes. The boxes used

shall have a minimum ultimate buckling strength of 15-bar, over a surface area of 1-m² and a

minimum ultimate buckling strength of 20-bar over a surface area of 0.16-m² (GTT thresTBABC

values for super reinforced GT No 96 insulation boxes) and shall be capable of sustaining the

sloshing pressure as assessed at item f) below;

c) The CONTRACTOR provides a cargo management procedure to avoid or minimize partial tank

filling levels;

d) The proposed LNG carrier shall comprise a centre line bulkhead;

e) The CONTRACTOR undertakes a sloshing analysis for the location to assess critical tank filling

levels and assess sloshing pressures for critical partial tank filling levels for exposure duration

of not less than 5-years;

f) A long term approach for the sloshing analysis shall be used. The long term‘s aim is to take

into account all the conditions the FSRU is supposed to face during the design life on station.

This shall lead to a statistical distribution which is representative of the ship‘s life profile, i.e.

Condition = f (sea state, heading, filling level, draught);

g) The CONTRACTOR shall prepare an on site tank inspection and repair procedure for approval

by COMPANY; and


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h) The CONTRACTOR shall also develop an internal containment system scaffolding system that

can be installed on site and can sustain all inspection and repair loads. The scaffolding system

is to be able to survive the vessel motion and acceleration resulting from a 100-year

environmental return condition during installation and fully installed. The scaffolding system

shall be approved by the classification society and shall be subject to approval by COMPANY.

16.4 LNG Cargo Containment and Transfer

16.4.1 General

The loading system shall be designed for jetty based LNG/NG transfer within a maximum 16-hour

period against a backpressure defined by the least favorable level differential between the LNG

Carrier and the FSRU. This loading and mooring arrangement set shall be installed on the starboard

side of the FSRU only. This loading system shall be designed to remain operational under loading

conditions defined in the BOD [1]. A one day turn around is assumed for common LNG Carriers while

at the FSRU site. Hence the system must be designed to load a nominal 157,000-m³ cargo in 16-

hours of cargo pumping time. Refer also to the Jetty Specification [1].

16.4.2 Boil Off Gas Return

The boil-off gas (BOG) from the cargo tanks shall be sent to the LP boil off gas compressor located in

the process plant area. The boil off gas shall be used for fuel gas, re-injected into the LNG at the

suction of the LNG booster pumps or sent out as product delivery into the pipeline. The boil-off gas

from the loading is returned to the LNGC storage tanks via the vapour return line or sent to the LP boil

off gas compressor.

16.4.3 LNG Cargo Transfer System

The cargo pump system shall include one duty and one standby submersible cryogenic pump for

each storage tank and also designed for continuous operation.

Pumps shall be vertical, retractable, and centrifugal, with inducer stage to be located in cylindrical well

with foot valve of proven design. Pump drive shall be integral, submerged electrical motor. The

pumps shall be supplied with a comprehensive operating, control and alarm system integrated with

the FSRU cargo handling and shutdown systems.

The associated on board transfer piping shall be supported and arranged for minimum stresses due

to thermal loads and hull girder flexing, and shall be insulated to normal cryogenic LNG piping

standards. Valves shall be of cryogenic butterfly type. Insulation shall be of pre-formed closed cell

type covered with a water vapour barrier and mechanical protection layer.

16.5 Power Generation and Electrical Systems

16.5.1 General Power Generation Equipment

An electrical power generation system shall be provided which shall provide power to the entire FSRU

including regasification plant, storage and cargo system, accommodation, control and marine systems


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under all normal operating circumstances. This system shall be configured with N+1 redundancy, so

that field operations are not compromised if the largest generating unit is out of service. The

generating system shall also include emergency generator capacity that shall be independent of the

main generator system. The emergency generator(s) shall meet the demand of the essential loads

including loads necessary for the safe and economic preservation of the FSRU systems, and hotel

services and comply with statutory requirements. In addition, the FSRU must be capable of a black

start with main power generation shut down and in the absence of fuel gas. The generating system

shall be able to operate in a stable manner with sudden variations in load and for extended periods of

time at reduced load.

Main generation shall be located at the stern. Generation voltage shall be 6.6-kilovolts (kV).

However there shall be an aft and a fore switchroom each of which shall have a 3 phase 6.6-kV MCC

& distribution and a 3 phase 480-V MCC & distribution. The stern shall have a 480-V Emergency

Generator and a 2 phase 230-V switchboard. The aft switchroom shall be located in the machinery

space near the actual generators. The fore switchroom shall be located in an electrical room located

below the fore process deck. Major motors shall run at 6.6-kV whilst smaller units shall use 480 and

230-Vs as appropriate. All generating frequencies shall be 50-Hz.

The entire power generation system shall be remote controlled from the FSRU central control room

located in the accommodation block. Machinery space shall be designed as unmanned machinery

space.

16.5.2 Fuel System

Under normal circumstances power generation shall consume boil-of-gas (BOG) treated by the fuel

gas skid and delivered at typically 70-psig (this value is system dependent). However, under start-up

or special maintenance repair circumstances as well as under emergency conditions gas may not be

available or not accessible. Therefore, at least one of the main generators shall be dual fueled MDO

& gas. Emergency and stand-by generator shall be MDO.

16.5.3 Electrical Equipment Summary & Performance

The following major items of electrical equipment are to be installed:

a) 4 x 5500-kW, 6.6-kV gas fuelled engine generators, with at least one as dual fuel equipped for

MDO as well. The power capacity is indicative and is to be confirmed by detailed load analysis

by CONTRACTOR;

b) Power Management System for controlling start-ups, distribution, monitoring and fault handling.

This system shall be able to automatically shed loads and start/stop various generating units in

order to maintain a reliable power supply;

c) One x 1500-kW, 480-V Diesel Engine Emergency Generator. The power capacity is indicative

and is to be confirmed by detailed load analysis by CONTRACTOR;

d) Separate after & fore switch rooms with transformers, switchgear etc.;

e) UPS supply for uninterruptible loads for a minimum of 18 – 24-hours in line with SOLAS

requirement;


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f) DC battery backed supply for control and communication loads for a minimum of 24-hours;

g) Lighting systems;

h) Grounding system;

i) Navaids; and

j) Impressed current protection system.

The electrical design and installation of electrical equipment, cables and fittings shall be based on

applicable classification society rules. All the required motor control centres, substations, cabling and

lighting systems shall be arranged in accordance with applicable regulations regarding standards,

protection, insulation and general safety. Switchrooms shall be properly pressurized and air

conditioned.

Lighting shall maximize the utilization of floodlighting to minimize fixture numbers and maintenance.

Lamps shall be HPS to provide high lumen output with minimum power consumption whilst achieving

acceptable colour rendition. Emergency lighting shall use battery-backed fluorescent fixtures in

egress pathways and quick-re-strike HPS in floodlit areas.

All electrical equipment within gas-dangerous zones shall be designed, installed and supplied with

certificates to show that it is rated for hazardous area conditions. All electrical systems shall be

designed in accordance with IEC standards and suitable for installation offshore.

16.6 Marine & Utility Systems

16.6.1 Ballast System

A port and starboard ring line ballast system, servicing all ballast tanks, with branch lines to the

individual tanks shall be provided. The ballast valves shall be equipped with remote controlled

actuators of hydraulic type. Strainers shall be installed in the suction lines from the sea chests. One

sea chest shall be arranged on each side of the vessel. The ballast pumps shall have suction from

sea and from all ballast tanks and discharge overboard and to ballast tanks as well as transferring

from one ballast tank to another. The ballast system shall be of capacity sufficient to maintain

constant draught under all LNG loading conditions. A ballast tank eductor system, using one of the

fire pumps shall be fitted to each double bottom ballast tank for stripping purposes. Three electrically

driven horizontal ballast pumps with automatic suction device shall be installed in their own machinery

compartment. One pump shall have stand-by functions. Each pump shall have a capacity to allow

both pumping and gravity flow to/from the ballast tanks from/to the sea for the double bottom water

ballast tanks for the full duration of the LNG cargo to be filled. The pumps shall also provide a

constant draught during FSRU loading operations

An environmental friendly ballast treatment system shall be installed.

Remote control of the ballast system valves shall be incorporated in the FSRU control system.

Preventive measures must be incorporated into the design so that any single failure of the system or

any operating failure shall not permit ballast water to be inadvertently transferred from one tank to

another causing the unintentional flooding or emptying of tanks. It must be possible to normally


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operate the ballast system whilst loading LNG, and concurrently operating the gasification process

plant.

The FSRU ballast system shall be design as follows:

a) A port and starboard ring line ballast system, servicing all ballast tanks, with branch lines to the

individual tanks shall be provided;

b) One sea chest shall be arranged on each side of the vessel, Strainers shall be installed in the

suction lines from the sea chests;

c) The ballast pumps will have suction from sea and from all ballast tanks and discharge

overboard and to ballast tanks as well as transferring from one ballast tank to another;

d) Remote control of the ballast system valves shall be incorporated in the FSRU control system;

e) The ballast system capacity shall be not less than 5000-m³/hr.

16.6.2 Fire Pumps

Four 50% rated diesel firewater pumps shall be provided for the FSRU vessel. Two shall be located

in the main after machinery space. The other two, shall be located in the fore machinery space. The

four together provide necessary redundancy. The fire mains shall be a wet system, maintained

pressurized by jockey pumps.

16.6.3 Deck Wash Down System

A deck wash down system shall be provided for the deck. The principal use is for washing down the

deck and for supplying water to any water driven equipment if required. Normally, washdown shall be

supplied with water from the fire mains and supplied by a General Service (GS) pump. In addition a

fresh water wash down system for deck and process area shall also be provided. This system shall

have a cross connection to allow fresh water flushing of the fire mains. When the regasification plant

is operating, this fresh water can be sourced from the excess produced water from the regasification

process.

16.6.4 Seawater Systems

Seawater shall be required for the process plant cooling, fire and foam systems, utility cooling

systems, hull consumers and deck wash-down. The seawater suction system design shall be

capable of taking suction from both sides of the FSRU and be equipped with adequate hull valves,

isolating valves, duplex filters and fittings so that as much flexibility as possible can be achieved. The

use of approved non-metallic material for both process and engine room seawater piping is

encouraged.

16.6.5 Fresh Water Systems

A redundant suitable system for fresh water generation sufficient for the entire FSRU shall be

required to ensure that the facility is self sufficient without the need for external supply. Waste heat

recovery from diesel generator and gas generator (each 100%) capacity is required. A sterilization

system for domestic water shall be provided. Salt water intakes feeding the fresh water generator


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shall be as remote as possible from any overboard or produced water discharges, especially sewage.

Fresh water storage tanks shall be made from stainless steel.

16.6.6 Compressed Air Systems

All utility and instrument air for both FSRU and process plant shall be supplied from redundant

facilities located within the hull machinery spaces. Preference shall be for low maintenance screw

type compressors. The compressed air systems shall be designed based on typical oilfield rather

than marine standards. This shall include an instrument quality air dryer capable of reducing the dew

point of compressed air to –5ºC, as well as a separate process instrument air receiver. At least three

50% electric driven air compressor shall be used. At least two units shall be connected to the

emergency board. This compressed air system should also be designed for the purpose of re-

charging on-board Breathing Apparatus (BA) bottles.

16.6.7 Inert Gas & Nitrogen Generators

One Inert Gas generator and blowers with typical minimum capacity of 20,000-N.m³/hr

(CONTRACTOR shall specify minimum capacity during detailed design) shall be installed for inerting

tanks and holds discharge pressure of approximately >0.3-barg (CONTRACTOR to specify discharge

pressure during detailed design).

In addition, membrane type nitrogen generators (purity 99% N2 at full capacity) and blowers with

discharge pressure of >0.3-barg, for inert gas purging, shall be provided as nitrogen shall not normally

be imported onto the FSRU from onshore. The capacity shall be a minimum of 3 x 120-m³/hr.

CONTRACTOR shall specify requirements of nitrogen generators and capacity during detailed

design.

16.6.8 Automation Systems for Machinery

It is intended that the marine machinery and equipment shall be operated under continuous

supervision from the Central Control Room. Hence, provision should be made for remote and

automatic controls and instrumentation for the FSRU equipment and systems. The system shall meet

full "Unmanned Machinery Space" classification. The forward auxiliary machinery space shall also be

designed as an unmanned machinery space.

However, overall the FSRU system design must allow for local operation of all machinery when the

automatic systems are out of action. Necessary instrumentation for local manual control must be

provided, such as thermometers and pressure gauges.

16.6.9 Lubricating Oil System

Two bulk lube oil storage tanks and two bulk hydraulic oil storage tanks shall be provided. The lube

oil shall be used both for the power generation prime movers and for major topsides rotating

equipment. A lube oil purification system shall also be provided. A bunker station including filling

connections, appropriate manifold valves, and spill containment drip tray system, is to be provided

somewhere after and appropriately serviced by the supply cranes.


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16.6.10 Fuel Oil System

In addition to the two MDO fuel oil bunker tanks mentioned previously, a settling tank, a daily service

tank plus a fuel oil overflow tank and a diesel oil purifier shall be provided. Bunkering shall be from

the aft of the FSRU within reach of the supply crane to handle bunker hoses. A bunker hose reel

shall be provided.

16.6.11 Laboratory

Contractor shall design, fabricate and install a laboratory in accordance with the following

specification:

a) Laboratory shall be located on main deck in the accommodation block. Alternative locations

shall be considered by COMPANY. The space shall be designed as per Classification Society,

SOLAS and all regulatory requirements;

b) Designed to Classification Society A-60 fire rating and protected with adequate fire and gas

protection and a seawater deluge system; and

c) Space shall include the following:

i) Floor area shall be at least 15-m².

ii) Ladders, walkways, doors and windows to suit the selected location and area

classification. Access shall have air locks, if required.

iii) Electric power for lighting, laboratory equipment and telephone communication. Lighting

fixtures and switches shall be explosion proof type.

iv) Air conditioning, ventilation (including independent exhaust). The vent system shall be

capable of a minimum of 10 air changes per hour so as to keep the laboratory space free

from explosive gases.

v) A fume cupboard with dedicated overboard extraction shall be included.

vi) Hot and cold fresh water.

vii) Floor space allocated to laboratory benches. Storage space for bottled gasses, helium,

hydrogen and methane, outside in a weather protected cabinet including means for

securing these bottles.

viii) Supply of clean air and nitrogen (laboratory quality).

ix) Tubing runs for the gasses required above from the storage area to the benches.

x) Furniture shall include wardrobe, single door wooden locker, double door wooden locker,

bookrack, work table, chair, sink and wooden bench.

xi) The space shall be equipped with a gas chronometer, refractometers, pH-meters and

other relevant LNG sampling equipment.


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16.6.12 Marine Growth Suppression Systems

A marine growth suppression system shall be installed to prevent growth and fouling in all seawater

systems. This system shall be chosen to suit the FSRU's at open space prolonged stationary duty at

its jetty mooring.

16.6.13 Anchoring Equipment

Under in-place circumstances, anchoring equipment shall not be required.

Anchoring equipment during transport to site shall be determined by the CONTRACTOR. An

emergency wire and pick-up pennant shall be required and whilst being outfitted, and during tow a

single anchor may be required. If this is required the entire system must be retrievable so that the

anchor, chain and windlass do not have to be taken care of during the service life.

16.6.14 Lifting Equipment

The FSRU vessel shall be supplied with the following lift and transport equipment:

a) Offshore type diesel powered cranes capable of covering the entire regasification plant,

mooring areas and lay down area. Given the size of the regasification plant, two cranes may

be required. The cranes should be large enough to be able to maintain and or replace major

components of equipment. Sizes and capacities shall be determined during detailed

engineering. The cranes shall be capable of safely lowering loads on loss of power.

b) Additional cranes are to be provided at the stern, on or near the accommodation block, for

handling re-supply provisions, for lifting equipment to/from the machinery space.

c) The stern supply cranes, shall be rated and designed for personnel transfer (i.e. man riding).

d) The crane shall be operable to 100% capacity in the 10-year return condition.

e) Single rail overhead cranes and or lift blocks shall be provided where the crane can not reach

and lifting may be required.

f) Davit cranes are to be installed at each LNG tank dome top for servicing of the dome top

equipment, LNG pumps and for internal maintenance and inspection of the tanks.

g) Single rail overhead travelling cranes shall be also be provided as a minimum for each deck in

the machinery space, over key/heavy pieces of equipment which may need maintenance lifting

such as major pieces of running equipment. At each level the overhead rail crane shall

terminate below the machinery space access hatch so lifted components can be brought in

and/or extracted.

h) Tested and certified pad-eyes are to be provided above pumps, fans, miscellaneous machines

and other equipment where required. Plus adjacent to doorways to the machinery spaces, for

assisting in getting heavy object over bulkheads.

i) Cranes and lifting appliances shall comply with classification society lifting appliances code.


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16.6.15 Mooring Equipment

The mooring fittings are to comply with appropriate OCIMF recommendations. Vessel based mooring

equipment requirements are described in section 7 and are to be designed to be fully compatible with

the jetty mooring system described in [1].

16.6.16 Maintenance Areas

The FSRU vessel shall be supplied with the following maintenance areas:

a) Equipped workshops that shall enable maintenance to be carried out on board. A

comprehensive material movement study shall be required to ensure that equipment parts to

be repaired can be moved to and from the workshop. It is envisaged that there shall be

(probably three workshop areas including one mechanical/machine tool workshop, one welding

workshop and one Instrument and electrical workshop) adjacent or inside both aft and forward

machinery spaces.

b) A secure spare parts store room, part or all of which is air conditioned, shall also be provided,

preferably within the machinery space.

c) A maintenance lift should be provided to access the aft machinery spaces & below deck area.

This must be designed so that this lift does not constitute a fire hazard to aft accommodation

block in case of engine room fire.

16.6.17 Garbage Disposal & Sewage Treatment

Garbage disposal and sewage treatment discharge requirements shall be fully in accordance with

MARPOL requirements.

The FSRU vessel shall be supplied with the following items:

a) A compactor and containers shall be provided for handling of solid waste to the shore base.

Waste segregation shall be required to keep moderately toxic wastes such as paint cans and

empty chemical containers, separate from ordinary dry bulk waste.

b) A grinder shall be provided so organic food waste can be ground down to acceptable less than

25-mm and dumped overboard as per MARPOL requirement.

c) A vacuum sewage collection system with a four-stage sewage treatment system as per

MARPOL 2005 shall be provided. Requirements include:

i) Collection and reduction to a particle size less than 25-mm

ii) Aeration by air injection

iii) Settlement for 18 to 24-hours for bacteriological breakdown

iv) Disinfection where grey water is added and the mixture disinfected with chlorine process

(MARPOL).


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d) However, the system must also be able to operate in a zero discharge mode with all black

water taken to shore. A 200-m³ black water tank and transfer system shall therefore also be

provided.

16.6.18 Produced Water, Bilge & Slops, Storage & Treatment

In operation, significant amounts of clean water shall be produced by the regasification system. This

water shall normally be disposed off overboard, however, as part of the system a 150-m³ tank shall be

provided at the fore of the vessel3. One operating and one spare transfer pump shall also be

provided.

Contaminated water shall be collected, treated for discharge overboard and/or collected for return to

shore for disposal. Areas to be considered as contaminated include all areas containing process and

utility equipment or other areas where oil or other spillage could occur. Contaminated water from the

fore and aft of the vessel shall be collected separately and treated at the aft of the vessel. The

equipment shall be suitable for the stringent discharge requirements. The collection and treatment

equipment is expected to include:

a) Bilge tanks and associated pumps estimated at 200-m³

b) Slops tanks and associated pumps estimated at 200-m³, (or a combined bilge & slops tank).

c) Oily water separator capable of cleaning up to oil-in-water content of less than 15-ppm.

d) A 200-m³ contaminated water/sludge tank and associated pumps and piping for periodic

offloading to supply boats for disposal onshore.

16.6.19 Surface Preparations, Coatings and Material Protection

The minimum requirements for Coating for Structures, Piping and Equipment including valves,

vessels and heat exchangers are detailed in Appendix 2 - Coatings for Structures, Piping and

Equipment. CONTRACTOR shall furnish of the required materials, labour, equipment and tools, for

the surface preparation, application and inspection.

CONTRACTOR shall obtain COMPANY written approval for any deviations from the requirements of

this document or specifications, standards and drawings referenced herein or elsewhere in the

Contract.

The codes, specifications and referenced documents listed in Appendix 2 - Coatings for Structures,

Piping and Equipment outline the minimum requirements which shall be complied with and are not

intended to be all-inclusive. The requirements set forth do not relieve CONTRACTOR of the

requirement to meet applicable codes and standards, to comply with government regulations or to

supply a product capable of performing its intended service.

3 Applicable to AAV regas only


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16.6.20 Piping and Equipment Insulation

The piping and equipment of the FSRU includes but is not limited to water glycol intermediate

heating/cooling systems, inert gas and nitrogen systems, instrument air and hydraulic oil systems and

regasification systems.

The design life of the piping and equipment insulation systems shall be the same design service life of

the FSRU. Piping and equipment insulation requirements are detailed in Appendix 3 - Piping and

Equipment Insulation.

16.7 Control, ESD, Navigation & Communications

16.7.1 General Description of Control System

The FSRU shall be equipped with centralized, fully automated control system to provide both control

and safeguarding functions located in Central Control Room (CCR) itself located within the

accommodation. The system shall comprise a Safety Instrumented System (SIS) to provide overall

process safety monitoring and shutdown functionality; and a Distributed Control System (DCS) to

provide overall control of both process and utility systems.

All process safety functions shall be carried out within the SIS; with F&G monitoring and alarming

being carried out in discrete nodes of the SIS. The majority of control functions shall be implemented

within the DCS, however, where appropriate local controllers shall be utilized for selected equipment.

The instrumented systems shall enable the gas processing, export systems to be normally

unmanned, being able to be fully monitored and controlled from the CCR. A comprehensive CCTV

coverage shall be implemented for these areas.

The overarching design philosophy adopted shall be for automatic operation of the CP facilities and

equipment: wherein operator action shall be designed to be kept to a minimum.

All electronic boards shall be humidity (tropical) coated.

16.7.2 Control System Components

The CCR shall provide an integrated working area from which all functions of the FSRU shall be able

to be monitored and controlled. This shall therefore enable both the process and marine operations

personnel to functionally operate the FSRU from one combined control room. The CCR shall contain

HMI screens connected to the FSRU‘s automation systems. These shall include a comprehensive

interface with the FSRU‘s SIS, F&G system and DCS for all areas, marine systems - including cargo

and ballast control; and utility systems, such as power generation. The HMI screens shall be

configured to form control nodes, so that the control functions for loading/storage; gas

processing/export; marine systems form separate groups. The FSRU‘s F&G monitoring HMIs shall

again form a separate group.

The safeguarding and process control system hardware shall be installed within two instrument

equipment rooms. One of these shall be the central instrument equipment room (CER) and be

situated adjacent to the CCR and contain the systems hardware for the loading and storage

operations; ballast control and utilities. The system hardware for the gas processing and export

operations shall be installed within a field equipment room (FER), situated adjacent to the


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regasification plant area. This shall be a pressurized room, situated beneath decks, and shall also

house the local power MCC; UPS and DC power supplies. The CCR and the two instrument

equipment rooms shall all be connected together by a redundant fibre-optic cabled network. The

cable utilized shall be both armoured and fire resistance; and the redundant cables shall be installed

on diverse and separate routes. The system architecture shall be designed, however, so that if the

control network between the systems is disrupted, either equipment room shall continue to provide

stand-alone control and safeguarding to equipment connected to it.

To augment the control functions at the CCR, there shall be two Field Control Points (FCP)

implemented. One of these shall be for providing local control of the LNG loading operations; and

shall be situated adjacent to the loading area. The other unit shall enable local control and monitoring

of the regasification system. This FCP shall be installed within the FER. The FCP shall be equipped

with HMIs and shall enable local control of specific equipment and systems. The HMI for the LNG

loading area shall be certified for a hazardous area.

In addition, specific control functions shall be able to be carried out on the FSRU‘s navigation bridge.

The bridge shall be equipped all radar and navigation aid functions and communication links. It shall

also be equipped with a HMI screen and control panel and have full CCTV coverage of the both the

LNG and cargo berthing and loading areas.

16.7.3 Control System Reliabil ity

Systems shall have availability greater than:

a) 99.95% for DCS;

b) 99.997% for SIS;

c) 99.997% for FGS;

To achieve this level of reliability, a high level of redundancy shall be required.

16.7.4 Safety Instrumented System

The SIS system shall be implemented by high reliability, fault tolerant, stand-alone system providing

process and emergency shutdown functions. Its equipment shall be uniform across the FSRU. The

system design shall combine the requirements of high reliability (safety) and high availability. A SIL

determination review shall be carried out to define the integrity levels (to IEC 61508) required of these

systems. The PLC architecture shall be of Triple Modular Redundant (TMR) or Dual Redundant with

extensive diagnostic (1oo2D) architecture throughout. All shutdown signals to other sub-systems

including small packaged equipment shall be hardwired direct from SIS marshalling cabinets. Both

SIS and FGS system shall be similar in hardware and software to maximize spare parts interchange

ability. The status information of the SIS system shall be made available to the operators via the data

communication link to the DCS for monitoring. The SIS system shall monitor and receive inputs from

the FGS and shall take executive action to safeguard the facility as directed by the FGS logic.

The SIS shall have a data communications input from the LNGC during berthing operations. This

shall enable authorized operations personnel on the LNGC to initiate specific shutdown actions on


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their facility should an emergency occur during loading operations. It is anticipated that this data link

would be via a dedicated fibre optic channel.

Shutdowns shall be designed to operate automatically when the process is outside normal operating

limits and when a dangerous situation is likely to occur. Shutdowns may be initiated manually from

manual pushbuttons either locally from the process area or from the CCR. Manual re-start

authorization facilities shall be provided at the operator workstation in the CCR.

All SIS alarms and status shall be transmitted to the data communication network, and displayed on

the operator workstation. This shall include diagnostic data.

16.7.5 Fire & Gas System

The FGS shall be a highly reliable, independent, stand alone sub-system of the SIS system,

monitoring and controlling all FGS detection devices, performing necessary logic and providing

outputs to all fire protection devices and shutdown signals to the SIS system. All fire, gas, heat

detection and any suppression system to other sub-systems including small packaged equipment

shall be hardwired direct from FGS marshalling cabinets.

FGS system shall continuously monitor for abnormal conditions and shall be designed such that when

a hazard is detected, it initiates alarms and control actions as necessary. Output signals from the

FGS shall be hardwired to the plant SIS system for further shutdown of appropriate shutdown valve,

using voting system. Alarms and faults shall be displayed on the operator workstations as well as the

mimic panel in the control room. The FGS shall interface with fire protection systems (e.g. fire water

pump panels) for the automatic/manual actuation of the systems and monitoring the status signals

from the protection systems. The FGS shall interface with PA system for the activation of the FSRU‘s

audible alarms. The FGS shall interface with other equipments as required to carry out actions as per

Fire and Gas Cause and effect matrices.

As a minimum the following detection/activation equipment shall be provided:

a) Hydrocarbon detection system;

b) Flame detection system;

c) Smoke/heat detection system;

d) Oil mist detection in machinery spaces; and

e) Manual fire alarm system.

In addition to the DCS display, a fire and gas mimic panel shall be provided in the control room. It

shall be visible to the control room operator and hardwired directly to the FGS.

16.7.6 Distributed Control System

The DCS shall be based on a standard distributed control system open architecture with industry

standard high-speed data communication network. The DCS shall allow functional and geographical

distribution and integration of foreign devices. The primary objective of the DCS shall be to facilitate

control and monitoring (including the production of written reports) by fast acquisition and processing

of the parameters, to enhance the operator's overall knowledge of the plant conditions and


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operational conditions. The system is expected to monitor points collected from various parts of the

plant and present the required information on the operator workstation screens in suitable formats at

the operator's request thereby offering a suitable operating interface.

Where possible the control of the FSRU‘s marine and general utilities systems shall be incorporated

into the DCS. It is recognized that there are certain systems for which control may be better

implemented in discrete controller units. These systems, e.g. main power generation, ship‘s ballast

and cargo control, regasification system; shall have their local controllers connected to the DCS by

data communications links.

The operating system for all operator and engineering workstations should be latest Microsoft

Windows operating system based. Interface adapters shall be provided on the workstation allowing

connection to an Ethernet based information domain. The workstation shall be able to work as server

to clients in information domain connected to Ethernet LAN.

The controllers are stand alone process control and data acquisition systems and interface the field

signals to the communication network via I/O termination assemblies, I/O modules, control processors

and network communication modules.

Operator interface to the process for monitoring and commands shall be via the operator control desk,

which shall consist of operator workstations and manual pushbutton and mimic panels for both the

SIS and FGS. A historical database PC for SER monitoring and archiving tool for retrieving all DCS

and package equipment data for analysing cause of shutdown and data management shall be

provided. In addition the distributed control system shall be:

a) Integrated to plant information and management system to the head office;

b) Provided with 20% I/O spare capacity;

c) Provided with redundant configuration (CPU, I/O, module, etc); and

d) Integrated at the FSRU with the ORF.

16.7.7 Navigation and Searching Equipment

The FSRU vessel shall be provided with navigation aids including lights, shapes, signals and

signalling and electronic equipment that shall comply with SOLAS, BUI, communications and other

applicable international standards as follows:

a) Towage from shipyard to outfitting yard (if required);

b) Towage from outfitting yard to final location; and

c) Normal operations as a fixed installation.

In addition, in either case, the FSRU shall be equipped with:

a) A comprehensive meteorology system;

b) ARPA type radar and AIS (Automatic Identification System) to be provided in the CCR, with a

long range setting to warn against possible collision and a short range setting for assisting in

monitoring loading carrier approach; and


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c) A gyro compass.

16.7.8 Communication Equipment

A comprehensive communications system shall be provided on board the FSRU. The system shall

be designed to the following guidelines:

a) All equipment must comply with the appropriate SOLAS, and FCC;

b) APCO-25 frequency technology shall be used;

c) CONTRACTOR shall include local Jamaican offshore communication requirements;

d) The FSRU telecommunications system shall form part of a cohesive overall field

telecommunications system;

e) All radio equipment should be located within the telecommunications room with appropriate

slave units located in the CCR and TSR;

f) A leaky feeder system is to be installed around the FSRU, as required to minimize radio

interference; and

g) Sound powered phones to specific locations for use in the event of loss of communications

power.

A public address system shall be provided. Locations of speakers and talk-back booths shall be

determined during detailed engineering, but in general shall be arranged to cover all areas regularly

manned. A split communications system is preferred with one system for general communications to

common areas and the second for emergency communications to all areas (cabins etc.).

Onboard Microwave, UHF, Marine VHF, Aeronautical VHF, and SATCOM communication systems

shall be provided.

A telephone system with VOIP shall be provided, with handsets in all offices and cabins, and working

rooms as appropriate. The system shall be interfaced with the public address system.

A Local Area Network with connections into all cabins, recreation rooms, and workspaces including

switch rooms etc., managed by a Network Server and linked to a reliable, high uptime, broadband

computer and data link to allow 96% uptime IT linkage between FSRU LAN and onshore IT network.

A cable television, video and entertainment system shall be provided, serving the various recreation

rooms, cabins and mess rooms.

To achieve the above, a fiber optic communication system shall be provided. A back-up

communications system shall also be installed, using both satellite (SAT M) and VHF systems.

16.7.9 Closed Circuit Television (CCTV)

A closed circuit television system (CCTV) shall be installed with sufficient cameras to cover

regasification area, machinery spaces, loading system and surrounding waters (with night vision) etc.

These CCTV's shall be monitored from the CCR with full zoom, pan & tilt function. This video system


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must electronically communicate with the LAN to allow remote (through the FSRU‘s control network)

access, image viewing and recording.

16.8 Accommodation & Personnel Equipment

16.8.1 Performance and Functional Requirements

CONTRACTOR shall undertake manning study to determine the accurate number of crew. The

accommodation block shall be laid out with permanent beds to accommodate a minimum complement

or POB of 44 men with a total of minimum 20 men per shift, a two shift crew shall be accommodated.

The accommodation shall be optimized for the normal operation POB. However, available bed

space, catering facilities, escape facilities, utility systems and sanitary facilities must be designed for

the maximum complement.

The accommodation block including the CCR and gathering space to comfortably TBABC the full

complement of POB, shall be constructed so that it can be used as a Temporary Safe Refuge (TSR).

Galley equipment, machinery and furniture shall be provided to enable a variety of food to be

prepared and served. Refrigerated stores, freezers and dry provision rooms shall be provided, sized

on the basis of a 30-day re-supply period (based on maximum POB). Access to the stores must be

such that supplies can be brought in after offloading by the stern supply crane from supply boats

without any change of level (i.e. no stairs) and no excessive manual carrying. Subsequently for

transfer from the stores to the galley, the same requirement shall apply. Hence the galley and stores

must be carefully laid out and located at an optimum and same level to ensure efficient, access,

storing and supplying with minimum manual labour.

The highest regard shall be paid to structural fire integrity and crew safety. No materials which are

considered combustible or which produce toxic gases or heavy smoke are to be used in the

construction. No materials containing any form of asbestos shall be used (in the accommodation

block or anywhere else on the FSRU) and the FSRU shall be delivered with an "Asbestos Free"

certificate. All materials, and fire ratings of materials, shall be in accordance with Classification

Society and SOLAS requirements.

16.8.2 Accommodation Configuration

The accommodation quarters shall be located at the after end of the FSRU. It shall comprise a multi-

level deckhouse structure above the main machinery space. This deckhouse structure shall be

sufficiently strengthened but isolated from the main hull structure in order to minimize transmission of

noise and vibrations from the machinery space to the accommodation areas.

The accommodation shall include:

a) Sleeping cabins shall be serviced with a telephone and en-suite washing, showering and toilet

facilities;

b) Kitchen and dining facilities;

c) A fully equipped medical emergency hospital room;

d) A number of separate offices and a conference room with video conferencing facility;


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e) Recreational rooms with cable TV systems and other recreational equipment;

f) A communications room with all radio, microwave, and other communications equipment;

g) Fire and gas detection/alarm/protection system and adequate fire rating design;

h) Multi religion prayer room; and

i) Smoking room.

Special attention shall be given to the general lay out of the accommodation with regards to the

segregation of sleeping, recreation and working areas. In general, working areas and recreation

areas shall be on separate deck levels to sleeping cabins.

The accommodation shall be optimized for the normal operation POB. Berths, catering facilities,

escape facilities, utility systems and sanitary facilities must be designed for the maximum

complement.

a) The accommodation block shall be laid out with permanent beds to accommodate a

complement or POB of minimum 44 men with a total of 20 men per shift, a two shift crew shall

be accommodated. Where the minimum cabins requirements as follows;

i) 1 berth cabins x 10;

ii) 2 berth cabins x 13;

iii) 4 berth cabins x 2;

b) The accommodation quarters shall be located at the after end of the FSRU; and

c) The FSRU shall have a clinic which shall be equipped with the required mandatory minimum

medical supplies in accordance with STCW 95 and classification requirements. This shall

include as a minimum a qualified person to manage medical emergencies/incidents.

16.8.3 Accommodation Block & Temporary Safe Refuge Design Requirements

The accommodation block shall meet as a minimum all latest Class, IMO and SOLAS safety

requirements as applicable to LNGC‘s plus the requirements listed below. It shall also be designed

so that risk to personnel meets ALARP criteria under the FSA and QRA.

The accommodation block shall be designed and constructed that it or part of it can be used as a

Temporary Safe Refuge (TSR) for the maximum POB. The TSR shall be designed to be able to

withstand impairment from the Hazards on the Installation for a minimum of one hour and be fully

protected on all sides by A60 rated fire walls, bulkheads, floors and ceilings. The forward bulkhead of

the accommodation block, and also the lifeboats, are to be protected from jet fire or explosion on the

process deck or cargo deck by means of a fire/blastwall. Fire and Blast rating above any A60 rating

shall be determined during detailed design QRA.

There shall be a muster and waiting area within the TSR equipped with appropriate fire protection and

self contained ventilation and air conditioning capable of operation under emergency power. The

Lifeboat stations shall be located at the stern with direct protected access from the main TSR.


Page 93

The accommodation layout shall be arranged so that there are at least two exits to escape routes

leading in different directions from each deck level with at least one internal stairway linking all levels.

There shall also be two outdoor stair wells at opposite sides of the accommodation allowing access to

all floors. The internal stairway shall be enclosed in an A60 fire rated wall with matching self-closing

fire rated doors. At the edge of the TSR the stairs shall not be continuous and shall be interrupted by

a fire rated self closing door and separate entry into the corridor. Similarly, the machinery space, in

addition to having a separate entry from outside the accommodation block shall have at least two

entries from within the accommodation block. These stairs too shall be isolated by fire rated self-

closing doors and not continuous with stairs within the accommodation block. Preferably a change

room acting as an airlock shall be provided between the machinery space and accommodation block.

Internally the accommodation shall be equipped with both fire suppression (e.g. sprinklers or mist)

and fire fighting (extinguishers and hoses) in accordance with SOLAS and Classification Society

requirements.

16.8.4 Util it ies & HVAC

Utility services (HVAC, hot and cold water, sewage, etc.) for the accommodation block shall be

provided in compliance with Classification Society, IMO and BUI regulations as appropriate. The

Heating Ventilating & Air Conditioning (HVAC) system shall be a central split system such that system

maintenance can be conducted on the air conditioning refrigeration system or air handling unit without

interrupting HVAC service to the accommodation. The air conditioning system shall include spot

coolers in the galley and laundry rooms. The HVAC shall be designed so the accommodation is

always slightly over-pressured even with one or two open doors and even with extraction equipment

in the galley functioning normally. Gas detection at the air intakes shall be required, along with

automatic closing and sealing of the intakes, should gas be detected.

16.8.5 Lifesaving Equipment

Two 444 man totally enclosed motor propelled survival craft shall be used and located on the

starboard and port side of the FSRU. Additional emergency escape arrangements are to be supplied

for each lifeboat, typically in the form of rope ladders. The length of these ladders must reach the

waterline at lightship displacement and shall comply with SOLAS LSA.

SOLAS approved inflatable life rafts for full POB persons, fitted with hydrostatic and quick release

equipment shall be located at each side of the accommodation block in compliance with the

requirements of SOLAS. An additional two 20-man SOLAS approved life rafts fitted with hydrostatic

and quick release equipment shall be located forward adjacent to the secondary TSR, one mounted

on the port side and one on the starboard side. Adjacent emergency escape arrangements are to be

supplied for each life raft, typically in the form of rope ladders or inflatable evacuation slides. The

length of these ladders/slides must reach the waterline at lightship displacement.

4 See section 16.8.1 in regards to manning requirement. Life boats shall meet manning requirements

and SOLAS


Page 94

SOLAS approved lifejackets and immersion survival suits for at least 100% lifeboat capacity shall be

provided and stored in glass fibre boxes near the lifeboat/life raft embarkation areas. Additional

lifejackets & immersion survival suits shall be stowed in cabins, with additional lifejackets & immersion

survival suits in key locations (forward life raft location and in CCR). In addition life buoys, line

throwing apparatus, emergency ladders, personnel transfer baskets, distress signals etc., are to be

supplied as per statutory requirements.

The tug/supply boats used for LNGC berthing alongside the FSRU shall have a dual function of

rescue boat. In the first instance these vessels shall be used in rescue operations. A dedicated

rescue craft shall also be provided to cover the event whereby a tug is not available.

16.8.6 Medical Facilities and Equipment

The vessel shall be fully equipped to deal with medical/first aid emergencies in accordance with

classifications requirement. This shall include as a minimum qualified person(s) to manage a medical

emergency/incident and the provision of a designed space for sickbay/dispensary. This facility shall

be quipped to treat cryogenic contact burns.

CONTRACTOR shall use STCW 95 as minimum requirements related to medical first aid and medical

care.

16.9 Fire Fighting

The vessel is provided with active fire protection in the form of fixed fire fighting systems. As part of

the conversion it is assumed that the fire water/spray water capacity needs to be increased, in order

to provide fire water/spray water to the new areas (regasification plant, suction drums, LNG loading

arms, gas export manifold etc), to comply with the IMO/IGC code requirements. As found necessary,

fire water monitors shall be installed and be dedicated to gas dispersion, heat protection and material

brittleness protection at the suction drums.

16.9.1 Loose Fire Fighting Equipment, Firemen’s Outfit

Fire hoses, hydrants, portable extinguishers, firemen‘s equipment, breathing apparatus, etc. shall be

provided. The type, quantity and location shall be subject to SOLAS and COMPANY‘s approval. An

area shall be designated within the TSR as a fireman‘s muster area. Alternate fire muster areas shall

be designated and equipment specified during detail design.

CONTRACTOR shall use STCW 95 as a minimum standard of competence in advanced fire fighting.

16.9.2 Secondary Temporary Safe Refuge

A secondary TSR shall be provided at the bow of the FSRU vessel (i.e. the end that is farthest from

the accommodation block). The auxiliary TSR shall be constructed with appropriate fire and blast

protection, in line with the detailed design assessments on all walls, floors and ceiling, to meet

survival criteria of at least one hour, and requirements as may arise from the Quantitative Risk

Analysis. The refuge should be simple in design and be able to accommodate about 60 personnel

that may be working in the vicinity. Communications and escape equipment must be provided.


Page 95

16.10 Seawater System

The seawater system required for the regasification plant shall depend on the LNG vapourization


As a minimum, the FSRU shall have a seawater system that supports the LNG loading and storage

facilities. If the regasification plant uses the IFV technology, additional seawater pumps and

treatment shall be required as specified in [2].

During the conversion it shall be decided whether the existing dry powder system needs to be

expanded. Relevant additional capacity may be related to pool fire extinction in the booster pump

suction drum area and regasification plant area.

16.11 Other Utilities

The following utilities are envisaged but not detailed:

a) N2 generators – flare purging, compressor/pump seal purging, marine systems;

b) HPU for actuated valves;

c) Plant and instrument air systems; and

d) HVAC for non-LQ pressurised spaces.

Additional utility requirements shall be defined by the system supplier and incorporated by

CONTRACTOR.

16.12 Main Propulsion System

For new build the CONTRACTOR shall propose the type and size of the main propulsion system.

Waste heat recovery shall be included to improve the efficiency or the regasification system.

For conversions the existing propulsion system shall be maintained.

Compliance with IACS, IMO and the flag state requirements shall be demonstrated by sea trials. The

minimum regular speed is 16-knots @ full draft plus 0.5-knots sea margin at 80% MCR.


Page 96

17. REFERENCES

[1] WorleyParsons, ―Jamaican LNG Project, Basis of Design‖, 402010-00260-00-GE-BOD-0001

[2] WorleyParsons, ―Jamaican LNG Project, Regasification Plant Functional Specification‖,

402010-00260-00-PR-SPC-0001

[3] WorleyParsons, ―Jamaican LNG Project, ORF & Pipeline Functional Specification‖, 402010-

00260-00-PR-SPC-0002

[4] WorleyParsons, ―Jamaican LNG Project, FSRU Operating Philosophy‖ 402010-00260-MA-00-

PHL-0001

[5] WorleyParsons, ―Jamaican LNG Project, Jetty Design Philosophy‖, 402010-00260-MA-00-PHL-

0002

[6] SIGTTO, LNG Operational Practice, 2006

[7] SIGTTO, Guide for Planning Gas Trials for LNG Vessels, July 2008

[8] http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade

_or_remain_in_port.htm

http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade_or_remain_in_port.htm

http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade_or_remain_in_port.htm


c:\users\ernie laptop\documents\jamaica lng\worleyparsons\word documents\402010-00260-00-ma-spc-0005 (jetty moored fsru functional specification).doc

Appendix 402010-00260 : 00-MA-SPC-0005 Rev 0 : 24 August 2011\

Appendix 1 - Design Premise



Page 1 402010-00260 : 00-MA-SPC-0005 Rev 0 : 24 August 2011

1. Codes and Standards

Table 1.1: Summary of applicable Standards/Codes for Health &Safety

Code No. Title













Table 1.2: Summary of applicable Standards/Codes for Environmenta

Code No. Title


System


1973

Table 1.3: Summary of applicable Standards/Codes for Quality Assurance

Code No. Title





etc)






Code No. Title


301)

Table 1.4: Summary of applicable Standards/Codes for IMR

Code No. Title




etc)




301)



API 570 Piping Inspection Code : Inspection, Repair, Alteration and re-rating




Table 1.5: Applicable Standards/Codes for the FSRU

Code No. Title

DNV-OSS-309 DNV‘s Verification, Certification and Classification of Gas Export and

Receiving Terminals. (OI Floating Offshore LNG Re-gasification

Terminal POSMOOR BIS CRANE HELDK COAT-2 EC0)

DNV-OSS-103 Rules for Classification of LNG Floating Production and Storage Units

or Installations

API RP 2C/D Offshore cranes/operation and maintenance

API RP 2A-WSD

Planning, Designing and Constructing Fixed Offshore Platforms

Working Stress Design (for Topside structures, including flare tower,

external turret mooring arm)

IGC International Code for the Construction and Equipment of Ships


DNV PT.5 Chapter 5 DNV Rules for Ships, Part 5, Chapter 5, Liquefied Gas Carriers




Code No. Title

DNV-OS-C101

Design of Offshore Steel Structures, General (LRFD method) (for

Topside structures, including flare tower and external turret mooring

arm (supplementing API RP 2A to account for vessel motions, etc.)

DNV-RP-C102 Structural Design of Offshore Ships

AISC-WSD AISC WSD Manual of Steel Construction (for Topside structures,

including flare tower, External turret mooring arm)

CN30.7 DNV Classification Note No. 30.7 Fatigue Assessment of Ship

Structures, February 2003

CN33.1 Classification Note No. 33.1 Corrosion Prevention of Tanks and

TBABCs, July 1999

DNV-RP-B401 Cathodic Protection Design

DNV-RP-B101 Corrosion Protection of Floating Production and Storage Units

DNV-RP-C201 Buckling Strength of Plated Structures

SIGTTO/ICS/OCIMF 1995 Ship to Ship Transfer Guide (Liquefied Natural Gas),

IGTTO/ICS/OCIMF

COLREG International Regulations for Preventing Collisions at Sea

USCGD FRSU and LNGC Exclusion and Safety Zones

NVIC 05-05 Waterway Suitability Assessment (WSA)

DNV-OS-D101 HVAC Standards

IMO Res A.468(XII) Code of Noise Levels on Board Ships





ISO 4867 Code for the measurement and reporting of shipboard vibration data

ISO 4868 Code for the measurement and reporting of local vibration data of

ship structures and equipment.

ISO 2041 Vibration and shock— Vocabulary

ISO 2631 Guide for the evaluation of human exposure to whole-body vibration.

ISO 2923

UL595 - Marine Type Electric Lighting Fixtures




Code No. Title

SIGTTO Manning Qualification Requirements

ILO International Labour Organisation - Maritime Labour Convention

IACS No 47 Shipbuilding & Repair Quality Standard

TSCF Guidelines for Ballast Tank Coating System and Surface Preparation

Table 1.6: Applicable Standards/Codes for Fendering & Mooring

Code No. Title


OCIMF Mooring equipment Guidelines




DNV-OS-E301 POSMOOR

Table 1.7: Applicable Standards/Codes for Mechanical Systems

Code No. Title





Pressure Piping


Systems




Ships Pt.4 Ch.7


Recognised codes for boilers

API Std 530 Calculation of Heater Tube Thickness in Petroleum Refineries

ASME section I Power Boilers

ASME section IV Heating Boilers




Code No. Title

NFPA 8502 Standard for the Prevention of Furnace Explosions/Implosions in

Multiple Burner Boilers


Ships Pt.4 Ch.7


ISO/R 831 Rules for construction of stationary boilers

TBK-1-2 General Rules for Pressure Vessels






Recognised codes for heat exchangers

API Std 661 Air Cooled Heat Exchanger for General Refinery Services


Ships Pt.4 Ch.7


TEMA R Heat Exchanger Tubing




Industry Services





Ships Pt.4 Ch.1




Services.


Industry Services




Code No. Title






Ships Pt.4 Ch.5







Ships Pt.4 Ch.3



2 hazardous areas








Ships Pt.4 Ch.3




Ships Pt.4 Ch.4






41.2





Code No. Title


Ships Pt.4 Ch.4





Ships Pt.4 Ch.4



Industry Services.




Table 1.8: Applicable Standards/Codes for Fire Fighting

Code No. Title







Installations.


Table 1.9: Recognised Codes for Pumps

Code No. Title




Industry Services






Code No. Title



Ships Pt.4 Ch.1


Table 1.10: Recognised Codes for Lifting

Code No. Title



Table 1.11: Applicable Standards/Codes for Process Systems

Code No. Title


Natural Gas











Refineries



.API Std 610 Centrifugal Pumps for Petroleum, Heavy Duty Chemical and Gas

Industry Services








Code No. Title Industry Services



Process Piping



Pressure Piping


Fuel Gas System




Table 1.12: Applicable Standards/Codes for LNG Tanks

Code No. Title



Class Rules DNV Rules for Liquefied Gas Carriers, Pt.5 Ch.5



Natural Gas (LNG)

Table 1.13: Applicable Standards/Codes for Re-Gasification System (Cargo Pump System)

Code No. Title


Gas



Platforms


Refineries.






Code No. Title Pressure Piping

Table 1.14: Applicable Standards/Codes for Re-Gasification System (Cargo Pump System)

Code No. Title


Gas



Platforms


Refineries.


Table 1.15: Applicable Standards/Codes for Electrical & Instrumentation

Code No. Title

















1 and Zone 2


Natural Gas (LNG)




Code No. Title


505)



requirements)



considerations)










IEC 60269 / BS 88 Low Voltage Fuses



above 1kV and up to and including 52kV


atmospheres






1-kV up to 30-kV.





Code No. Title






Spec Test Methods








Gases








60534-2Mod)






ANSI/ISA 75.22 Face-to-Centerline Dimensions for Flanged Globe-Style Angle Control







Code No. Title









Metal Seats







Industries


















Code No. Title














Chromatography

IEC 60079-0 Electrical Apparatus for Explosive Gas Atmospheres, Part 0:General

Requirements


Flameproof enclosures ―d‖


Pressurized enclosures ―p‖

IEC 60079-7 Electrical Apparatus for Explosive Gas Atmospheres, Part 7:Increased

Safety ‗e‘


Safety ―i‖


Encapsulation ―m‖



450/750 V






Code No. Title






polyolefin sheath












sector






other units











Code No. Title



Data












Tactile Method





Table 1.16: Applicable Standards/Codes for Life Saving Appliances

Code No. Title





Table 1.17: Applicable Standards/Codes for Mooring

Code No. Title

API RP 2SK Recommended Practice for Design and Analysis of Stationkeeping





Code No. Title





2SK)






Table 1.18: Applicable Standards/Codes for Installation

Code No. Title





Table 1.19: Applicable Standards/Codes for In-service Operations

Code No. Title



section.

Table 1.20: General Mechanical



Marine Vessels









Reference Title/Comments Nondestructive Testing

Table 1.21: General Structural

Reference Title






Table 1.22: Painting and Corrosion Protection

Reference Title


ISO 8501 Preparation of steel substrates before application of paints and

related products -- Visual assessment of surface cleanliness












SSPC-PA-3 Paint Application No. 3, A Guide to Safety







Reference Title Pressed and Forged Steel Shapes, Plates, Bars, and Strip




ASTM A143 Safeguarding Against Embrittlement of Hot-Dip, Galvanized

Structural Steel Products







Appendix 2 - Coatings for Structures, Piping and Equipment




1. Introduction

This Appendix defines the minimum technical requirements for Coating for Structures, Piping and

Equipment including valves, vessels and heat exchangers furnishing of all materials, labour,

equipment and tools, for the surface preparation, application and inspection.



Contract.

This document and the codes, specifications listed in section 1.1 below are not intended to be all-

inclusive. The requirements set forth do not relieve CONTRACTOR of his responsibility to perform all

services in a safe manner, to meet applicable codes and standards, to comply with government

regulations or to supply a product capable of performing its intended service.

1.1 Codes, Specifications and References

The latest editions of all applicable codes, specifications and references shall define the minimum

requirements applicable to the subject work and no statement contained in this specification shall be

construed as limiting the work to such minimum requirements.

Wherever conflicts or omissions between codes, specifications and contract occur, the most onerous

condition shall apply. CONTRACTOR is responsible for reviewing the list below and informing

COMPANY of any omissions. All conflicts shall be formally brought to the attention of COMPANY.

Table 1.1: Applicable Codes

Reference Title
















Reference Title




ASTM A123

Zinc (Hot Galvanized) Coatings on Products Fabricated from Rolled,





ASTM A143

Safeguarding Against Embrittlement of Hot-Dip, Galvanized



NACE RP-0176

Corrosion Control of Steel, Fixed Offshore Platforms Associated with


2. General Requirements

CONTRACTOR shall provide all labour, equipment and materials necessary to perform surface

preparation and coating in accordance with this Specification.

All CONTRACTOR personnel involved in surface preparation or coating work shall be qualified and

thoroughly trained as to the materials and specifications pertaining to the coating systems and shall

be provided with breathing apparatus and skin protection as per OSHA Hygiene and other applicable

safety standards.

CONTRACTOR shall be responsible for the proper storage, transportation and disposal of any and all

waste material (hazardous or otherwise) generated as a result of its operation. All handling of waste

material, including but not limited to spent abrasives, paints, thinners, solvents and cleaners shall be

in a safe and legal manner and shall comply with all applicable Regulations and Laws.

CONTRACTOR shall ensure that the coating system(s) specified herein fully comply with any local

and/or regional air quality or Volatile Organic Compounds (VOG) emission standards or requirements.

All materials shall comply with 2.80 Ibs per gallon VOC (maximum), except for high temperature

products. Should modifications or alternate coating systems be required to meet such standards or

regulations, CONTRACTOR shall immediately notify COMPANY and submit details of the proposed

alternate system to COMPANY for review and acceptance.

All paint and surface preparation abrasives shall be free of lead, chromate and crystalline silica. In

addition, all paint materials shall meet latest guidelines with respect to VOCs.




Scaffolding or staging shall be used, where required, to provide easy access for surface preparation

and paint application. Scaffolding shall be such that operator's arms and body shall be free to

perform the necessary work and shall be provided with safety features that shall prevent accidents.

This specification and NACE Standard RP-0176 shall govern the procedures and materials required

for surface preparation and coating of the specified structures and/or equipment. No deviations or

exceptions from this specification shall be made without prior written approval of COMPANY.

The paint manufacturer's product data sheets and specifications for mixing, application and curing

shall be considered an integral part of this specification.

The coating systems shall be determined by CONTRACTOR. If a coating option is indicated, the

selected option shall be used as specified throughout the coating operation.

COMPANY shall designate paint manufacturers/suppliers. COMPANY reserves the right to specify

which manufacturer's coating system shall be used. Mixing of different manufacturers' products shall

not be permitted without written permission from COMPANY. If the coating system specified herein

by manufacturer's brand name is not consistent with the generic designation specified,

CONTRACTOR shall notify COMPANY immediately for instructions.

CONTRACTOR shall perform all touch-up painting to provide a completely painted assembly unless

specified otherwise. All field tie-ins, exposed surfaces of piling, field splices, weld areas, etc. shall be

painted. The coating system used for field touch-up painting shall be from the same manufacturer as

used during the fabrication of the structure. All coating materials required for offshore touch-up shall

be furnished by CONTRACTOR.

Multiple coats of paint shall be of colours approved by COMPANY which contrast to the colour of the

previous coat. CONTRACTOR shall verify the finish coat colour with COMPANY prior to the initiation

of material procurement. The final coat colours shall be as identified in Section 10.

All carbon and stainless steel surfaces that operate in the 65°c to 175°C range and that shall be

insulated shall be coated in accordance with a coating system to prevent chloride cracking that can

occur in this temperature range.

Pre-painted equipment purchased by CONTRACTOR, or others shall be re-coated by

CONTRACTOR if existing paint system does not meet or exceed those of this specification.

COMPANY shall determine if existing system of pre-painted equipment meets or exceeds this

Specification.

The following surfaces shall not be abrasive blasted, coated or painted unless otherwise specified:

aluminium, brass, rubber, glass, plastic, concrete, monel, copper-nickel alloys, bronze, fiberglass

reinforced plastic, PVC, stainless steel weather jacketing, insulation, plated surfaces, machined

flange faces, machined mounting pads for rotating equipment and instrument cases.

Inside surfaces of manways, nozzles, bosses and other connections shall be blasted and coated with

the same system as the internal surfaces of the tank or vessel, where internal coating is specified.

Inorganic zinc primers may be used as pre-construction primers, but weld bevels must be free of all

the primer before welding. This can be done by masking prior to coating or by grinding or abrasive




blasting before welding. The coating-free area shall extend a minimum of 75-mm from the weld

bevel.

Weld-through primers shall not be used unless welding qualification tests show no detrimental effects

such as unacceptable porosity. The use of any weld through primers must be approved by

COMPANY in writing prior to their use.

All non-machined mating surfaces of equipment subject to outdoor exposure shall be completely

coated in accordance with these specifications prior to assembly (i.e. saddle base plates, skirt base

plates, bolted components, etc.).

All contaminated inorganic zinc primer shall be removed by abrasive blasting. The surface shall be

abrasive blasted to original designated finish and the zinc primer reapplied according to this

Specification.

3. Surface Preparation

Unless otherwise approved by COMPANY, all fabrication, assembly, and non-destructive testing of a

particular component shall be complete before surface preparation begins.

CONTRACTOR shall protect all gasket surfaces, flange faces, valve stems, name plates, pressure

gauges, instrument cases, gauge glasses, electrical conduit and fixtures, instrument tubing, aids to

navigation, and all previously installed and coated equipment including galvanized equipment. If the

coating on any previously installed equipment is damaged, the damage shall be repaired or replaced

as directed by COMPANY. Where practical, electrical cable and instrument tubing shall be installed

after blasting.

CONTRACTOR shall remove all sharp edges and corners.

All bolt holes, including U-bolt holes in pipe supports, shall be drilled and ground smooth before

initiating blasting operations unless otherwise approved by COMPANY.

All oil and grease contamination shall be removed from the surface in accordance with SSPC-SP1,

"Solvent Cleaning", and using biodegradable water soluble cleaner prior to abrasive blasting. All

blasting shall be performed using dry blasting techniques in accordance with the SSPC specification

required for that particular area. Blasting anchor profiles shall be consistent with manufacturer's

recommendations for each coating application.

Except as otherwise specified, all surfaces shall be blasted to a "near-white metal" blast cleaned

surface finish as per SSPC-SP1 0 and shall demonstrate an anchor pattern of 1.5 to 2.0 mils peak to

peak.

Mechanical cleaning in accordance with SSPC-SP2 or SSPC-SP3 and solvent cleaning in

accordance with SSPC-SP1 may be required separately or in conjunction with each other when

blasting cannot achieve a near-white metal surface or when blasting shall damage fragile components

(e.g. engine and compressor, etc.). Prior COMPANY approval is required for all areas where

mechanical and or solvent cleaning is to be used.

Except as otherwise specified, acid washes or other cleaning solutions or solvents shall not be used

on metal surfaces after being blasted. This includes any inhibitive washes intended to prevent rusting.




The abrasive may be coal slag, refractory slag or flint, sized to produce the required anchor profile

and graded to be free from clay, silt or other matter likely to become embedded in the steel surface.

Abrasive other than those listed above shall be approved by COMPANY. Silica containing abrasives

are not allowed to be used.

Blast materials containing impurities or inclusions shall not be allowed.

Blast cleaning operations shall not be conducted on surfaces that shall be wet after blasting and

before coating, when the surfaces are less than 3°C above dew point as measured by a sling

psychrometer, or when the relative humidity of the air is greater than 90%, without permission of

COMPANY.

It is desired that blasting be done during daylight hours. If blasting is allowed during the night, the

surface shall be swept clean and bright the next morning with fresh, light blasting to provide a "near

white" blasted surface.

Blasting shall be done in an area removed from painting operations and freshly coated surfaces to

prevent contamination. Contaminated coatings shall be solvent cleaned and then removed by

blasting to a near-white finish. The coating shall then be reapplied as specified in this specification.

All welded areas and appurtenances shall be given special attention for removal of welding flux in

crevices. Welding splatter, slivers, and underlying mill scale exposed during blasting shall be

removed or repaired.

After blasting, CONTRACTOR shall thoroughly clean all blast grit and dust from both internal and

external surfaces, including removal from crevices, recesses, etc.

4. Coating Application

Coating application shall be in accordance with this specification and the paint manufacturer's

recommendations included with the materials and shall be subject to inspection by COMPANY

Inspector at all times.

All coating materials furnished by CONTRACTOR shall be in unopened, clearly identifiable

containers. Mixing of different manufacturer's paints on the same surface shall not be permitted.

Containers shall remain unopened until required for use. No paint shall be used whose shelf life has

expired.

Only sufficient volumes for the appropriate pot life of application shall be mixed at one time.

Manufacturer's recommended pot life shall not be exceeded and when this limit is reached, the spray

pot must be emptied the material properly, disposed of and new material mixed.

All components shall be thoroughly stirred before, during and after mixing. Inorganic zinc coatings

shall be continuously stirred by mechanical spray pot agitators or other approved means during

application. The volume to be mixed shall be accurately measured. All mixing shall be done in clean

containers, free from traces of grease, other type paints, or other contaminants. All containers shall

be kept covered to prevent contamination by dust, dirt or rain.

Coating application shall not be permitted: in the fog, mist or rain, when the steel is wet, when

surfaces are less than 3°C above the dew point as measured by a sling psychrometer, when the




relative humidity is greater than 90%, or when the temperature is below 10°C or above 38°C without

prior approval of COMPANY.

All painting done outdoors shall be done in daylight hours and completed at least one hour prior to

sundown. Indoor painting is allowed 24 hours a day if the specified metal and air temperatures and

relative humidity requirements are met inside the building at all times during preparation, painting and

curing.

Blast-cleaned surfaces shall be coated with primer during the same day as blasting and at least one

hour prior to sundown of that day, and also before any rusting occurs. A minimum of 75-mm around

edges of blasted areas shall be left unprimed. Blasting shall continue a minimum of 25-mm into

adjoining coated surface. Any blast-cleaned surfaces that are not primed and are wet by rain or

moisture shall be re-blasted prior to application of primer.

Material surface shall be clean, dry and free from dust before application of any coat of paint. In areas

where inorganic zinc is used as a primer, the surface shall be pressure cleaned with fresh water when

the primer remains exposed in excess of 48-hours prior to top coating, unless specifically approved

by COMPANY representative on a case by case basis. This shall ensure removal of dust and

contamination in the porous zinc film.

All coatings shall be allowed to dry and cure thoroughly in accordance with the manufacturer's written

instructions prior to application of a succeeding coat. All coats shall be applied as soon as possible

after the minimum specified drying time of the preceding coat.

Damage to intermediate coats, prior to application of the next coat, shall be repaired by

CONTRACTOR to provide the coating sequence and film thickness as specified in the coating

systems.

Coatings shall not be applied when the wind speed exceeds 24-km per hour unless specifically

approved by the onsite COMPANY representative on a case by case basis.

Large surfaces shall always receive passes in two directions at right angles to each other (cross-

hatched). Parallel passes are acceptable in all other areas.

All excessive over spray shall be screened off.

No coating shall be placed on or within three inches of edges prepared for field welds. Succeeding

coats of paint shall be stopped a minimum 75-mm between coats at field weld locations (i.e. primer

coat stops 75-mm from field weld, intermediate coat stops 75-mm from field weld, etc.).

Atomizing air and paint pot pressure shall each be regulated to the minimum amount required to

properly atomize material for application without dry spray, runs or sags. If a particular coating

system requires a special pump(s) or equipment, then only that specific equipment shall be

acceptable for coating application.

An adequate moisture trap shall be placed between the air supply and pressure feed to gun. Trap

shall continually bleed off any water or oil from air supply. Lines and pot must be cleaned before

adding new materials. Suitable and working regulators and gauges shall be provided for both air

supply to pressure-pot and air supply to pressure gun.




Separate regulators shall be used to adjust the paint pot pressure and atomization pressure. Each

regulator shall be provided with a pressure gauge operating properly at all times.

Coating may be brushed on all areas which cannot be properly spray coated. Use brushes of style

and quality that shall enable proper application of materials and in accordance with the specified

coating thickness. Inorganic zinc coatings shall not be applied by brush, even for touch-up or repair.

Ring grooves and raised face surfaces of flanges shall be protected from abrasive blasting and paint.

The complete coating system shall be applied to faces other than the ring groove or the raised face

prior to installation. Swabs should be used to coat the inside of flange bolt holes. Flange bolt holes

do not require the finish coat of paint.

The finished job shall not contain sags, runs, wrinkles, spots, blisters, or other application flaws.

Holidays in the final coat at edges, corners, welds and inaccessible areas may be protected by

spraying or hand brushing an additional layer of topcoat provided excessive build-up does not occur.

The coatings described in this specification contain flammable solvents. The vapour from these

solvents may be harmful and cause skin and eye irritation. The resinous components of the primers

and laminating resin may cause serious delay dermatitis. Employees involved in coating work shall

be provided with breathing apparatus and eye and skin protection as necessary.

Inorganic zinc requires a minimum relative humidity of 50% to cure. If the relative humidity is below

50% then special precautions must be taken to insure the cure of the zinc primer. Consult supplier

and COMPANY representatives for further instructions.

All welds and edges to be coated shall be brush stripe coated prior to application of each coat. Zinc

primer coats are not to be stripe coated.

When applying coatings over inorganic zinc primer a mist coat is required to seal the surface and

prevent surface bubbling of topcoats. A mist coat shall consist of a thin coat (1-2 mils) of the coating

being applied over the zinc primer. This should be allowed to tack up before applying a full coat over

the top of the mist coat. Consult Supplier for proper methods of applying a mist coat using their

materials.

5. Repair and Damaged Areas (Touch Up)

All external surfaces where coating is damaged during fabrication, transportation, and erection shall

be repaired as follows:

a) Top coat damaged, but, base coat undamaged: Repair by removing damaged coating with

sandpaper or other means acceptable to COMPANY (wire brushing shall not be acceptable),

feather edges of adjacent painted surfaces and apply 2.0 to 3.0 mils of polyurethane top coat.

b) Coating damaged to base metal: Repair by blasting damaged area to SSPC-SP10 Near-White

metal, feather adjoining paint surfaces with sandpaper to provide a smooth surface transition

and apply an appropriate four coat system.

c) Coating damaged to base metal where blasting is not approved: Mechanically cleans and

applies the appropriate three-coat system specified by CONTRACTOR.




Care shall be taken to avoid damaging the coatings surrounding repaired areas and to assure

complete tie-in of the coating with surrounding areas.

All internal surfaces where coating is damaged during fabrication, transportation, and installation shall


a) Remove damaged area by spot blasting to white metal (SSPC-SP-5) and feather into

surrounding coating with sandpaper. Clean all loose material from the surface in accordance

with SSPC-SP-1.

b) Re-coat with same coating system using same manufacturer.

CONTRACTOR shall repair the coating on all damaged areas prior to final acceptance by

COMPANY.

All clamps and brackets shall be removed to allow for the full coating system to be applied under the

bracket or clamp. Care should be taken when securing the brackets or clamps that the coating under

the bracket or clamp is not damaged.

6. Galvanizing

All grating, handrails, ladders, stairs, cages, toe plates, guard rails, clips, and miscellaneous items

defined in the drawings are to be hot dip galvanized as per ASTM A123. The weight of the zinc

coating shall average not less than 915 grams per square meter and no specimen shall show less

than 760-grams per square meter. Dry film thickness of the zinc coating shall not be less than 2.5

mils and shall not exceed 8.0 mils. Consult COMPANY representative when coatings exceed 8.0

mils.

Hot dip galvanizing of bolts, nuts, washers and miscellaneous manufactured items shall be performed

in accordance with ASTM A153 "Zinc Coating (Hot Dip) on Iron and Steel Hardware" and ASTM A143

"Safeguarding Against Embrittlement of Hot, Galvanized Steel Products".

Galvanized members which are to be permanently fixed to the structure by welding shall be attached

after the supporting members are primed and Intermediate coated, but before top coat is applied to

the supporting members.

All damage to galvanized items caused by fabrication, welding, handlIng, or loading out shall be

blasted and coated with the system specified in CONTRACTOR‘s coating systems.

All grating support members shall be primed and intermediate coated before securing the grating and

then those weld areas shall be near-white metal blasted, re-primed and fully coated.

7. Inspection

COMPANY shall have the right to inspect any equipment and material used, or to be used in the

performance of the specified work and may reject any equipment, material or work not conforming to

the specifications either before or after work commences.

COMPANY representative shall have access to all work while being performed. COMPANY shall be

given at least two days notice prior to commencement of any work described in this specification.




Surface preparation and/or coating application shall not be done in the absence of COMPANY

Representative without his knowledge or consent.

CONTRACTOR shall arrange to have a technical representative from the coatings manufacturer

present to assist and witness the initial application of each coating system for all major jobs such as

jackets, decks, skids, and multiple pieces of equipment. Further technical assistance from the

coatings manufacturer shall be obtained, when problems arise or when COMPANY requests such

assistance.

A copy of this specification and manufacturer's recommendations shall be kept at the job site.

CONTRACTOR shall provide and utilize wet and dry film thickness, temperature and humidity gauges

as required by the performance of the work. Paint foreman shall inspect and monitor the work of

painters and blasters under his direction.

All prepared surfaces shall be inspected and approved by COMPANY's representative before primer

is applied. Acceptance of the blast cleaned surface shall be made by COMPANY's representative,

based on a visual comparison with Clemtex "Anchor Pattern Standards", Keane-Tator "Surface Profile

Comparator", Swedish pictorial surface preparation standards SSPC-VISI-1, the appropriate SSPC

surface preparation specifications.

Measurement of paint dry film thickness shall be made with a gauge, which has been calibrated

against National Bureau of Standards "Certified Coating Thickness Calibration Standards" in the

presence of COMPANY's representative. Failure to meet specified thickness ranges shall cause work

to be rejected.

Work shall be rejected because of poor workmanship. Poor workmanship is defined as improper

surface preparation, inadequate drying or curing, excessive paint build-up, dirt or dust inclusions, over

spray, pinholes, runs and sags, or inadequate film build, etc.

Rejected work shall be repaired to meet the requirements of this specification.

Acceptable finish work must be free of abrasions and must be uniform in color and appearance.

A final inspection shall be made by COMPANY representative prior to acceptance. Representatives of

CONTRACTOR and paint manufacturer may be present. Any defective areas shall be repaired by

CONTRACTOR at no additional cost to COMPANY.

8. Special Coating Requirements

Upon completion of protective coating work, CONTRACTOR shall provide stenciled paint

identification of all major items of equipment. Identification shall include the equipment item number

and description as indicated on drawings. Two opposite sides shall be stenciled with BLACK paint

with numbers and letters approximately 75-mm high.

In areas with non-slip coating requirements, dynamic wet friction factor shall be 0.8 or greater.




9. Coating Systems

CONTRACTOR shall specify for COMPANY approval a listing of the complete coating system for all

repaired and/or new items to be included as part of the FSRU. It shall include, but is not limited to the

following:

a) Structural steel

b) Piping

c) Vessels

d) Equipment

e) Exhaust / Flare torch / Vent

10. Colour Selection Table

Item Description Finish Colour

Structural Steel: Framing Components, Pipe Supports, I-Beams, Legs,

Handrails, Stairs Cases, Metal Buildings, Components In And Above

The Splash Zone, Boat Landings, Riser Guards And Cranes

Topcoat (Yellow)

Production Equipment: Vessels Packages, Piping, Wellheads,

Conductor Pipe, Header Packages, Slop Oil Tanks, Pumps,

Compressors, Turbine Packages, Generator Packages, Valves And

Misc. Skid Packages

Topcoat (Grey)

Paint System 14 for Subsea Christmas Trees, Subsea Manifolds,

Subsea Templates, Riser Arches, Living Quarters and PLEMS piping.

Topcoat (White)

Sub sea Structures and Manifolds

Piping

Structural

Topcoat (White)

Topcoat (Yellow)

Flare Booms And Transmission Towers OSHA Safetv Red & White

High Temperature Components (Exhaust Stacks, Fire Tubes, Etc.) Aluminum

Plated Steel Deck Surfaces Topcoat (Grev)

11. Documentation

CONTRACTOR shall submit to COMPANY for approval a painting and anti-corrosion coating data

book containing the following information as a minimum:




a) Material certificates

b) Inspection equipment and calibration certificates

c) Inspection and testing reports

d) Release certificates

All data shall be supplied in hard copy and electronic format.




Appendix 3 - Piping and Equipment Insulation




1. Introduction

This appendix describes the specifications for the insulation of piping and equipment for the FSRU.

The piping and equipment of the FSRU including but not limited to water glycol intermediate

heating/cooling systems, inert gas and nitrogen systems, instrument air and hydraulic oil systems and

regasification systems. The design life of the piping and equipment insulation systems shall be

identical to that of the FSRU.

2. Application

2.1 Stainless Steel

The LNG process pipe work shall be constructed of grade 316LSS and great care shall be adopted

not to contaminate or damage it with ferrous material. This includes:

a) Cutting, grinding and welding

b) Chipping

c) Hammering

d) Lifting off or providing support

The surface preparation for Stainless Steel:

a) Insulation shall not commence until after the completion of all NDT and leak/pressure tests on

the system, or section of the system, to be insulated.

b) Where deemed necessary by COMPANY, surfaces that have been exposed to salt spray

during storage and/or construction, shall be washed with fresh potable water containing less

than 500-ppm chloride ions, by CONTRACTOR.

c) Surfaces to be insulated shall be dried and if necessary cleaned using appropriate solvents to

remove grease or foreign matter.

2.2 Carbon Steel

The surface preparation of Carbon Steel:

d) Insulation shall not commence until after the completion of all NDT and leak/pressure tests on

the system, or section of the system, to be insulated.

e) Where deemed necessary by COMPANY, surfaces that have been exposed to salt spray

during storage and/or construction, shall be washed with fresh potable water containing less

than 500-ppm chloride ions, by CONTRACTOR

f) Surfaces to be insulated shall be primed and painted by the Painting Contractor and the

Insulation Contractor shall specify the types of primer and paint that shall be compatible for

mastic use.




2.3 Insulation Application

The application of the insulation shall comply with the following requirements:

a) All the preformed sections shall be accurately fabricated, radiused and beveled to fit closely to

both the application surface and adjacent sections of insulation. (Glue where applicable)

b) All insulation joints shall be butted together, with a maximum gap between sections of 1.25-mm

c) Multiple layer construction shall be employed where the insulation thickness exceeds 50-mm.

Each layer shall be installed with a circumferential and longitudinal joints staggered to ensure

there are no through joints.

d) For multiple layered constructions, each layer shall be installed with the thinnest layer against

the insulated surface, with thicker layers applied radially outwards.

e) Side and end joints shall be covered with joint sealant or adhesive. For multilayered

construction, only the joints of the outermost layer shall be required to be sealed

f) Insulation with factory applied, reinforced metallic foil vapour barrier shall be supplied with

hinged halves, a flap for sealing the longitudinal joint and water proof adhesive. End joints

shall be sealed with strips of vapour barrier material or aluminum tape. The insulation shall be

fastened with band or pressure sensitive tape only, (fibre reinforced tape 13-mm minimum

width)

g) Insulation on vessel heads shall be held in place with bands radiating from the floating ring

made of 6-mm round carbon steel rod. The bands shall be spaced at no more than 300-mm

apart at the tangent line and attached to a 12-mm carbon steel rod at the head tangent (or

other suitable alternative)

h) Contraction and expansion joints shall be provided in the insulation system and shall take into

account the following factors:

i) Contraction/expansion of equipment or pipes;

ii) Contraction/expansion/shrinkage of insulative material;

i) Resilience of insulative material;

j) Properties of mechanical protection material;

k) Method of supporting insulation.

l) As far as possible, individual lines or vessels shall be insulated as a single item.

m) Insulation of pipe line fitting such as elbows, tees etc shall be shop fabricated, with the

minimum number of joints and amount of adhesive.

2.4 Vapour Barrier

An elastomeric coating, reinforced with synthetic fibre fabric shall be applied to act as a vapour barrier

against the ingress or moisture whilst in cold service.




a) Elastomeric coatings shall meet the following conditions:

b) Flame spread classification not exceeding 25 per ASTM E84;

c) Demonstrated resistance to solar radiation;

d) Flexibility at the minimum design temperature.

e) Water vapour permeability not exceeding 0.05 metric perm-cm as per ASTM E96 Procedure E

for DFT used. DFT = WFT x 0.146.

The vapour barrier shall be applied in three coats, giving a total DFT of 1.0-mm with successive coats

in contrasting colors.

The first coat of vapour barrier shall be applied between 8 and 24 hours after the completion of the

insulation installation. Immediately after the application of the first coat, and whilst it is still wet, a layer

of reinforcing fabric shall be pressed smoothly into the coating with a fabric overlap of 25-50-mm.

After a minimum of four hours of drying time, the second coat shall be applied, with the third coat to

be applied after a further 24-hour‘s of drying time.

Double layers of fabric shall be used at joints to ensure a smooth unbroken transition of vapour

barrier coating.

Where the insulation has been interrupted or terminated for completion at a later date, the coating

shall be terminated approximately 100 to 150-mm from the edge of the applied insulation.

2.5 Mechanical Protection

The insulation and vapour barrier shall be mechanically protected against damage and weather by a

0.5-mm thick galvanized steel cladding.

Laps of cladding shall be positioned to prevent the ingress of water. Minimum Lap requirements are

shown in the Table below.

Pipe/Equipment Diameter Minimum Lap

Up to and including 24‖/600-mm 50-mm

Greater than 24‖/600-mm 75-mm

The above minimum laps shall also be applied to longitudinal overlaps between adjacent sections of

cladding.

a) All circumferential and longitudinal joints shall be sealed by the application of a suitable non-

setting water impervious sealant.

b) A minimum of two stainless steel bands per cladding course shall be used to retain it in place.

On vertical surfaces, means to prevent the bands from slipping shall be provided.




c) Where the use of pop rivets or self-tapping screws is deemed necessary, they shall be of a

type that does not require penetration of the vapour barrier.

d) The minimum sized bands are stipulated in the table below.

Pipe or Vessel Outside Diameter Band Size

Pipe and Vessel Up to and Including 24‖/600-mm 10x0.4-mm

Pipes Over 24‖/600-mm 12x0.4-mm

Vessels Over 24‖/600-mm 20x0.5-mm

Cladding at elbows shall be mitred to a close fit tolerance to the insulation, with all mitre joints to be

sealed in a non-setting water impervious sealant.

Particular attention shall be given to cladding joints at branch connections with regard to integrity (fit

and sealing).

3. Insulation Concept

The basic concept for the insulation of process and auxiliary equipment and pipelines considers the

following aspects:

a) Limitation of heat ingress into cold systems (cold conservation),

b) Limitation of heat loss to the environment on warm systems (heat conservation),

c) Prevention of condensation of ambient humidity on cold systems

d) Prevention of moisture ingress by way of vapour sealing,

e) Prevention of damages by way of mechanical protection,

f) Personnel protection on systems having high operating temperatures,

g) Limitation of heat ingress into equipment in case of fire,

h) Leak detection on flanged connections,

i) Convenience of maintenance work.

Generally, insulation for heat or cold conservation shall be applied to a system if the surface

temperature of the respective system is expected to differ by more than 20K from the average

ambient temperature range in normal operation.

4. Cold Insulation

Cold insulation shall be applied to all systems where conservation of the cold temperature of the

contained fluid is required or the formation of boil-off gas needs to be limited. This applies primarily to




liquid cargo systems as well as cargo vapour systems that are connected to the cargo tank vapour

space or the regasification system.

Cold insulation shall also be applied to systems where there is a considerable risk of condensation of

ambient humidity or ice formation on cold surfaces. This particularly applies to systems in the

machinery rooms and cargo compressor room. Outside of the machinery rooms and cargo

compressor room insulation to prevent sweating shall be limited to systems in permanent operation.

Cold insulation shall be designed according to the following criteria:

a) Limit the heat ingress to 30-kW/m² on the external surface of the insulation and;

b) Prevention of condensation on the external surface of the insulation.

The design of the cold insulation systems shall be based on the worst case ambient conditions as

defined for the project and an average wind speed of 1.5-m/s.

5. Warm Insulation

Warm insulation shall be applied to all systems where conservation of the heat of the contained fluid

is required.

Warm insulation shall be designed according to the following criteria:

a) Limit the heat loss to 45-kW/m² on the external surface of the insulation for systems with an

operation temperature below 100°C,

b) Limit the heat loss to 50-kW/m² on the external surface of the insulation for systems with an

operation temperature between 100°C and 150°C and

c) Limit the heat loss to 70-kW/m² on the external surface of the insulation for systems with an

operation temperature above 150°C.

The design of the warm insulation systems shall be based on the worst case ambient conditions as

defined for the project and an average wind speed of 1.5-m/s.

6. Personnel Protection

Personnel protection shall be applied to all surfaces which are likely to have temperatures of 60 °C or

above, or -5°C and below, under continuous operating conditions that can normally be expected at

the worst case ambient conditions as defined for the project and an average wind speed of 1.5-m/s, if

these surfaces are accessible to personnel and are in areas that are frequently manned.

Personnel protection shall not be applied to expose potentially cold surfaces as they shall form a

protective ice coating. The same design criteria as stated above shall be applied to all systems in the

machinery rooms and cargo compressor room.

7. No Insulation

No insulation is required for the following systems and locations:

a) Any intermittent vent and drain systems,




b) Pipe branches and valves up stream of safety valves or other sections of pipe in which the fluid

shall be stagnant,

c) Any flanges or other detachable connections,

d) Any flanged valves and removable spools and

e) Any system or part of a system which is only likely to experience high or low temperatures

temporarily, during transient periods or during commissioning.

8. Fire Protection Concept

Further to the process requirements outlined in section 2, the insulation system shall also serve to

protect equipment from heat ingress due to fires in the vicinity of the respective equipment.

For this purpose all major vessels and heat exchangers which shall contain cold products shall be

insulated with fire resistant insulation (e.g. foam glass with stainless steel cladding or equivalent).

9. Further Points for Consideration

CONTRACTOR shall be responsible for the provision of all access platforms, scaffolding etc. for the

safe execution of the installation.

CONTRACTOR shall ensure that all materials are carefully and correctly stored prior to use.

CONTRACTOR shall state clearly the facilities and/or services that shall be supplied by others.

CONTRACTOR shall provide drawings etc, detailing the following:

a) Details of expansion/contraction joints;

b) Vapour seals around nozzles and projecting attachments

c) Repair procedures for damaged areas;

d) Inspection, QA/QC procedures

e) Composition re thickness for multi layered constructions.

CONTRACTOR shall provide a detailed program of execution of the installation, including material

delivery periods, surface treatment, insulation application etc

CONTRACTOR shall include in the program an indication of the manpower requirements.

CONTRACTOR shall note that COMPANY shall have the right to inspect the materials and/work at

any stage and reject the same if not acceptable.

Attachment 08 - Jetty Design Philosophy

GOVERNMENT OF JAMAICA - OFFICE OF THE CABINET JAMAICA LNG PROJECT JETTY DESIGN PHILOSOPHY

Page i

Jamaica LNG Project Jetty Design Philosophy

402010-00260 – 00-MA-PHL-0002

25 August 2011


Page ii

CONTENTS 1. INTRODUCTION ................................................................................................................ 1

1.1 Background ......................................................................................................................... 1

1.2 Purpose ............................................................................................................................... 1

1.3 Objective ............................................................................................................................. 1

1.4 Abbreviations ...................................................................................................................... 2

1.5 Definitions ........................................................................................................................... 3

2. DESIGN BASIS INFORMATION ........................................................................................ 4

2.1 Availability ........................................................................................................................... 4

2.2 Design Life .......................................................................................................................... 4

2.3 Design Conditions ............................................................................................................... 4

2.4 Codes and Regulations ...................................................................................................... 4

2.5 Site Coordinates ................................................................................................................. 4

2.6 Health and Safety ............................................................................................................... 4

2.7 Metocean Data .................................................................................................................... 5

2.8 Geophysical and Geotechnical Data .................................................................................. 5

2.9 Overpressure Protection ..................................................................................................... 5

2.10 Cargo Handling Criteria .................................................................................................. 6

2.11 LNG Loading .................................................................................................................. 6

2.12 NG Offloading ................................................................................................................. 7

2.13 Datum ............................................................................................................................. 7

2.14 Jetty Layout .................................................................................................................... 7

2.15 Supply LNG Carriers ...................................................................................................... 7

2.16 Berthing Operational Considerations ............................................................................. 7

2.17 Material Data .................................................................................................................. 8

2.17.1 Structural Reinforced Concrete .............................................................................. 8

2.17.2 Structural Steel ...................................................................................................... 8

2.18 Piling Requirements ....................................................................................................... 9

2.19 Ground Anchorage ......................................................................................................... 9


Page iii

2.20 Design Loads ............................................................................................................... 10

2.20.1 Dead Loads .......................................................................................................... 10

2.20.2 Equipment Loads ................................................................................................. 10

2.20.3 Live Loads ............................................................................................................ 10

2.20.4 Environment Loadings ......................................................................................... 11

2.20.5 Earthquake Loading ............................................................................................. 11

2.20.6 Berthing Loads ..................................................................................................... 11

2.20.7 Mooring Loads ..................................................................................................... 11

2.21 Load Combinations ...................................................................................................... 12

2.22 Deflection Limits ........................................................................................................... 12

3. FUNCTIONAL REQUIREMENTS ..................................................................................... 13

3.1 Layout of the SRT Jetty .................................................................................................... 13

3.2 Berth Configuration ........................................................................................................... 13

3.3 Jetty Structures ................................................................................................................. 14

3.3.1 Service Platform ................................................................................................... 14

3.3.2 Independent Power Supply .................................................................................. 15

3.3.3 Walkways ............................................................................................................. 15

3.3.4 Approach Road .................................................................................................... 15

3.3.5 Pipe Trestle .......................................................................................................... 16

3.3.6 Jetty Equipment Room ......................................................................................... 16

3.3.7 Gangway .............................................................................................................. 16

3.3.8 Handrail ................................................................................................................ 17

3.3.9 Vehicle Crash Barriers ......................................................................................... 17

3.4 Mooring Structures and Equipment .................................................................................. 17

3.4.1 Breasting Dolphins ............................................................................................... 17

3.4.2 Mooring Dolphins ................................................................................................. 18

3.4.3 Fenders ................................................................................................................ 19

3.4.4 Quick Release Hooks .......................................................................................... 19

3.5 Loading Arms .................................................................................................................... 20

3.6 Safety Systems ................................................................................................................. 20


Page iv

3.6.1 Lifesaving Equipment ........................................................................................... 20

3.6.2 Emergency Shut Down ........................................................................................ 21

3.6.3 Port Security Plan ................................................................................................ 21

3.6.4 Fire Fighting ......................................................................................................... 21

3.6.5 Cryogenic Fluid Hazard ....................................................................................... 21

3.6.6 Jetty Drainage ...................................................................................................... 21

3.6.7 Safety Accreditation ............................................................................................. 21

3.7 Electronics and Communication ....................................................................................... 21

3.7.1 Integrated Mooring and Environmental Monitoring, Piloting and Docking System21

3.7.2 Navigational Aids and Aero lights ........................................................................ 22

3.7.3 Ship-to-Shore Communications ........................................................................... 22

3.7.4 Metering ............................................................................................................... 22

3.8 Construction, Installation and Commissioning .................................................................. 22

3.8.1 Shore Protection and Dredging ............................................................................ 22

3.8.2 Piling .................................................................................................................... 22

3.8.3 Surface Protection ............................................................................................... 22

4. MANDATORY CODES, STANDARDS, GUIDELINES AND RECOMMENDATIONS ..... 24

5. REFERENCES ................................................................................................................. 26

Appendices

APPENDIX 1 DESIGN PREMISE

APPENDIX 2 COATINGS FOR STRUCTURES, PIPING AND EQUIPMENT To be Advised by CONTRACTOR

[TBABC 001] Typical jetty layout ........................................................................................................... 15

[TBABC 002] Typical jetty head ............................................................................................................ 16

[TBABC 003] Mobile crane capacity ..................................................................................................... 17

[TBABC 004] Independent power supply .............................................................................................. 17

[TBABC 005] Fender specification ........................................................................................................ 22

[TBABC 006] Port security plan ............................................................................................................ 23

[TBABC 007] Fire fighting equipment.................................................................................................... 23

[TBABC 008] Risk mitigation plan ......................................................................................................... 24


Page v

[TBABC 009] Dredging .......................................................................................................................... 25

[TBABC 010] Piling................................................................................................................................ 25


Page 1

1. INTRODUCTION

1.1 Background
















1.2 Purpose

The purpose of this document is to provide a functional specification for the Jamaican LNG FSRU

double berth jetty.

1.3 Objective

CONTRACTOR shall provide a double berth jetty as specified in this functional specification. This

document requires that CONTRACTOR demonstrates the performance as described in this functional

specification and in the operational philosophy document. CONTRACTOR is also required to

demonstrate the system performance in accordance with criteria established in the Basis of Design

[1] and the Operational Philosophy [2] document while ensuring that:

a) The jetty shall integrate with the Floating Storage Regasification Unit (FSRU) [3] and pipeline to

shore and the shore based ORF (it is CONTRACTOR’s responsibility that the interfaces are

managed and integrated into the design and construction activities);

b) The jetty shall meet the minimum criteria and code and standards as set out in the design

premise document, Appendix 1 Design Premise;

c) CONTRACTOR shall apply good offshore oil & gas industry practice when undertaking the

design, construction, commissioning and installation of the jetty.


Page 2

1.4 Abbreviations





ANSI American National Standards Institute


ASME American Society for Mechanical Engineers

BOD Basis of Design

CD Chart Datum






IDs Identifications


KO Knock Out



LOA Length Over All

mmscf Millions Standard cubic feet

mmscfd Millions Standard cubic feet per day

NDMMO Navigation, Docking, Mooring, MetOcean system

NG Natural Gas

OCIMF Oil Companies International Marine Forum


Page 3



PERC Power Emergency Release Coupler

PIANC Permanent International Association of Navigation Congresses

PPU Portable Piloting Unit

QCDC Quick Connect Disconnect

QRH Quick Release Hooks

SIGTTO Society of International Gas Tanker and Terminal Operators



TBC To Be Confirmed

WP WorleyParsons

1.5 Definitions













Page 4


2.1 Availability

SRT availability requirements are as set out in the BOD document [1].

2.2 Design Life

SRT design life is set out in the BOD document [1].


SRT design conditions are detailed in the BOD document [1].

2.4 Codes and Regulations

The jetty is to be built in accordance with, the codes and regulations mentioned in the BOD [1] and

Appendix 1 Design Premise.

2.5 Site Coordinates

SRT site location is detailed in the BOD document [1].


Safety shall be of primary importance in the design of all systems associated with the jetty. The

design shall comply in all respects with the relevant workplace safety and health act(s) enforced in

Jamaica.

The rapid detection of any release of LNG gas or liquids, or other hazardous chemicals on the

installation is vital, as is the rapid detection and extinguishment or containment of any resultant

fire/explosion by either active or passive means in order to minimise the escalation potential.

A Safety Instrumented System (SIS) shall be implemented to provide a comprehensive coverage

which shall monitor all potential hazards within the facility, and automatically initiate appropriate

shutdown and containment measures. A comprehensive fire and gas detection system shall form

part of the SIS. The exposure of personnel in the gas processing areas of the facility shall be

minimised by the use of automated control and monitoring technology and CCTV coverage.

Diverse means of escape shall be provided. The facility shall be provided with a temporary safe

refuge and alternative muster/refuge areas as considered necessary, following a safety assessment

in accordance with COMPANY requirements. The philosophy to be adopted for evacuating the facility


facility unsafe.


Page 5

2.7 Metocean Data

Detailed metocean data is to be prepared by CONTRACTOR. Indicative metocean details are

contained in the BOD [1].

CONTRACTOR shall use a reputable metocean data company to obtain detailed metocean data for

the SRT location, CONTRACTOR shall obtain as a minimum the following data:

a) Wind sea and swell hind cast data for the FSRU location

b) Cross correlation between wind sea and swell and the persistence of these

c) Annual wind, wave (wind sea and swell) and current distribution

d) 1-year return condition, wind, wave and current

e) 10-year return condition, wind, wave and current

f) 100-year return condition, wind, wave and current

g) Hs vs. Tp

h) Hs vs. direction

i) Wind vs. direction

j) Current vs. direction

k) Cross correlation between the wind and seas and the persistence of these

l) Cross correlation between the current and seas and the persistence of these

m) Squall winds.

The data shall be of sufficient detail to allow fatigue assessment and the mooring and offloading

availability analysis.

2.8 Geophysical and Geotechnical Data

Only preliminary geophysical and geotechnical data is currently available for the proposed site

locations. Refer to the BOD [1] for details. Detailed geophysical and geotechnical data is to be

prepared by CONTRACTOR.




instrument malfunction or fire. All design shall be in accordance with the latest editions of API RP 520

and 521.


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2.10 Cargo Handling Criteria

Cargo handling criteria is outlined in Appendix 1 Design Premise. All LNG operations shall follow

guidelines and procedures as given in SIGTTO LNG Operational Practice [6]. Further, LNG gas trails

shall be performed in accordance with SIGTTO “Guide for Planning Gas Trials for LNG Vessels” [7].

2.11 LNG Loading

The SRT is to be capable of accepting LNG from LNG carriers (LNGC) ranging in size from 125,000-

m³ to 180,000-m³. A one day turn around is assumed for LNG loading, hence the system must be

designed to load at a rate of 10,000-m³/hr.

The FSRU shall be capable of receiving 100% load of 157,000-m³ at one continuous offloading

operation.

The manifold system shall allow for loading of all cargo tanks individually but also simultaneously from

any LNG loading arm. This shall be facilitated by valves and should not require removing of spool

pieces. Each loading arm shall be able to be disconnected individually without compromising the

ability to load LNG.

The LNGC manifold shall accommodate a double blocked valve system to allow for the liquid header

to vapour header, liquid header to HD compressor to be isolated and loading arms to be isolated,

without the need to remove spool pieces.

The manifold system shall be configured to allow all vessel operations to take place if one tank is

taken out of service, and or one tank is in the process of being warmed-up or cooled down.

The manifold shall allow for a recirculation of LNG and NG to maintain individual systems at cryogenic

temperatures at all times.

Interface with the shipping contractor/team during the design phase is necessary to confirm the

manifold connection sizes.

OCIMF also recommend the manifold arrangement as:

L – L – V – H

L = Liquid, V = Vapour, H = Hybrid (both liquid and vapour)

Note: Final manifold arrangement to be specified by CONTRACTOR during detailed design, in-line with CONTRACTOR's specification for loading arms.

A further consideration of the system is maintaining cold temperatures during TBABCing mode.

During TBABCing mode, heat leak into the loading lines would generate vapour which could lead to

over-pressure/thermal relief or at worst stratification and hence bowing in the lines. To avoid this (or

time consuming repeated emptying of the lines between loading operations) a vapour management

system shall be installed.

The system shall provide for a single loading and dual loading line capability. Therefore, an

additional, smaller recirculation header is required to enable LNG circulation for the single loading

line. In a dual loading line system circulation is to be carried out down one header and returned in the

other, removing the need for an additional line.


Page 7

The system shall be operated in general to maintain the hybrid arm as spare.

Hydraulic surge shall be considered for the LNG loading system. The system shall therefore provide

a surge drum to protect against excessive surge pressure. CONTRACTOR is to perform a detailed

transient analysis.

2.12 NG Offloading

Two high pressure natural gas loading arms of total 200% capacity of peak NG flow, as outlines in the

BOD [1], shall be provided. The NG loading arms shall connect to the FSRU manifold for HP gas.

2.13 Datum

All design documentation for the jetty shall refer to the Chart Datum (CD) based on WGS 84 as given

in the BOD [1]. The interface between onshore and marine structures shall be carefully checked for

consistency.

2.14 Jetty Layout

The berthing layout shall be based on the following factors:

a) Bathymetry,

b) Environmental constraints,

c) Surface geology,

d) Unloading and reloading requirements, and

e) LNGC supply vessel characteristics.

The berth shall be designed for the specified range of environmental conditions and for all

laden/unladen supply LNGC conditions.

2.15 Supply LNG Carriers

The berth shall be designed for both membrane type and spherical (Moss) type LNG carriers. Typical

LNGC characteristics are given in the BOD [1].

2.16 Berthing Operational Considerations

The following operational issues are to be taken into consideration for the detailed berth design:

a) The Helios wharf ship operations and turning circles.

b) LNGC minimum all round ship’s hull clearance of 1-m from the revetment and structures with

the vessel approach angle of 10 deg to the berthing line.


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2.17 Material Data

2.17.1 Structural Reinforced Concrete

Reinforced concrete shall be designed to achieve the design life stated in the BOD [1].

Concrete design shall be in accordance with BS 8500/BS EN 206-1 as per the requirements defined

below. Where a conflict exists, the more stringent requirement shall apply.

a) Characteristic strength of concrete ......................... 45-N/mm² for marine structures (C45)

b) Minimum cover:

i) Permanently buried ........................................ 50-mm

ii) Seawater or splash zone ............................... 75-mm

iii) Atmospheric ................................................... 50-mm

c) Minimum cement content ......................................... 350-kg/m³

d) Maximum water/cement ratio ................................... 0.45

e) Design crack width ................................................... 0.15-mm.

Reinforcing Bars shall be in accordance with BS 4449, 4483, EN 10080, ASTM A 615 and ASTM A

996:

a) Yield strength of hot rolled high strength steel ......... fy = 460-N/mm² (deformed type II)

b) T-bar designed for crack control purpose ................ fy = 250-N/mm²

c) Yield strength of Mild Steel ...................................... fy = 250-N/mm² (denoted as “R” bar)

d) Yield strength of Steel Fabric Meshes ..................... fy = 485-N/mm² (BRC)

2.17.2 Structural Steel

a) Design Yield Strength of Steel ................................. py = 275-N/mm² (BS EN 10210 S275)

b) Design Yield Strength of Steel ................................. py = 355-N/mm² (BS EN 10210 S355)

c) Design Yield Strength of Pipe .................................. py = 355-N/mm² (API 5L GrB/ X52)

d) Slenderness ratio of structural members (ratio of effective length to radius of gyration)

i) Main critical members shall not exceed ......... 120

ii) Other members shall not exceed ................... 180

e) Minimum thickness of members:

i) Except for webs of flanged and hollow section members serving as secondary members,

thickness of main structural members shall be ≥ 6-mm

ii) For open steel structures higher than 20-m, thickness of any parts of structural members

shall be ≥ 6-mm


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f) Connections:

i) Gusset plates shall not be thinner than the members to be connected, and shall have a

thickness of ≥ 6-mm

ii) Flange width of purlins:

− for supporting light-weight concrete slabs ≥ 80-mm

− for supporting roof sheeting and wall cladding ≥ 50-mm

g) Corrosion allowance for 40 year design life:

i) Submerged zone ........................................... min. 3-mm

ii) Splash zone ................................................... min. 5-mm

h) Steel structure in air and protected by coating system min. 2-mm

i) All steel submerged in seawater shall be protected using sacrificial anodes.

2.18 Piling Requirements

Foundations shall be designed based on the marine soil investigation data. The minimum safety

factor for design of pile geotechnical capacity shall be as follows:

a) Normal working compression load ........................... 2.5

b) Combined extreme vertical and horizontal load ....... 2.0

c) Normal working tension load .................................... 3.0

d) Short-term or accidental working load ..................... 2.0

e) Extreme tension load ............................................... 1.5

f) Lateral load .............................................................. 2.51

g) Allowable working load stress in driven steel piles:

i) Compressive stress ....................................... fy = 0.3, for normal loading conditions

ii) Axial tensile stress ......................................... fy = 0.3, for normal loading conditions

2.19 Ground Anchorage

Tension micro-piles (anchor pile) are recommended if the desired tensile pile capacities cannot be

achieved by driving. In the event of premature driving refusal within the hard layer, micro-piles may

also be used to supplement the required compression and tensile resistances of the steel piles.

1 The criteria for the design of laterally loaded piles is usually determined by the allowable deflection

at the serviceability limit state which shall be assessed but is recommended to be not greater than 60-

mm.


Page 10

2.20 Design Loads

2.20.1 Dead Loads

Dead loads shall be factored to obtain the worst case and applied, in accordance with the design

codes. The following unit weights are assumed for design:

a) Density of concrete: ................................................ 24-kN/m³

b) Density of steel: ...................................................... 77-kN/m³

c) Density of water: ...................................................... 9.81-kN/m³

2.20.2 Equipment Loads

The structures shall be designed for all equipment and plant permanent and live loads, piping loads

and thermal loads. In particular the loads due to the offloading arms operating, abnormal and

maintenance conditions shall be addressed.

The vertical loads and overturning moments for the marine loading arms and gangway should be

considered for the structural design of the jetty head.

2.20.3 Live Loads

Live loads shall include:

a) Approach road:

i) Mobile crane .................................................. 50-tonne

ii) Truck .............................................................. 10-tonne

iii) Fire engine ..................................................... 10-tonne

b) Jetty head:

i) Mobile crane .................................................. 50-tonne

ii) Truck .............................................................. 10-tonne

iii) Fire engine ..................................................... 10-tonne

c) Dolphins:

i) Deck live load ................................................ 5-kN/m²

ii) Reactions from catwalks, fender reactions, mooring loads

d) Walkway, stairway & catwalks ................................. 5-kN/m²

e) Hand railing .............................................................. 0.5-kN/m applied at the level of the upper

rail

f) Piping area ............................................................... Full pipes plus 10-kN/m² of gross plan area

including space between the pipes


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2.20.4 Environment Loadings

The extreme marine environmental design conditions should take into consideration 1 in 100 years

return period in all cases unless otherwise specified. In addition, the detail design phase has to

consider seiches and shallow long swell conditions. The effect of Tsunami shall also be assessed

and considered for the extreme water level analysis. Correlation and directionalities of wind wave,

swell, wind and currents shall be taken into account as well as wake from passing vessels and

diffraction of waves around coral outcrops and islands within Portland Bight.

2.20.5 Earthquake Loading

CONTRACTOR shall design the jetty to be operational under the 50-ARI conditions. Ultimate survival

with minor damage shall be designed to the 500-ARI condition.

2.20.6 Berthing Loads

Berthing loads shall be determined in accordance with BS6349 – Maritime Structures Part 4: Code of

Practice for Design of Fender and Mooring Systems and the results from detailed navigation

simulations based on site specific parameters.

Fenders shall be designed to cover the complete range of ships that will use the berth. The level of

each fender and face arrangement of it shall be designed to suit the hulls and to ensure that

maximum allowable hull pressure on the ships is not exceeded for all states of the tide and for all

carrier loading conditions. The breasting dolphins shall be located to accommodate the flat body area

of the parallel midsection of ships side.

The following berthing parameters shall be used:

a) Design berthing velocity ........................................... 0.15-m/s

b) Design berthing angle .............................................. 10°

c) Distance between fenders ....................................... 0.25 x LOA to 0.4 x LOA

d) Safety factor on berthing energy .............................. 1.5, for abnormal berthing

e) Softness factor for fender ......................................... 1

f) Maximum hull pressure for fender frame ................. 140-kPa

g) Coefficient of friction between vessel and fender .... 0.25

2.20.7 Mooring Loads

Quick Release Hooks (QRH) shall be provided for mooring of the carriers. The capacity of the QRHs

shall be based on the static and dynamic mooring analysis allowing variations in the carrier

positioning and different mooring pretension loads. Mooring loads shall be determined from the

assessment of all environmental loads on the carriers at berth. The mooring load calculation and

design of dolphins supporting mooring equipment shall comply with the BS Codes and OCIMF

Mooring Equipment Guidelines (MEG3), 2008.


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2.21 Load Combinations

The marine structures shall adequately withstand a number of loads including, but not limited to the

following:

a) The loads imposed by a ship berthing based on a maximum approach speed of 0.15-m/sec and

a maximum 10° berthing angle in accordance with BS 6349, OCIMF and PIANC guidelines.

b) The operational condition for a moored ship in accordance with OCIMF guidelines.

c) The load based on the 100-year design storm, including squalls, maximum water level and

wave crest elevation.

Worst-load case combinations shall be determined and applied in the design.

2.22 Deflection Limits

Particular attention shall be paid to the design of steel/concrete structures supporting piping or

equipment sensitive to deflection.

Maximum permissible deflections for the pipe support and equipment structures shall be the lesser of

the limiting deflection requirements for the topsides equipment and piping of the criteria as follows:

a) Loading arm support beam:

Maximum rotation in any direction .......................... 0.004-radians

b) Pipe support beams:

Maximum vertical deflection under live load ........... span/600

c) Approach road support beams................................. span/200

d) Vehicle manoeuvring area support beams .............. span/200

e) Pipe trestle pile bents:

Maximum lateral deflection ...................................... span/500

f) Pipe support structure:

Maximum differential settlement .............................. 0.001 x distance between supports

g) Walkway between dolphins:

Maximum vertical deflection ..................................... span/300


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3. FUNCTIONAL REQUIREMENTS

3.1 Layout of the SRT Jetty

The CONTRACTOR shall design the SRT jetty layout which shall include, but not be limited to:

a) Number of required dolphins,

b) Dolphin spacing relative to the vapour arm connection,

c) Dolphin setback from the berthing line,

d) Jetty head location and setback from berthing line,

e) Berth orientation (parallel to base of revetment),

f) Approach road by trestle.

3.2 Berth Configuration

The jetty shall be oriented to be perpendicular to the shore line.

The position of the berthing line is to be confirmed during the detail design and shall be based on

minimum keel clearance (1-m from the revetment and structures from all sides) and maximum

berthing/unberthing angle (10°). Failure modes of mooring lines, emergency unberthing, tug blackout,

etc. are to be considered and a risk appraisal strategy is to be developed and to be approved by all

stakeTBABCer during the detail design phase.

The jetty shall have two dedicated berths to receive:

a) The semi-permanently moored FSRU as specified in [3], and

b) Supply LNG carriers (LNGCs) ranging from 125,000-m³ to 180,000-m³.

The jetty berth shall be designed to accommodate the FSRU on one side of the berth and the range

of LNGC moored on the opposite side of the berth. The facility shall be able to operate continuously,

without night restrictions. All vessels shall be able to berth and un-berth without any tidal restrictions.

The berthing and un-berthing operation shall be tug assisted. The normal operation is to support the

arrival of ships with four tugs.

The design life of the jetty facilities is given in the BOD [1]. The jetty design shall incorporate all the

requirements of the IMO document International Ship and Port Facility Security (ISPS) Code. A full

and extensive evaluation of all proposed designs and associated construction methods shall be

carried out to demonstrate that design intent is achieved, environmental impact is minimised, the

ease of construction optimised and maintenance minimised.

The jetty configuration shall be optimised in conjunction with the final confirmation of the design

FSRU, LNGC vessel range and location and orientation of the jetty. Any LNG carrier that can’t be

fully accommodated at the berth shall be assessed and reported in detail in order that the implications

can be fully reviewed by the GOJ. Changes to the jetty berth may result in cases of non compliance.


Page 14

3.3 Jetty Structures

3.3.1 Service Platform

The service platform (for unloading/reloading) shall provide support for all topsides facilities and resist

all applied loads, including berthing and mooring of vessels. The platform shall have all necessary

access and space required for the operation of the berths. .

The service platform shall accommodate all items necessary for the operation of the marine facilities

and as required by the topsides design including but not limited to the following:

a) Loading arms for LNG and NG,

b) Independent power supply,

c) Hydraulic power pack systems,

d) Pipe work, supports and associated access platforms,

e) Jetty liquid KO drum,

f) All other pipe work, supports and associated access platforms,

g) Fire-fighting equipment and fire monitors,

h) Drainage systems and impounding basin,

i) Trenching for cabling and services,

j) Berthing aid systems,

k) Gangway,

l) Access to breasting dolphins,

m) Adequate space for access and maintenance of plant and equipment in accordance with the

topsides requirements,

n) Life-saving equipment,

o) Area lighting,

p) Walkway/stairway supports and,

q) Access/safety ladders,

r) Mobile crane access and hardstand,

s) Lay down area for provisions and spares.

The deck level of the jetty head shall be determined by the CONTRACTOR based on extreme water

level analysis. Under no cases shall the extreme water level surface (inclusive of all effects) reach

the underside level of the jetty structure (exclusive of the piling). The deck layout dimensions shall be

adequate for the items listed as above.


Page 15

At the rear of jetty head there shall be a vehicle turning area of clear dimensions adequate to enable

a mobile crane of lifting capacity up to ____ to manoeuvre and turn round. The adequacy of the area

shall be fully verified during the detail design. Clear pedestrian access shall be provided from the

vehicle turning area to walkway, stairways and ladders giving access to breasting dolphins, pilot boat

landing stages and the gangway.

Safe escape routes shall be provided from the moored vessels, dolphin walkways/stairways and jetty

head to the approach road.

3.3.2 Independent Power Supply

To be provided by Contractor.

3.3.3 Walkways

Walkways shall provide pedestrian access linking together all the breasting and mooring dolphins to

the jetty head and shall also permit access for small-wheeled trolleys. Cable trays shall be provided

as required by the topsides design along the walkways for service routes between structures.

The walkways shall be designed for carrying the mooring lines from the ships to the dolphins and the

grating level within the walkway shall not exceed a slope of 1 in 10 and there shall be no steps

between walkway terminations and the connecting structures. It should allow for safe and practical

access and egress from the outer MD’s via the jetty head to the approach road. Any lighting, safety

equipment, cable trays etc. shall be at the landward side of the walkways.

Intermediate walkway supports may be provided to limit the walkway spans, if required. The

minimum clear width of walkways connecting dolphins shall be 1.4-m

The structural form shall ensure that no obstructions are present on the seaward side of the walkway

at a height greater than 1.2-m above grating level to enable easy handing of lines. All members along

the uppermost limit of the structure shall be rounded so as not to chafe or abrade lines being passed

along. Ends of handrails shall be detailed so that mooring lines cannot catch on the handrail.

3.3.4 Approach Road

If an approach road is provided then the approach road shall provide access for vehicles between the

land and jetty head. The approach road shall also provide pedestrian access to the jetty head. The

approach road shall as a minimum include the following:

a) Vehicle access roadway,

b) Area lighting,

c) Drainage systems,

d) Clear emergency egress,

e) Vehicle crash barriers,

f) Handrails,

g) Safety equipment,


Page 16

h) Security access gates and fencing around the pipelines.

The width of the approach road shall be optimised to accommodate the above facilities and may be

widened at locations where lifting operations of pipe, valves and pipe rack components is required

using an adequately sized crane. Cross falls shall be provided to facilitate drainage. Drainage shall

be directly into the sea. Drainage runoff onto the underside of the deck shall be prevented by a drip

detail incorporated in the soffit of the deck slab along the entire length of the jetty.

3.3.5 Pipe Trestle

If a pipe trestle is provided then the trestle shall incorporate a pipe rack to accommodate lines as

shown on the piping conceptual layout drawings and other smaller diameter service pipe lines and

cables. Supports and anchors for the pipes and expansion loops shall be provided as required by the

topsides design. The pipe rack shall accommodate the following pipelines, as a minimum:

a) Two ring main lines for unloading (loading) and recirculation,

b) Vapour return line,

c) Firewater line,

d) Instrument air,

e) Utility air,

f) Nitrogen,

g) Potable water,

h) Process water,

i) Dry chemical hose reel.

The piping design shall review and confirm the provision for expansion loops along the approach

road/trestle during the initial and detail design phases.

3.3.6 Jetty Equipment Room

The jetty equipment room shall be provided on the jetty which accommodates the jetty specific

electrical and electronic equipments like loading arm remote controls, tools, spare mooring ropes etc.

Any cabinet/equipment related to the integrated mooring and environmental monitoring, piloting and

docking system shall be placed in the jetty equipment room. The room has to be monitored for any

outbreak of fire and protected. It shall also be provided with a fixed phone line and provided with a

window overlooking the jetty. It shall also be equipped with an ESD control button which is capable of

ESD loading/unloading with/without depressurisation.

3.3.7 Gangway

A gangway is to be provided at the jetty head, to allow boarding of personnel. The gangway design

needs to take into consideration the range of vessels provided at section 2.15. The gangway and its

components shall comply with national manned elevator codes, lifting appliance codes and shall meet

all national working at heights requirements where applicable.


Page 17

The location of the gangway shall be designed for safe access from the FSRU and LNGC to the jetty

head and should be located at a safe distance from any mooring line or any equipment. The position

of the gangway from the berthing line shall be such that self levelling steps are not required. The

position shall be optimised from the jetty "spotting line" with regard to the design vessels. The end

steps from the gangway (i.e. on board the LNGC) shall ensure safe step-down at all times on to the

FSRU/LNGC’s main deck.

A catwalk, with a gate, shall be fitted between the gangway tower platform and the unloading arm

platform.

3.3.8 Handrail

Handrail details to area of pedestrian access shall be provided as follows:

a) To the rear and inner side of each breasting dolphin,

b) To the rear and sides of each mooring dolphin,

c) To areas of pedestrian access around the perimeter of jetty head,

d) To both sides of the walkways on the jetty.

3.3.9 Vehicle Crash Barriers

If a vehicle access is provided then crash barriers to areas of vehicle access shall be un-tensioned

corrugated beam safety fence in accordance with the relevant statutory regulation, and incorporate a

handrail at 1,100-mm above pavement.

Crash barriers shall be provided on both sides of approach road on the jetty and around the vehicle

manoeuvring areas on jetty head. Loading shall be taken as 5-kN/m applied at the level of the

vehicle-type safety barrier.

3.4 Mooring Structures and Equipment

3.4.1 Breasting Dolphins

A minimum of 3 breasting dolphins shall be provided for each berth for the safe berthing and mooring

of the FSRU and range of supply LNGCs specified. Spacing of the breasting dolphins shall be in

accordance with OCIMF guidelines but ultimately the location is to be proven by detailed berthing and

mooring analysis for the FSRU and range of LNG carriers. The fenders are to be aligned with the

parallel midsection of the vessels in ballast condition. The location of the breasting dolphins shall

take into consideration the manifold off-sets for the FSRU/LNGC and un-obstructed mooring line

handling. The fenders shall be mounted in a way that no diver access is required to remove and

replace the fender. The fender and the pile design shall take the stiffness of the pile and fender

combination into consideration.

Each breasting dolphin shall as a minimum include the following items:

a) Fender assembly, complete with chains,


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b) 2 x Quick Release Hooks (QRH) with motorized capstans,

c) Walkway/stairway supports,

d) Unimpeded access from one dolphin to another via walkways,

e) Handrails,

f) Adequate working and access space,

g) Edge protection to prevent abrasion by mooring lines,

h) Cable tray/ducts for services,

i) Lifebuoys,

j) Area lighting.

The exact location of the dolphins and fenders is to be optimised by using a reputable static and

dynamic mooring analysis modelling tool, taking into consideration the design parameters in the

OCIMF and SIGTTO guidelines.

Structural design shall be in accordance with the “Mandatory Codes, Standards, Guidelines and

Recommendations” listed in section 4. Design forces exerted in the moored condition by fenders and

quick release hooks from the relevant analysis shall be considered concurrently with the limiting

operational environmental conditions.

Multiple hook assemblies shall be supplied to moor the vessel. The capacity of each hook of the

quick release hook assembly shall be fixed based on the highest mean breaking load of the vessel’s

mooring line. Each quick release hook assembly shall have a dual speed motorized capstan. The

orientation of the hooks shall be in accordance with OCIMF guidelines.

Plinths, ducts and cable trays shall be provided as required for services and lighting. Handrail shall

be fitted to the rear and sides of each dolphin platform and shall not impede mooring operations.

Edge protection shall be provided to the front and sides of each dolphin platform.

3.4.2 Mooring Dolphins

A minimum of 6 mooring dolphins shall be provided for the safe mooring of the FSRU and range of

supply LNGCs. Each mooring dolphin shall as a minimum include the following items:

a) Quick release hooks and motorised capstans for each berth for minimum of 18 mooring lines

for each berth,

b) Walkway supports,

c) Unimpeded access from one dolphin to another via walkways,

d) Handrails,

e) Edge protection to prevent abrasion by mooring lines,

f) Cable tray/ducts for services,

g) Lifebuoy,


Page 19

h) Jetty end lights on extreme outer dolphins only,

i) Area lighting,

j) Intercom from control room to ship via ship to shore connection.

Plinths, ducts and cable trays shall be provided as required for services and lighting. Handrails shall

be fitted to the rear and sides of each dolphin platform and shall not impede mooring operations.

Edge protection shall be provided to the front and sides of each dolphin platform.

The exact location of the dolphins is to be optimised by a detailed static and dynamic mooring

analysis considering the design parameters in OCIMF and SIGTTO guidelines.

Structural design shall be in accordance with the criteria listed in Section 5, “Mandatory Codes,

Standards, Guidelines and Recommendations”. Design mooring forces exerted by quick release

hooks from the relevant analysis shall be considered concurrently with the operational environmental

conditions.

Multiple hook assemblies shall be supplied to moor the vessel. The safe working load capacity of

each quick release hook assembly shall be fixed based on the highest mean breaking load of the

vessel’s mooring line. Each quick release hook assembly shall have a motorised capstan capable of

being switched between high and low speeds. The orientation of the hooks shall be in accordance

with OCIMF guidelines.

3.4.3 Fenders

To be determined by Contractor.

3.4.4 Quick Release Hooks

The quick release hooks shall have as a minimum, a Safe Working Load (SWL) equal to or greater

than the Minimum Breaking Load (MBL) of the mooring lines used onboard the FSRU and range of

supply LNGCs but not less than 180-tonnes. The appropriate location and distribution is to be

assessed based on a detailed static and dynamic mooring analysis for the FSRU and range of supply

LNGCs. The orientation of the hooks shall be in the direction of use which is typically perpendicular

to the berthing line for mooring dolphins and approximately 5 to 10° for hooks in breasting dolphins.

However it has to be optimised during detail design using the detailed static and dynamic mooring

analysis. All quick release hooks are to be provided with load cells as part of an integrated

Navigation, Docking, Mooring, MetOcean (NDMMO) system. Quick release hooks shall be able to be

released manually and automatically. The hook release system shall be designed such that not all

the hooks can be released at the same time as per the latest LNG industry best practices.

The quick release hook cluster at each dolphin shall be equipped with a mooring capstan with a

minimum capacity of 5-tonne, and shall be dual speed (i.e. full load speed of 18-m/min and light load

speed 36-m/min). Mooring load monitoring systems shall include the following minimum system

features:

a) Audible alarm,

b) Emergency stop,


Page 20

c) Foot pedal control,

d) Vertical bar chart display of load parameters,

e) Database,

f) Low/high load set point adjustments,

g) Hard copy printout,

h) Suitable for hazardous area.

3.5 Loading Arms

Six (6) 16’’ loading arms with Quick Connect Disconnect (QCDC) are to be initially installed for each

berth on the jetty head with the vapour arms located considering the most ergonomic and cost

effective design for jetty layout and dolphin spacing. The arms shall be capable of transfer rates and

fluid properties specified in the BOD [1].

Provision for an additional future loading arm for each berth shall be provided on the jetty deck. The

size and specifications of the loading arms are to be established during detailed design and must be

compatible with the manifolds on the design FSRU and range of supply LNGCs. The jetty head

structure and equipment shall be set-back to allow sufficient clearance for the vessels to roll either 3

degrees or the maximum roll and movement that is determined from the detailed mooring analysis.

The spacing of the loading arms shall be compatible with the manifold requirements of the vessels,

which conform to ‘OCIMF Recommendations for Manifolds for Refrigerated Liquefied Natural Gas

Carriers‘. The arms shall be capable of connecting in any configuration, including using the hybrid as

the vapour arm, so that they do not clash during a PERC separation. In any event they shall not be

more than 4000-mm apart (i.e. centre off-loading flange to flange). Access platforms for maintenance

of the loading arms are to be provided and the loading arms are to be equipped with motion

sensors/ESD devices. The fatigue life of the loading arms for all components that do not require

ongoing maintenance shall be the same as the facility. The loading arms are to be equipped with

isolation flanges which prevent discharge of static electricity.

The minimum offloading operational motion envelope is specified in the BOD [1]; the actual motion

envelope is to be assessed based on the range of supply LNGCs. The arms shall have quick-cam

connections or similar for connecting the arms to the ship’s manifolds, and safe access to the arms

for the maintenance having to use scaffolding or a crane barge. The Loading arms shall be

operational for all tidal conditions. In the stored position the loading arms shall survive a minimum

wind speed as defined in the BOD [1].

3.6 Safety Systems

3.6.1 Lifesaving Equipment

The minimum safety equipment to be provided is as follows:

a) Lifebuoys with life lines at a maximum spacing of 100-m along the jetty, one on each face of

the jetty head and one on each dolphin.


Page 21

3.6.2 Emergency Shut Down

The Emergency Shut Down (ESD) systems for LNG Loading arms shall be designed according to the

specifications mentioned in OCIMF Guidelines, ‘Design and Construction Specification for Marine

Loading Arms’. The ESD system ship to shore link typically consists of separate optical fibre,

pneumatic and electrical links with backup by portable VHF/UHF radios.

3.6.3 Port Security Plan


3.6.4 Fire Fighting


3.6.5 Cryogenic Fluid Hazard

All steel structures shall be provided with fireproofing and/or cryogenic hazard protection in areas

where spillage of LNG may occur. These shall apply to the jetty head and at any valve location along

the LNG lines.

The design of the marine structure shall ensure that LNG spillage will not result in structural failure.

3.6.6 Jetty Drainage

Containment areas shall be provided around equipment viz. hydraulic pumps that may give rise to

contaminated liquid on the jetty deck. These containment areas shall be drained to individual blind

sumps to permit manual removal of contaminated run-off or wash-down water during normal jetty

maintenance. All other areas shall be drained directly to the sea. The drainage of runoff onto the

underlying supports shall be provided.

3.6.7 Safety Accreditation

The SRT shall comply and meet all requirements as set-out in the SIGTTO information paper no. 14

[9]. CONTRACTOR shall address all risk reduction options as detailed in the appendix of the

SIGTTO information paper no. 14 [9] and CONTRACTOR shall address all issues and demonstrate

that all risks have been mitigated ALARP. The risk assessment is subject to approval by COMPANY.

3.7 Electronics and Communication

3.7.1 Integrated Mooring and Environmental Monitoring, Piloting and Docking System

An integrated, and fully compatible, Mooring and Environmental Monitoring, Piloting and Docking

System shall be provided for the jetty. It shall be equipped with a PPU (Portable Piloting Unit)

suitable for the operations in the terminal. It shall, as a minimum, be equipped with remote release

systems, mooring line load monitoring, vessel docking aid systems (such as approach radar etc) and

environmental and met ocean monitoring.


Page 22

3.7.2 Navigational Aids and Aero l ights

The jetty end lights shall comply with the internationally accepted requirements of the International

Association of Lighthouse Authorities, which set out common requirements for navigation markings

and lighting characteristics. The Maritime and Port Authority of Jamaica shall be consulted for

finalizing the navigation aids requirements. Necessity for Aero lights shall be studied during the detail

design stage in consultation with the Civil Aviation Authority of Jamaica and its specifications shall be

met.

3.7.3 Ship-to-Shore Communications

The ship-to-shore connection shall be designed to BS EN 1532, ‘Installation and Equipment for

Liquefied Natural Gas - Ship to Shore Interface’.

3.7.4 Metering

To be provided at the FSRU and ORF, see the regasification plant [4] and ORF and pipeline

functional specification [5].

3.8 Construction, Installation and Commissioning

3.8.1 Shore Protection and Dredging

The shore surrounding the terminal is to be protected using armour rocks. Particular attention has to

be paid for the design and construction of the marine structures affecting the shore protection and the

rocks has to be repaved as in original condition if any are affected during the construction. .

3.8.2 Pil ing


3.8.3 Surface Protection

A corrosion assessment and materials selection study shall be undertaken during the detail design

phase. All materials, equipment and corrosion management activities in the corrosion assessment

and materials selection study shall be based on the specified design life. All corrosion allowances or

materials recommended shall give a reasonable expectation of the equipment lasting for this design

life. The materials selection and corrosion control systems adopted for the loading arm and major

equipments, piping and associated fittings shall be designed to withstand a design life where possible

for 40-years.

As a minimum, 3 layers of epoxy coating system with a minimum total dry film thickness of 575 micro

meters shall be applied to all steel piles and other steel structures below the jetty deck (fender panels,

etc). All steel structures to be shot blasted and a marine grade shop primer is to be applied, cable

trays, handrails and all other steel structure (except piles) is to be hot-dipped galvanised and

protected by a marine grade epoxy coating system. The coating system design life for all submerged

parts shall be 40-years.


Page 23

All steel members and piles shall be designed without taking into account the protective coating or

cathodic protection.

Where zinc rich primers are used, care shall be taken to avoid the contamination of austenitic

stainless steel, nickel alloy or 9% nickel steels to avoid zinc embitterment.

For austenitic stainless steels, irrespective of design temperature (both insulated and uninsulated)

shall be externally painted to avoid external chloride pitting and chloride stress corrosion cracking.

To avert corrosion under insulation, the use of external insulation should be minimised, if used all

piping and equipments under insulation shall be painted. Like wise to minimise the risk of chloride

stress corrosion cracking of austenitic stainless steel, all insulation materials shall have residual

chloride content less than 10-ppm.

For the external corrosion protection of the jetty piles, both on the atmospheric zone, tidal zone and

the submerged pile in mud zone shall be paint coated. Rest of the pile submerged in the water shall

be protected by cathodic protection using sacrificial anodes.

Design, testing and operation of the system should be in accordance with DNV-RP-B401. Protective

coating should be provided for the concrete surfaces within the splash zone.


Page 24

4. MANDATORY CODES, STANDARDS, GUIDELINES AND RECOMMENDATIONS

SS CP 4 2003 Code of Practice for Foundations

SS CP 65 : Part 1 1999 Structural Use of Concrete - Design and Construction

SS CP 65 : Part 2 1999 Structural Use of Concrete - Special Circumstances

BS.EN 206 -1 2000 Concrete. Specification, performance, production and conformity

BS EN 1532 2008 Installation and Equipment for Liquefied Natural Gas - Ship to

Shore Interface

BS 4449 2005 Steel for the reinforcement of concrete

BS 5400 : Part 2 2006 Steel, Concrete and Composite Bridges - Specification For Loads

BS 5400 : Part 4 1990 Steel, Concrete and Composite Bridges - Code Of Practice for

Design Of Concrete Bridges

BS 5950 : Part 1 2000 Structural Use of Steelwork in Building

BS 6031 1981 Code of Practice for Earthworks

BS 6349 : Part 1 2000 Maritime Structures - General Criteria

BS 6349 : Part 2 1988 Maritime Structures - Design of quay walls. Jetties and dolphins

BS 6349 : Part 4 1996 Maritime Structures - Code of Practice for design of fendering and

Mooring systems

BS 6399 : Part 1 1996 Code of practice for dead and live loads

BS 6399 : Part 2 1997 Code of Practice for Wind Loads

BS 8004 1994 Code of Practice for Foundations

BS 8081 1989 Code of Practice for Ground Anchorages

BS 8110 : Part 1 1997 Structural Use of Concrete - Code of Practice For Design And

Construction

BS 8500 2006 Concrete. Complementary British Standard to BS EN 206-1

DNV-RP-B401 2005 Recommended Practice for Cathodic Protection Design

API RP 2A-LRFD 1993 Recommended Practice for Planning, Designing and Constructing

Fixed Offshore platforms - Load and Resistance factor design,


Page 25

American Petroleum institute (APl), 1st edition, 1993.

CUR/CIRIA/CETMEF

169 2007

Rock Manual. The use of Rock in Hydraulic engineering, 2nd

Edition, 2007.

CIRIA/CUR Report

154 2007 Manual on the use of rock in coastal and shoreline engineering

EAU 2006

Recommendations of the Committee for Waterfront Structures -

Harbours and waterways, 8th Edition; Translation of the 10th

German Edition.

IALA 1998 IALA Recommendation O-114, Recommendation on the marking of

Offshore Structures

PIANC 2001 Seismic Design Guidelines for Port structures, Marcom Working

Group 34, 2001.

PIANC 2002 Guidelines for the design of Fender systems

OCIMF 2008 Mooring Equipment Guidelines 3 (MEG3)

OCIMF 1999 Design and Construction Specification for Marine Loading Arms

OCIMF 1993 Safety Guide for Terminals Handling Ships Carrying Liquefied Gas

in bulk.

OCIMF 1978 Guidelines and Recommendations for the Safe Mooring of Large

Ships at Pier and Sea islands

OCIMF 1995 Prediction of Wind Loads on Large Liquefied Gas Carriers

OCIMF 1994 Recommendations for Manifolds for Refrigerated Liquefied Natural

Gas Carriers

OCIMF 2006 International Safety Guide for Oil Tankers and Terminals - 5th

edition 2006

SIGTTO 2000 Liquefied Gas Handling Principles on Ships and in Terminals

SIGTTO 1997 The Ship/Shore Interface

SIGTTO 1997 Site Selection and Design for LNG Ports and Jetties (Information

Paper No. 14)

SIGTTO 2003 LNG Operations in Port Areas: Essential best practices for the

Industry.

US Army Corps. 2001/02 Shore Protection Manual


Page 26

5. REFERENCES

[1] WorleyParsons, “Jamaican LNG Project, Basis of Design”, 402010-00260-00-GE-BOD-0001

[2] WorleyParsons, “Jamaican LNG Project, FSRU Operating Philosophy”, 402010-00260-MA-00-

PHL-0001

[3] WorleyParsons. “Jamaican LNG Project, Jetty Moored FSRU Functional Specification”,

402010-00260-MA-00-SPC-0005

[4] WorleyParsons, “Jamaican LNG Project, Regasification Plant Functional Specification”,

402010-00260-00-PR-SPC-0001

[5] WorleyParsons, “Jamaican LNG Project, ORF & Pipeline Functional Specification”, 402010-

00260-00-PR-SPC-0002

[6] SIGTTO, LNG Operational Practice, 2006

[7] SIGTTO, Guide for Planning Gas Trials for LNG Vessels, July 2008

[8] http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade

_or_remain_in_port.htm

[9] SIGTTO, “Site Selection and Design for LNG Ports and Jetties”, Information Paper No. 14, ©

1997

http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade_or_remain_in_port.htm�

http://www.nrlmry.navy.mil/~cannon/tr8203nc/jamaica/montegobay/text/the_decision_to_evade_or_remain_in_port.htm�


c:\users\ernie laptop\documents\jamaica lng\worleyparsons\word documents\402010-00260-00-ma-phl-0002 (jetty design philosophy).doc

Appendix 402010-00260 : 00-MA-PHL-0002Rev 0 : 25 August 2011\

Appendix 1 Design Premise


Page 1

1 . C o d e s a n d S t a n d a r d s

Table Appendix 1.1: Summary of Applicable Standards/Codes for Health &Safety

Code No. Title













Table Appendix 1.2: Summary of Applicable Standards/Codes for Environment

Code No. Title


System


1973

Table Appendix 1.3: Summary of Applicable Standards/Codes for Quality Assurance

Code No. Title





etc)


Page 2

Code No. Title




301)

Table Appendix 1.4: Summary of applicable Standards/Codes for IMR

Code No. Title




etc)




301)



API 570 Piping Inspection Code : Inspection, Repair, Alteration and re-rating




Table Appendix 1.5: Applicable Standards/Codes for Fendering & Mooring

Code No. Title


OCIMF Mooring Equipment Guidelines




DNV-OS-E301 POSMOOR


Page 3

Table Appendix 1.6: Applicable Standards/Codes for Mechanical Systems

Code No. Title





Pressure Piping


Systems




Ships Pt.4 Ch.7










Industry Services





Ships Pt.4 Ch.1




Page 4

Code No. Title


Services.


Industry Services






Ships Pt.4 Ch.5







Ships Pt.4 Ch.3



2 hazardous areas








Ships Pt.4 Ch.3



Rules for Classification of Rotating Machinery, Power Transmissions


Page 5

Code No. Title

Ships Pt.4 Ch.4





41.2



Ships Pt.4 Ch.4





Ships Pt.4 Ch.4



Industry Services.




Table Appendix 1.7: Applicable Standards/Codes for Fire Fighting

Code No. Title







Installations.



Page 6

Table Appendix 1.8: Recognised Codes for Pumps

Code No. Title




Industry Services





Ships Pt.4 Ch.1


Table Appendix 1.9: Recognised Codes for Lifting

Code No. Title



Table Appendix 1.10: Applicable Standards/Codes for Process Systems

Code No. Title


Natural Gas










Page 7

Code No. Title



Refineries



.API Std 610 Centrifugal Pumps for Petroleum, Heavy Duty Chemical and Gas

Industry Services





Industry Services



Process Piping



Pressure Piping


Fuel Gas System




Table Appendix 1.11: Applicable Standards/Codes for LNG Tanks

Code No. Title



Class Rules DNV Rules for Liquefied Gas Carriers, Pt.5 Ch.5


Page 8

Code No. Title



Natural Gas (LNG)

Table Appendix 1.12: Applicable Standards/Codes for Electrical & Instrumentation

Code No. Title

















1 and Zone 2


Natural Gas (LNG)


505)



requirements)


Page 9

Code No. Title



considerations)










IEC 60269/BS 88 Low Voltage Fuses



above 1kV and up to and including 52kV


atmospheres






1-kV up to 30-kV.





Page 10

Code No. Title




Spec Test Methods








Gases








60534-2Mod)






ANSI/ISA 75.22 Face-to-Centerline Dimensions for Flanged Globe-Style Angle Control




Page 11

Code No. Title










Metal Seats







Industries












Page 12

Code No. Title


















Chromatography

IEC 60079-0 Electrical Apparatus for Explosive Gas Atmospheres, Part 0:General

Requirements


Flameproof enclosures “d”


Pressurized enclosures “p”

IEC 60079-7 Electrical Apparatus for Explosive Gas Atmospheres, Part 7:Increased

Safety ‘e’


Safety “i”


Page 13

Code No. Title


Encapsulation “m”



450/750 V








polyolefin sheath












sector





Page 14

Code No. Title



other units










Data












Tactile Method





Page 15

Code No. Title


Table Appendix 1.13: Applicable Standards/Codes for Life Saving Appliances

Code No. Title





Table Appendix 1.14: Applicable Standards/Codes for Mooring

Code No. Title

API RP 2SK Recommended Practice for Design and Analysis of Stationkeeping






2SK)






Table Appendix 1.15: Applicable Standards/Codes for Installation

Code No. Title





Page 16


Table Appendix 1.16: Applicable Standards/Codes for In-service Operations

Code No. Title



section.

Table Appendix 1.17: General Mechanical



Marine Vessels







Table Appendix 1.18: General Structural

Reference Title






Table Appendix 1.19: Painting and Corrosion Protection

Reference Title


ISO 8501 Preparation of steel substrates before application of paints and


Page 17

Reference Title

related products -- Visual assessment of surface cleanliness












SSPC-PA-3 Paint Application No. 3, A Guide to Safety








ASTM A143 Safeguarding Against Embrittlement of Hot-Dip, Galvanized






c:\users\ernie laptop\documents\jamaica lng\worleyparsons\word documents\402010-00260-00-ma-phl-0002 (jetty design philosophy).doc

Appendix 402010-00260 : 00-MA-PHL-0002Rev 0 : 25 August 2011\

Appendix 2 Coatings for Structures, Piping and Equipment


Page 1

1 . In t r o d u c t io n

This Appendix defines the minimum technical requirements for Coating for Structures, Piping and

Equipment including valves, vessels and heat exchangers furnishing of all materials, labour,

equipment and tools, for the surface preparation, application and inspection.



Contract.

This document and the codes, specifications listed in section 1.1 below are not intended to be all-

inclusive. The requirements set forth do not relieve CONTRACTOR of his responsibility to perform all

services in a safe manner, to meet applicable codes and standards, to comply with government

regulations or to supply a product capable of performing its intended service.

1 .1 C o d e s , S p e c ific a t io n s a n d R e fe r e n c e s

The latest editions of all applicable codes, specifications and references shall define the minimum

requirements applicable to the subject work and no statement contained in this specification shall be

construed as limiting the work to such minimum requirements.

Wherever conflicts or omissions between codes, specifications and contract occur, the most onerous

condition shall apply. CONTRACTOR is responsible for reviewing the list below and informing

COMPANY of any omissions. All conflicts shall be formally brought to the attention of COMPANY.

Table Appendix 2.1: Applicable Codes

Reference Title












Page 2

Reference Title






ASTM A123

Zinc (Hot Galvanized) Coatings on Products Fabricated from Rolled,





ASTM A143

Safeguarding Against Embrittlement of Hot-Dip, Galvanized



NACE RP-0176

Corrosion Control of Steel, Fixed Offshore Platforms Associated with


2 . G e n e r a l R e q u ir e m e n t s

CONTRACTOR shall provide all labour, equipment and materials necessary to perform surface

preparation and coating in accordance with this Specification.

All CONTRACTOR personnel involved in surface preparation or coating work shall be qualified and

thoroughly trained as to the materials and specifications pertaining to the coating systems and shall

be provided with breathing apparatus and skin protection as per OSHA Hygiene and other applicable

safety standards.

CONTRACTOR shall be responsible for the proper storage, transportation and disposal of any and all

waste material (hazardous or otherwise) generated as a result of its operation. All handling of waste

material, including but not limited to spent abrasives, paints, thinners, solvents and cleaners shall be

in a safe and legal manner and shall comply with all applicable Regulations and Laws.

CONTRACTOR shall ensure that the coating system(s) specified herein fully comply with any local

and/or regional air quality or Volatile Organic Compounds (VOG) emission standards or requirements.

All materials shall comply with 2.80 Ibs per gallon VOC (maximum), except for high temperature

products. Should modifications or alternate coating systems be required to meet such standards or


Page 3

regulations, CONTRACTOR shall immediately notify COMPANY and submit details of the proposed

alternate system to COMPANY for review and acceptance.

All paint and surface preparation abrasives shall be free of lead, chromate and crystalline silica. In

addition, all paint materials shall meet latest guidelines with respect to VOCs.

Scaffolding or staging shall be used, where required, to provide easy access for surface preparation

and paint application. Scaffolding shall be such that operator's arms and body shall be free to

perform the necessary work and shall be provided with safety features that shall prevent accidents.

This specification and NACE Standard RP-0176 shall govern the procedures and materials required

for surface preparation and coating of the specified structures and/or equipment. No deviations or

exceptions from this specification shall be made without prior written approval of COMPANY.

The paint manufacturer's product data sheets and specifications for mixing, application and curing

shall be considered an integral part of this specification.

The coating systems shall be determined by CONTRACTOR. If a coating option is indicated, the

selected option shall be used as specified throughout the coating operation.

COMPANY shall designate paint manufacturers/suppliers. COMPANY reserves the right to specify

which manufacturer's coating system shall be used. Mixing of different manufacturers' products shall

not be permitted without written permission from COMPANY. If the coating system specified herein

by manufacturer's brand name is not consistent with the generic designation specified,

CONTRACTOR shall notify COMPANY immediately for instructions.

CONTRACTOR shall perform all touch-up painting to provide a completely painted assembly unless

specified otherwise. All field tie-ins, exposed surfaces of piling, field splices, weld areas, etc. shall be

painted. The coating system used for field touch-up painting shall be from the same manufacturer as

used during the fabrication of the structure. All coating materials required for offshore touch-up shall

be furnished by CONTRACTOR.

Multiple coats of paint shall be of colours approved by COMPANY which contrast to the colour of the

previous coat. CONTRACTOR shall verify the finish coat colour with COMPANY prior to the initiation

of material procurement. The final coat colours shall be as identified in Section 10.

All carbon and stainless steel surfaces that operate in the 65°c to 175°C range and that shall be

insulated shall be coated in accordance with a coating system to prevent chloride cracking that can

occur in this temperature range.

Pre-painted equipment purchased by CONTRACTOR, or others shall be re-coated by

CONTRACTOR if existing paint system does not meet or exceed those of this specification.

COMPANY shall determine if existing system of pre-painted equipment meets or exceeds this

Specification.

The following surfaces shall not be abrasive blasted, coated or painted unless otherwise specified:

aluminium, brass, rubber, glass, plastic, concrete, monel, copper-nickel alloys, bronze, fiberglass

reinforced plastic, PVC, stainless steel weather jacketing, insulation, plated surfaces, machined

flange faces, machined mounting pads for rotating equipment and instrument cases.


Page 4

Inside surfaces of manways, nozzles, bosses and other connections shall be blasted and coated with

the same system as the internal surfaces of the tank or vessel, where internal coating is specified.

Inorganic zinc primers may be used as pre-construction primers, but weld bevels must be free of all

the primer before welding. This can be done by masking prior to coating or by grinding or abrasive

blasting before welding. The coating-free area shall extend a minimum of 75-mm from the weld

bevel.

Weld-through primers shall not be used unless welding qualification tests show no detrimental effects

such as unacceptable porosity. The use of any weld through primers must be approved by

COMPANY in writing prior to their use.

All non-machined mating surfaces of equipment subject to outdoor exposure shall be completely

coated in accordance with these specifications prior to assembly (i.e. saddle base plates, skirt base

plates, bolted components, etc.).

All contaminated inorganic zinc primer shall be removed by abrasive blasting. The surface shall be

abrasive blasted to original designated finish and the zinc primer reapplied according to this

Specification.

3 . S u r fa c e P r e p a r a t io n

Unless otherwise approved by COMPANY, all fabrication, assembly, and non-destructive testing of a

particular component shall be complete before surface preparation begins.

CONTRACTOR shall protect all gasket surfaces, flange faces, valve stems, name plates, pressure

gauges, instrument cases, gauge glasses, electrical conduit and fixtures, instrument tubing, aids to

navigation, and all previously installed and coated equipment including galvanized equipment. If the

coating on any previously installed equipment is damaged, the damage shall be repaired or replaced

as directed by COMPANY. Where practical, electrical cable and instrument tubing shall be installed

after blasting.

CONTRACTOR shall remove all sharp edges and corners.

All bolt holes, including U-bolt holes in pipe supports, shall be drilled and ground smooth before

initiating blasting operations unless otherwise approved by COMPANY.

All oil and grease contamination shall be removed from the surface in accordance with SSPC-SP1,

"Solvent Cleaning", and using biodegradable water soluble cleaner prior to abrasive blasting. All

blasting shall be performed using dry blasting techniques in accordance with the SSPC specification

required for that particular area. Blasting anchor profiles shall be consistent with manufacturer's

recommendations for each coating application.

Except as otherwise specified, all surfaces shall be blasted to a "near-white metal" blast cleaned

surface finish as per SSPC-SP1 0 and shall demonstrate an anchor pattern of 1.5 to 2.0 mils peak to

peak.

Mechanical cleaning in accordance with SSPC-SP2 or SSPC-SP3 and solvent cleaning in

accordance with SSPC-SP1 may be required separately or in conjunction with each other when

blasting cannot achieve a near-white metal surface or when blasting shall damage fragile components


Page 5

(e.g. engine and compressor, etc.). Prior COMPANY approval is required for all areas where

mechanical and or solvent cleaning is to be used.

Except as otherwise specified, acid washes or other cleaning solutions or solvents shall not be used

on metal surfaces after being blasted. This includes any inhibitive washes intended to prevent rusting.

The abrasive may be coal slag, refractory slag or flint, sized to produce the required anchor profile

and graded to be free from clay, silt or other matter likely to become embedded in the steel surface.

Abrasive other than those listed above shall be approved by COMPANY. Silica containing abrasives

are not allowed to be used.

Blast materials containing impurities or inclusions shall not be allowed.

Blast cleaning operations shall not be conducted on surfaces that shall be wet after blasting and

before coating, when the surfaces are less than 3°C above dew point as measured by a sling

psychrometer, or when the relative humidity of the air is greater than 90%, without permission of

COMPANY.

It is desired that blasting be done during daylight hours. If blasting is allowed during the night, the

surface shall be swept clean and bright the next morning with fresh, light blasting to provide a "near

white" blasted surface.

Blasting shall be done in an area removed from painting operations and freshly coated surfaces to

prevent contamination. Contaminated coatings shall be solvent cleaned and then removed by

blasting to a near-white finish. The coating shall then be reapplied as specified in this specification.

All welded areas and appurtenances shall be given special attention for removal of welding flux in

crevices. Welding splatter, slivers, and underlying mill scale exposed during blasting shall be

removed or repaired.

After blasting, CONTRACTOR shall thoroughly clean all blast grit and dust from both internal and

external surfaces, including removal from crevices, recesses, etc.

4 . C o a t in g Ap p lic a t io n

Coating application shall be in accordance with this specification and the paint manufacturer's

recommendations included with the materials and shall be subject to inspection by COMPANY

Inspector at all times.

All coating materials furnished by CONTRACTOR shall be in unopened, clearly identifiable

containers. Mixing of different manufacturer's paints on the same surface shall not be permitted.

Containers shall remain unopened until required for use. No paint shall be used whose shelf life has

expired.

Only sufficient volumes for the appropriate pot life of application shall be mixed at one time.

Manufacturer's recommended pot life shall not be exceeded and when this limit is reached, the spray

pot must be emptied the material properly, disposed of and new material mixed.

All components shall be thoroughly stirred before, during and after mixing. Inorganic zinc coatings

shall be continuously stirred by mechanical spray pot agitators or other approved means during

application. The volume to be mixed shall be accurately measured. All mixing shall be done in clean


Page 6

containers, free from traces of grease, other type paints, or other contaminants. All containers shall

be kept covered to prevent contamination by dust, dirt or rain.

Coating application shall not be permitted: in the fog, mist or rain, when the steel is wet, when

surfaces are less than 3°C above the dew point as measured by a sling psychrometer, when the

relative humidity is greater than 90%, or when the temperature is below 10°C or above 38°C without

prior approval of COMPANY.

All painting done outdoors shall be done in daylight hours and completed at least one hour prior to

sundown. Indoor painting is allowed 24 hours a day if the specified metal and air temperatures and

relative humidity requirements are met inside the building at all times during preparation, painting and

curing.

Blast-cleaned surfaces shall be coated with primer during the same day as blasting and at least one

hour prior to sundown of that day, and also before any rusting occurs. A minimum of 75-mm around

edges of blasted areas shall be left unprimed. Blasting shall continue a minimum of 25-mm into

adjoining coated surface. Any blast-cleaned surfaces that are not primed and are wet by rain or

moisture shall be re-blasted prior to application of primer.

Material surface shall be clean, dry and free from dust before application of any coat of paint. In areas

where inorganic zinc is used as a primer, the surface shall be pressure cleaned with fresh water when

the primer remains exposed in excess of 48-hours prior to top coating, unless specifically approved

by COMPANY representative on a case by case basis. This shall ensure removal of dust and

contamination in the porous zinc film.

All coatings shall be allowed to dry and cure thoroughly in accordance with the manufacturer's written

instructions prior to application of a succeeding coat. All coats shall be applied as soon as possible

after the minimum specified drying time of the preceding coat.

Damage to intermediate coats, prior to application of the next coat, shall be repaired by

CONTRACTOR to provide the coating sequence and film thickness as specified in the coating

systems.

Coatings shall not be applied when the wind speed exceeds 24-km per hour unless specifically

approved by the onsite COMPANY representative on a case by case basis.

Large surfaces shall always receive passes in two directions at right angles to each other (cross-

hatched). Parallel passes are acceptable in all other areas.

All excessive over spray shall be screened off.

No coating shall be placed on or within three inches of edges prepared for field welds. Succeeding

coats of paint shall be stopped a minimum 75-mm between coats at field weld locations (i.e. primer

coat stops 75-mm from field weld, intermediate coat stops 75-mm from field weld, etc.).

Atomizing air and paint pot pressure shall each be regulated to the minimum amount required to

properly atomize material for application without dry spray, runs or sags. If a particular coating

system requires a special pump(s) or equipment, then only that specific equipment shall be

acceptable for coating application.


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An adequate moisture trap shall be placed between the air supply and pressure feed to gun. Trap

shall continually bleed off any water or oil from air supply. Lines and pot must be cleaned before

adding new materials. Suitable and working regulators and gauges shall be provided for both air

supply to pressure-pot and air supply to pressure gun.

Separate regulators shall be used to adjust the paint pot pressure and atomization pressure. Each

regulator shall be provided with a pressure gauge operating properly at all times.

Coating may be brushed on all areas which cannot be properly spray coated. Use brushes of style

and quality that shall enable proper application of materials and in accordance with the specified

coating thickness. Inorganic zinc coatings shall not be applied by brush, even for touch-up or repair.

Ring grooves and raised face surfaces of flanges shall be protected from abrasive blasting and paint.

The complete coating system shall be applied to faces other than the ring groove or the raised face

prior to installation. Swabs should be used to coat the inside of flange bolt holes. Flange bolt holes

do not require the finish coat of paint.

The finished job shall not contain sags, runs, wrinkles, spots, blisters, or other application flaws.

Holidays in the final coat at edges, corners, welds and inaccessible areas may be protected by

spraying or hand brushing an additional layer of topcoat provided excessive build-up does not occur.

The coatings described in this specification contain flammable solvents. The vapour from these

solvents may be harmful and cause skin and eye irritation. The resinous components of the primers

and laminating resin may cause serious delay dermatitis. Employees involved in coating work shall

be provided with breathing apparatus and eye and skin protection as necessary.

Inorganic zinc requires a minimum relative humidity of 50% to cure. If the relative humidity is below

50% then special precautions must be taken to insure the cure of the zinc primer. Consult supplier

and COMPANY representatives for further instructions.

All welds and edges to be coated shall be brush stripe coated prior to application of each coat. Zinc

primer coats are not to be stripe coated.

When applying coatings over inorganic zinc primer a mist coat is required to seal the surface and

prevent surface bubbling of topcoats. A mist coat shall consist of a thin coat (1-2 mils) of the coating

being applied over the zinc primer. This should be allowed to tack up before applying a full coat over

the top of the mist coat. Consult Supplier for proper methods of applying a mist coat using their

materials.

5 . R e p a ir a n d Da m a g e d Ar e a s (To u c h Up )

All external surfaces where coating is damaged during fabrication, transportation, and erection shall


a) Top coat damaged, but, base coat undamaged: Repair by removing damaged coating with

sandpaper or other means acceptable to COMPANY (wire brushing shall not be acceptable),

feather edges of adjacent painted surfaces and apply 2.0 to 3.0 mils of polyurethane top coat.


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b) Coating damaged to base metal: Repair by blasting damaged area to SSPC-SP10 Near-White

metal, feather adjoining paint surfaces with sandpaper to provide a smooth surface transition

and apply an appropriate four coat system.

c) Coating damaged to base metal where blasting is not approved: Mechanically cleans and

applies the appropriate three-coat system specified by CONTRACTOR.

Care shall be taken to avoid damaging the coatings surrounding repaired areas and to assure

complete tie-in of the coating with surrounding areas.

All internal surfaces where coating is damaged during fabrication, transportation, and installation shall


a) Remove damaged area by spot blasting to white metal (SSPC-SP-5) and feather into

surrounding coating with sandpaper. Clean all loose material from the surface in accordance

with SSPC-SP-1.

b) Re-coat with same coating system using same manufacturer.

CONTRACTOR shall repair the coating on all damaged areas prior to final acceptance by

COMPANY.

All clamps and brackets shall be removed to allow for the full coating system to be applied under the

bracket or clamp. Care should be taken when securing the brackets or clamps that the coating under

the bracket or clamp is not damaged.

6 . G a lv a n iz in g

All grating, handrails, ladders, stairs, cages, toe plates, guard rails, clips, and miscellaneous items

defined in the drawings are to be hot dip galvanized as per ASTM A123. The weight of the zinc

coating shall average not less than 915-grams per square meter and no specimen shall show less

than 760-grams per square meter. Dry film thickness of the zinc coating shall not be less than 2.5-

mm and shall not exceed 8.0-mm. Consult COMPANY representative when coatings exceed 8.0-

mm.

Hot dip galvanizing of bolts, nuts, washers and miscellaneous manufactured items shall be performed

in accordance with ASTM A153 "Zinc Coating (Hot Dip) on Iron and Steel Hardware" and ASTM A143

"Safeguarding Against Embrittlement of Hot, Galvanized Steel Products".

Galvanized members which are to be permanently fixed to the structure by welding shall be attached

after the supporting members are primed and Intermediate coated, but before top coat is applied to

the supporting members.

All damage to galvanized items caused by fabrication, welding, handlIng, or loading out shall be

blasted and coated with the system specified in CONTRACTOR’s coating systems.

All grating support members shall be primed and intermediate coated before securing the grating and

then those weld areas shall be near-white metal blasted, re-primed and fully coated.


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7 . In s p e c t io n

COMPANY shall have the right to inspect any equipment and material used, or to be used in the

performance of the specified work and may reject any equipment, material or work not conforming to

the specifications either before or after work commences.

COMPANY representative shall have access to all work while being performed. COMPANY shall be

given at least two days notice prior to commencement of any work described in this specification.

Surface preparation and/or coating application shall not be done in the absence of COMPANY

Representative without his knowledge or consent.

CONTRACTOR shall arrange to have a technical representative from the coatings manufacturer

present to assist and witness the initial application of each coating system for all major jobs such as

jackets, decks, skids, and multiple pieces of equipment. Further technical assistance from the

coatings manufacturer shall be obtained, when problems arise or when COMPANY requests such

assistance.

A copy of this specification and manufacturer's recommendations shall be kept at the job site.

CONTRACTOR shall provide and utilize wet and dry film thickness, temperature and humidity gauges

as required by the performance of the work. Paint foreman shall inspect and monitor the work of

painters and blasters under his direction.

All prepared surfaces shall be inspected and approved by COMPANY's representative before primer

is applied. Acceptance of the blast cleaned surface shall be made by COMPANY's representative,

based on a visual comparison with Clemtex "Anchor Pattern Standards", Keane-Tator "Surface Profile

Comparator", Swedish pictorial surface preparation standards SSPC-VISI-1, the appropriate SSPC

surface preparation specifications.

Measurement of paint dry film thickness shall be made with a gauge, which has been calibrated

against National Bureau of Standards "Certified Coating Thickness Calibration Standards" in the

presence of COMPANY's representative. Failure to meet specified thickness ranges shall cause work

to be rejected.

Work shall be rejected because of poor workmanship. Poor workmanship is defined as improper

surface preparation, inadequate drying or curing, excessive paint build-up, dirt or dust inclusions, over

spray, pinholes, runs and sags, or inadequate film build, etc.

Rejected work shall be repaired to meet the requirements of this specification.

Acceptable finish work must be free of abrasions and must be uniform in color and appearance.

A final inspection shall be made by COMPANY representative prior to acceptance. Representatives of

CONTRACTOR and paint manufacturer may be present. Any defective areas shall be repaired by

CONTRACTOR at no additional cost to COMPANY.

8 . S p e c ia l C o a t in g R e q u ir e m e n t s

Upon completion of protective coating work, CONTRACTOR shall provide stenciled paint

identification of all major items of equipment. Identification shall include the equipment item number


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and description as indicated on drawings. Two opposite sides shall be stenciled with BLACK paint

with numbers and letters approximately 75-mm high.

In areas with non-slip coating requirements, dynamic wet friction factor shall be 0.8 or greater.

9 . C o a t in g S y s t e m s

CONTRACTOR shall specify for COMPANY approval a listing of the complete coating system for all

repaired and/or new items to be included as part of the FSRU. It shall include, but is not limited to the

following:

a) Structural steel

b) Piping

c) Vessels

d) Equipment

e) Exhaust/Flare torch/ Vent

1 0 . C o lo u r S e le c t io n Ta b le

Table Appendix 2.3 Colour Selection Table

Item Description Finish Colour

Structural Steel: Framing Components, Pipe Supports, I-Beams, Legs,

Handrails, Stairs Cases, Metal Buildings, Components In And Above

The Splash Zone, Boat Landings, Riser Guards And Cranes

Topcoat (Yellow)

Production Equipment: Vessels Packages, Piping, Wellheads,

Conductor Pipe, Header Packages, Slop Oil Tanks, Pumps,

Compressors, Turbine Packages, Generator Packages, Valves And

Misc. Skid Packages

Topcoat (Grey)

Paint System 14 for Subsea Christmas Trees, Subsea Manifolds,

Subsea Templates, Riser Arches, Living Quarters and PLEMS piping.

Topcoat (White)

Sub sea Structures and Manifolds

Piping

Structural

Topcoat (White)

Topcoat (Yellow)

Flare Booms And Transmission Towers OSHA Safetv Red & White

High Temperature Components (Exhaust Stacks, Fire Tubes, Etc.) Aluminum

Plated Steel Deck Surfaces Topcoat (Grev)


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1 1 . Do c u m e n t a t io n

CONTRACTOR shall submit to COMPANY for approval a painting and anti-corrosion coating data

book containing the following information as a minimum:

a) Material certificates

b) Inspection equipment and calibration certificates

c) Inspection and testing reports

d) Release certificates

All data shall be supplied in hard copy and electronic format.

Attachment 09 - Pipeline & ORF Operating Philosophy

GOVERNMENT OF JAMAICA: OFFICE OF THE CABINET JAMAICA LNG PROJECT PIPELINE & ORF OPERATING PHILOSOPHY

Page i

Jamaica LNG Project Pipeline & ORF Operating Philosophy

402010-00260 – 00-PR-PHL-0001

25 August 2011


Page ii

CONTENTS 1. INTRODUCTION ................................................................................................................ 5

1.1 Background ......................................................................................................................... 5

1.2 Pipeline & ORF Operating Philosophy................................................................................ 5

1.2.1 Scope ..................................................................................................................... 5

1.2.2 Objectives .............................................................................................................. 5

1.3 Abbreviations ...................................................................................................................... 6

1.4 Philosophy Document Outline ............................................................................................ 7

2. BASIS OF PHILOSOPHY ................................................................................................... 9

2.1 Safety .................................................................................................................................. 9

2.2 Health .................................................................................................................................. 9

2.3 Environment ........................................................................................................................ 9

2.4 Emergency Equipment ..................................................................................................... 10

2.5 Personal Protective Equipment ........................................................................................ 10

2.6 Emergency Response Plan .............................................................................................. 10

3. STAFFING, COMPETENCY, DEVELOPMENT AND TRAINING .................................... 11

3.1 Staffing .............................................................................................................................. 11

3.2 Competency, Development and Training ......................................................................... 11

4. PIPELINE OPERATING PHILOSOPHY ........................................................................... 12

5. ORF OPERATING PHILOSOPHY .................................................................................... 13

5.1 Pig Receiver ...................................................................................................................... 13

5.2 Pipeline Filters .................................................................................................................. 13

5.3 Fiscal Metering .................................................................................................................. 13

5.4 Future Requirements ........................................................................................................ 14

5.5 Pressure Letdown ............................................................................................................. 14

5.6 Gas Preheating / Heat Recovery ...................................................................................... 14

5.7 Cold Vent System ............................................................................................................. 15

5.8 Utility Systems .................................................................................................................. 15

5.8.1 Electrical Power System ...................................................................................... 15


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5.8.2 Instrument Air System .......................................................................................... 15

5.8.3 Utility Water System ............................................................................................. 16

5.8.4 Fire Water System ............................................................................................... 16

6. SRT OPERATING PHILOSOPHY .................................................................................... 17

7. ORF RELIEF AND VENT SYSTEM OPERATION PHILOSOPHY ................................... 18

7.1 Relief Contingencies ......................................................................................................... 18

7.2 Blowdown .......................................................................................................................... 18

7.3 Manual Drains and Vents ................................................................................................. 18

8. SHUTDOWN AND CONTROL SYSTEMS ....................................................................... 19

8.1 Shutdown Hierarchy ......................................................................................................... 19

8.2 System Architecture .......................................................................................................... 20

8.3 Process Monitoring, Control and Safeguarding ................................................................ 20

8.4 Start-up and Restart ......................................................................................................... 20

9. LOSS PREVENTION PHILOSOPHY ............................................................................... 21

9.1 Fire and Gas Detection ..................................................................................................... 21

9.2 Active Fire Protection ........................................................................................................ 21

9.2.1 Water Spray Systems .......................................................................................... 22

9.2.2 Portable and Mobile Dry Chemical Powder Extinguishers .................................. 22

9.2.3 Manual Alarm Call Points ..................................................................................... 22

9.3 Passive Fire Protection ..................................................................................................... 22

10. INSTRUMENTATION, AUTOMATION AND TELECOMMUNICATION PHILOSOPHY .. 24

10.1 Instrumentation ............................................................................................................. 24

10.2 Control Room and Human Machine Interface .............................................................. 24

10.3 Telecommunications .................................................................................................... 24

11. MAINTENANCE PHILOSOPHY ....................................................................................... 26

11.1 Maintenance Management ........................................................................................... 26

11.2 Frontline Maintenance .................................................................................................. 26

11.3 Condition Monitoring, Testing and Inspection .............................................................. 26

11.4 Certification .................................................................................................................. 27

11.5 Spares Holding ............................................................................................................. 27


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11.6 Permit to Work/Work Orders ........................................................................................ 27

12. ESCAPE, MUSTER, EVACUATION AND RESCUE ........................................................ 29

13. MISCELLANEOUS OPERATIONAL PHILOSOPHIES ..................................................... 30

13.1 Simultaneous Operations ............................................................................................. 30

13.2 Materials Handling ........................................................................................................ 30

13.3 Accessibility .................................................................................................................. 30

13.4 Impact Protection ......................................................................................................... 30

13.5 General Housekeeping ................................................................................................. 30

14. REFERENCES ................................................................................................................. 32


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1. INTRODUCTION

1.1 Background








bauxite/alumina production. The initial estimate of demand in these sectors is equivalent to about 0.8

million tonnes of LNG per year, with the expansion of the bauxite/alumina sector and construction of

new IPPs likely to raise the base LNG demand to around 2.5 million tonnes per year. It is expected






1.2 Pipeline & ORF Operating Philosophy

1.2.1 Scope

This document outlines the operating philosophy for the Project natural gas export system,

comprising the pipeline and Onshore Receiving Facility (ORF). It is anticipated that this document

shall be updated and re-issued on an “as-required” basis throughout the development of this project.

Further details of the functional requirements of these facilities are available in the Pipeline and ORF

Functional Specification [2].

Operational philosophies associated with the upstream Storage and Regasification Terminal (SRT),

also part of the Jamaican LNG project, are beyond the scope of this document. Further details are

available in [3].

1.2.2 Objectives

The objective of this safety philosophy is to describe the facility configuration in terms of hazard

assessment, general layout requirements, safety systems, equipment and procedures necessary to

protect against major hazards which could lead to harm to personnel, damage to facilities, loss of

production or cause pollution of the environment, and to prescribe the loss prevention measures

which will be adopted in the design of this facility to achieve the following:

• Avoid exposure to potential hazards;

• Minimise the potential for hazardous occurrence;


Page 6

• Contain and minimise the consequence of the hazards;

• Provide means of escape and evacuation from such hazards;

• Ensure the installation is designed to a safe standard;

• Provide a safe working environment for personnel.

This document also presents the key operational requirements to be incorporated into the design of

the pipeline and ORF. Operational requirements are set out in general terms; the detailing of which

shall be undertaken in the development of the Basis of Design (BOD) document [1].

1.3 Abbreviations




ABS American Bureau of Shipping

ALARP As Low AS Reasonably Practicable


BDV Blowdown Valve


COMPANY Government of Jamaica, acting on behalf of the Jamaica Gas Trust

CONTRACTOR Pipeline & ORF BOOT Contract Owner

dB Decibel

dB(A) Decibel with A-weighted Scale

DG Diesel Generator


FGS Fire and Gas System

FVO First Valve On


HMI Human Machine Interface

I/O Inputs/Outputs

IR Infrared

JGT Jamaica Gas Trust


LVO Last Valve Off

MAC Manual Alarm Call Points

MCR Main Control Room

MTPA Million Tonne Per Annum


Page 7


NFPA National Fire Protection Association


PA Public Address


PFP Passive Fire Protection

PG Power Grid

PPE Personal Protective Equipment

PSD Process Shutdown

SCBA Self Contained Breathing Apparatus

SDV Shutdown Valve

SIS Safety Instrumented System


TBABC To Be Advised By CONTRACTOR, subject to COMPANY approval

USD Unit Shutdown

UV Ultra Violet

WP WorleyParsons

1.4 Philosophy Document Outline

This operating philosophy document is divided into the following key sections:

• Section 2: covers the basis of this philosophy, including brief overview of the health, safety and

environment (HSE);

• Section 3: covers the staffing, competency, development and training requirements to ensure

safe operations of the pipeline & ORF;

• Section 4: covers the pipeline operating philosophy;

• Section 5: covers the ORF operating philosophy;

• Section 6: covers the SRT operating philosophy;

• Section 7: covers relief and vent system operation philosophy;

• Section 8: covers the ORF shutdown and control systems;

• Section 9: covers the loss prevention philosophy;

• Section 10: covers the instrumentation, automation and telecommunication philosophy;

• Section 11: covers the maintenance philosophies associated with the pipeline and ORF.

• Section 12: covers the escape, muster, evacuation and rescue philosophies; &


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• Section 13: covers other miscellaneous operational philosophies associated with the pipeline

and ORF.


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2. BASIS OF PHILOSOPHY

2.1 Safety

The design and operation of the pipeline and ORF shall conform to the requirements of the relevant

legislations and local Jamaican laws and regulations and applicable codes and standards. The safety

in design philosophy shall be one of identification of potential hazards under normal perceived

operating circumstances and designing to reduce the risk from these hazards to ALARP (As Low As

Reasonably Practical).

2.2 Health

Health hazards shall be identified (such as chemicals, toxic material, noise and heat etc) and

appropriate means incorporated into the design to minimise the risk to personnel from these hazards.

A database of all hazardous materials shall be established during the detailed design phase of this

Project. This database shall include Material Safety Data Sheets (MSDS) for all chemicals to be used

at the ORF, and shall be available electronically and in hard copy.

A separate safety management system for handling/storing and treating exposure to hazardous

materials/chemicals shall be developed during the detailed design phase of this project.

A person qualified to act as a paramedic shall be present at the ORF at all times.

Asbestos or materials containing asbestos, tar-coal epoxy coatings and heavy metals shall not be

used in the design of or during the operation of the ORF.

Personnel shall not be subjected to passive smoking.

2.3 Environment

The pipeline & ORF shall meet the local Jamaican legislative and COMPANY requirements in relation

to environmental management. An environmental management plan shall be developed during

detailed design phase of this project, which shall outline any conditions imposed by local regulators in

relation to environmental management.

Consistent with COMPANY policy and local Jamaican legislative requirements, all reasonable

measures shall be taken to avoid direct discharge of pollutants to the environment. The design and

operation of the ORF shall allow for containment of minor spills.

A design and operating philosophy of energy conservation shall be pursued where practical.

The use of halon’s or ozone depleting chlorofluorocarbon (CFCs) is prohibited. Alternatives shall be

used which have less effect on the environment (ozone Layer).

Operational venting from the ORF cold vent stack shall be limited to ALARP.

Monitoring of effluents (gaseous and liquid) discharged to the environment shall be conducted to

provide an overall inventory of pollutant discharges.


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2.4 Emergency Equipment

The ORF shall be equipped with all necessary emergency equipment:

• Fire fighting equipment (such as monitors, hose reels etc.);

• A fully equipped First Aid room;

• Safety showers, eye wash, first aid kits; and

• Breathing apparatus (BA) sets.

2.5 Personal Protective Equipment

Staff shall be supplied with personal protective equipment (PPE) to enable safe operation and

maintenance of the ORF.

2.6 Emergency Response Plan

An Emergency Response Plan shall be developed for the ORF. This plan shall address all credible

events and shall cover:

• An emergency including, but not necessarily limited to gas release, fire, explosion, vessel

collision;

• Medical emergency response;

• Hurricane plan; and

• Environmental emergency.

Emergency response simulation exercises shall be carried out and shall be defined within the HSE

Plan. A twice a year a simulation exercise shall be conducted which shall involve the ORF operating

and Emergency Management Teams. Refer to Section 12 for further details of muster and

evacuation requirements.


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3. STAFFING, COMPETENCY, DEVELOPMENT AND TRAINING

3.1 Staffing

Staffing numbers shall be sufficient for completion of all routine operations and maintenance activities

such that technical integrity is assured and overall gas export availability is optimised. Additional

contract labour shall be utilised for shutdown and specialist maintenance activities as required.

ORF normal operational staffing shall include, but not limited to, the following personnel/disciplines:

• Plant superintendent;

• Production operators;

• Technicians, including mechanical and instrumental/electrical.

ORF staffing requirements shall be optimised to ALARP so as to reduce risk and minimise operating

expenses (OPEX). Notwithstanding this, staffing shall be sufficient to cover two shifts and provide a

typical relief rate of 20%. Wherever possible, the recruitment strategy should target multi-skilled

operators who are capable of carrying out routine frontline maintenance, testing and inspection.

CONTRACTOR shall determine final manning requirements, inclusive of role descriptions and the

corresponding responsibilities, for COMPANY approval.

3.2 Competency, Development and Training

A Competency Based Training and Assessment (CBTA) system shall be established as part of the

management system. The CBTA system shall ensure that individuals are trained in all safety and

production critical activities and they shall be objectively assessed to be competent to perform the

necessary tasks.

Where appropriate the CBTA system shall also include proficiency in English. General cultural

awareness training shall be provided where this is required.

The CBTA system shall be designed and implemented to assure competency of operations personnel

prior to ORF / pipeline start-up.

Staff development shall be continuously addressed so that the workforce skills base is broadened

with the objective of leading to an improvement in operating efficiency and safety. This shall be

carried out as part of an annual appraisal process.


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4. PIPELINE OPERATING PHILOSOPHY

The pipeline will transfer regasified LNG from the SRT to the ORF. Pipeline entry pressure shall be

controlled to ensure design gas rates can be delivered to the ORF at end-user arrival pressure

requirements. The regasification unit outlet temperature shall also be controlled to ensure gas

delivery to the ORF at greater than the minimum end-user arrival temperature requirements under all

operating temperature conditions. Refer to the Project Basis of Design [1] for further details.

Due to the short length and relatively low operating pressures of the pipeline, “line packing” is not

expected to provide significant operational benefit. The pipeline shall be fitted with a “Last Valve Off”

(LVO), located immediately downstream of the SRT regasification unit outlet manifold, as well as a

“First Valve On” immediately upstream of the ORF for the purposes of emergency shutdown. These

valves will enable isolation of the SRT, pipeline and ORF inventories as required to prevent

escalation, for example in the event of a confirmed fire at the SRT.

Pipeline mechanical design shall be completed according to the basis outlined in the BOD document

[1]. Given the sales gas is clean and dry, the requirement for injection of corrosion inhibitor is not

anticipated. On the same basis, pigging requirements are envisaged to be infrequent, specifically for

initial pipeline commissioning and afterwards only for intelligent pigging surveys as required by the

applicable certifying and regulatory bodies. CONTRACTOR shall advise final pigging survey

requirements for COMPANY approval.

Gas flow rates shall be reduced (as required) to the daily contract quantity [1] during the intelligent

pigging operation such that the maximum allowable intelligent pig velocity is not exceeded.


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5. ORF OPERATING PHILOSOPHY

Regasified LNG from the SRT is received at the ORF. The ORF shall be designed for receipt of the

full range of gas flow rates detailed in the BOD document [1]. Pipeline entry pressure shall be

controlled to ensure design gas rates can be delivered to the ORF at end-user arrival pressure

requirements. The regasification unit outlet temperature shall also be controlled to ensure gas

delivery to the ORF at greater than the minimum end-user arrival temperature requirements under all

operating temperature conditions. Refer to the Project Basis of Design [1] for further details.

From the ORF, the gas will be distributed to the Project’s end-users via user or third party pipeline.

Pressure letdown, preheating and cold recovery requirements shall be the responsibility of the gas

end-users.

5.1 Pig Receiver

The Pig Receiver is provided to enable pipeline pigging during commissioning as well as for

performing intelligent pigging surveys as required by the applicable certifying and regulatory bodies.

Given pigging requirements are envisaged to be infrequent, the CONTRACTOR may provide tie-ins

for pig receipt and utilise a temporary receiver as required in preference to installation of permanent

equipment. In the event that a temporary arrangement is pursued, supply of all equipment for

pipeline pigging as needed shall be the responsibility of the CONTRACTOR.

The CONTRACTOR shall also advise final pigging survey requirements for COMPANY approval.

5.2 Pipeline Filters

Fully spared pipeline filters shall be provided to remove any potential debris or mill scales from the

pipeline, in particular during the commissioning phase. Filter design conditions and capacity shall be

consistent with ORF requirements detailed in the BOD document [1]. Partial filter blockage shall be

indicated by differential pressure gauge, which shall initiate an alarm at the PCS. Operator action

shall be to perform manual change-over from duty to standby filter unit on alarm. The dirty filter shall

be returned to serviceable condition as soon as practicable.

5.3 Fiscal Metering A metering system shall be provided at the ORF to enable fiscal metering of sales gas transfer from the ORF operator to the end-users. The fiscal gas metering system shall be designed as per International American gas Association (AGA) standards and shall be complete with, but not limited to, the following equipment and requirements:

• Fiscal application approved, redundant, multi-path ultrasonic flow meters

• Gas Chromatograph and sampling system

• Hydrocarbon Dewpoint Analyser

• Water Content Analyser

• Isolation and switching valves


Page 14

• Flow computers

• On skid piping, instrumentation and equipment

• Meter proving

The flowmeters will normally be operated as parallel runs with only one run online at a time.

Changeover between the flow metering runs shall be achievable remotely through commands

initiated from the Process Control System (PCS) and activated through the flow metering computers.

Configuration of the changeover sequence shall ensure that a gas flow path from the inlet to the outlet

of the skid is maintained at all times during changeover.

The parallel ultrasonic metering runs shall be capable of being lined up serially via a skid based

crossover complete with two full bore isolation ball valves, to facilitate cross-checking of meter

indications. Changeover between parallel and series operation of the flow meters shall be achievable

remotely through commands initiated from the PCS and activated through the flow metering

computers.

The flowmeter in service shall determine actual (uncorrected) gas flow by measurement of gas

velocity. Gas compressibility, density, calorific value (heating - LHV) and Wobbe Index (WI) shall be

calculated by the Gas Chromatograph from the measured compositional data. Using this and the

flowing pressure and temperature measurements, the flow computer shall calculate standard

volumetric flow rate, energy and mass flows.

Measurement of the hydrocarbon dewpoint shall be through a dedicated hydrocarbon dewpoint

analyser system interfacing to the PCS.

Measurement of water content shall be through a single water content analyser (water dewpoint

analyser) interfacing to the PCS.

5.4 Future Requirements

Tie-ins shall be provided to enable duplication of the pipeline filters and fiscal metering skid such that

future increases in gas demand may be accommodated. Refer to the BOD document for details of

envisaged future and base supply requirements.

5.5 Pressure Letdown

Pressure letdown requirements will be managed downstream of the ORF and will therefore be the

responsibility of the gas end-users. Pipeline entry pressure and temperature shall be controlled at the

SRT to ensure delivery of on-specification gas to the ORF.

5.6 Gas Preheating / Heat Recovery

Gas preheating requirements to meet end-user delivery temperature requirements after pressure will

be managed downstream of the ORF and will therefore be the responsibility of the gas end-users.

Likewise, any requirements for use of sales gas in a cooling fluid service downstream of the pressure

letdown station will be at the discretion and therefore responsibility of the gas end-users.


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5.7 Cold Vent System

A relief and vent system is required for safe disposal of hydrocarbon gas inventory in the event of an

emergency situation or alternately during routine maintenance activities. Relief and vent system shall

comply with API STD 521 requirements.

The ORF shall be designed with no continuous venting. Under accidental/ emergency conditions, the

cold vent system shall safely dispose all envisaged flows. The vent shall be able to accommodate the

highest flow rate that results from an uncontrolled and/ or unplanned event which may occur during

facility operation. The governing design case is envisaged to be a failure (open) of the upstream

(SRT) supply pressure control valve.

Cold vent location shall be selected, as far as practicable, taking consideration of the prevailing wind

directions in order to minimise the risk of the flammable gas clouds reaching ignition sources.

Dispersion analysis for the vent shall be performed to check HC gas LEL concentration. A radiation

study shall also be performed to assess the impact on personnel and facilities in the event of vented

gas ignition e.g. via lightning strike.

In order to minimize ingress of air, the vent tip shall be equipped with a fluidic seal. CO2 snuffing

system shall be provided to extinguish the flame in the event of gas ignition. Refer to Section 7 and

the BOD document [1] for further details.

5.8 Utility Systems

5.8.1 Electrical Power System

400-V, 50-Hz, 3-phase electrical power shall be supplied to the ORF via the Jamaican power grid

(PG). The switchboard shall be provided with two incomers, one for the PG incoming supply and the

other for supply from a (permanent or temporary) diesel generator (DG) back-up. Requirements for a

permanent DG back-up power supply shall be determined by the CONTRACTOR based on Jamaican

power grid reliability data such that facility availability demands can be guaranteed.

5.8.2 Instrument Air System

An instrument air system consisting of the following components shall be installed at the ORF:

a) Fully spared electric motor driven rotary screw compressors

b) Fully spared dual air dryer package (heatless type)

c) Pre & post filters

d) Instrument air receiver

Consistent with the aforementioned equipment sparing requirements, the compression / drying units

shall be operated in duty / standby mode.

Design details are provided in the Project Basis of Design [1]. CONTRACTOR shall confirm final

design requirements for COMPANY approval.


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5.8.3 Util ity Water System

Utility water storage tanks shall be provided to store water for personnel usage and equipment wash

down.

Design details are provided in the Project Basis of Design [1]. CONTRACTOR shall confirm final


5.8.4 Fire Water System

The ORF shall be provided with active fire fighting equipment i.e. fire hydrant, fire monitor and fire

hose. Provision of firewater storage tank and firewater pumps to supply firewater requirements shall

be developed by the CONTRACTOR in compliance with International standards.

Fire water network shall be provided around all sections of the facility, with water supply via a ring

main header so that it remains uninterrupted in the case of maintenance of or damage to a section of

piping.


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6. SRT OPERATING PHILOSOPHY

For details of the SRT operating philosophy, refer to the FSRU Operating Philosophy-Permanently

Moored FSRU [3].


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7. ORF RELIEF AND VENT SYSTEM OPERATION PHILOSOPHY

7.1 Relief Contingencies

Relief contingencies shall be assessed in detail as part of the relief and blowdown philosophies which

shall be developed by the CONTRACTOR during the detailed design phase of the Project for

COMPANY approval. The major relief events anticipated are:

• Failure (open) of the upstream (SRT) gas supply pressure control valve;

• Facility fire.

7.2 Blowdown

Blowdown and release of gas and liquid to the cold vent system is not expected to be a common

occurrence. The process shall be designed to retain all fluids within the equipment under all


Blowdown is expected to occur mainly due to events external to the process e.g. fire and gas alarm,

maintenance etc. Blowdown shall be constrained to hydrocarbon bearing equipment.

Emergency blowdown shall comply with the requirements of API STD 521, with inventory diverted to

the cold vent system for safe disposal. Blowdown of liquid sources shall be minimised.

7.3 Manual Drains and Vents

The process area shall be serviced by independent open and closed drain systems as a minimum.

The open drain system shall collect all liquid discharges from equipment via tundishes. Deluge and

rainwater shall be able to be routed to the open drain system, but in general direct release to the

environment is anticipated. The closed drain system shall collect all pressurised liquids from

equipment drains, etc. The CONTRACTOR shall develop an appropriate methodology for disposal of

materials collected in the open and closed drain systems for COMPANY approval. Disposal

methodology shall be in compliance with applicable codes, regulations and emissions standards.

Process and equipment vents will be connected to the cold vent header for safe disposal of all

flammable vapours.


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8. SHUTDOWN AND CONTROL SYSTEMS

The ORF shall be provided with control, monitoring, safe shutdown and fire and gas detection

systems. The required systems shall be as follows:

• Process and Control System (PCS) for regulatory control, monitoring and alarms for the

process and utility system within the facilities. The PSC is intended to maintain stable

operations, thereby minimising process excursions in order to avoid shutdown initiation;

• Safety Instrumented System (SIS) for monitoring process and utility systems for abnormal

operating conditions and initiate process or emergency shutdown (Process Shutdown –

PSD, Unit Shutdown – ESD or Emergency Shutdown – ESD) and trip field equipment,

motors, packaged equipment and close shutdown valve (SDV) or open blowdown valves

(BDV);

• Fire and Gas System (FGS) for detection and suppression of fire and protection against

occurrences of fire or gas leaks.

It is envisaged that process, safety and fire & gas signals from the ORF will be routed to the central

(and independent) SRT PCS, SIS and FGS respectively for executive action / alarm activation. A

local Human Machine Interface (HMI) Operator Work Station (OWS) is envisaged to enable

monitoring and control capability from the ORF such that safety and operability can be assured.

Refer to Section 8.3 for additional details. CONTRACTOR shall confirm final design requirements for

COMPANY approval.

8.1 Shutdown Hierarchy

Envisaged shutdown hierarchy requirements (from most to least serious) at the ORF are as follows:

• Emergency shutdown (ESD);

• Process shutdown (PSD);

• Unit shutdown (USD).

ESD activation shall cause equipment shutdown and ESD valves operation to their fail safe position in

order to contain inventories. ESD shall be initiated either by the activation of hard or soft ESD push

button or by confirmed fire / gas detection at the ORF. The corresponding action shall be shutdown

of the ORF and ESD isolation from the upstream pipeline via the FVO.

PSD activation shall cause equipment shutdown to prevent ORF damage. PSD shall be initiated

either by the activation of hard or soft PSD push button or by any critical system fault such as low low

instrument air pressure. The corresponding action shall be shutdown of the ORF.

USD activation shall cause individual equipment shutdown to prevent (less critical) item-specific

damage. USD shall be initiated by process fault, and will result in shutdown of the corresponding

equipment item.


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8.2 System Architecture

The PCS, SIS, and FGS shall be standalone, independent systems. Refer to the LNG FSRU

Functional Specification – Permanently Moored [5] for specific details including system redundancy /

reliability requirements.

Signalling between the SRT PCS, SIS and FGS and the ORF is envisaged to be via hard-wired optic

al fibre with in-built redundancy as described in [5], however the CONTRACTOR shall confirm final


8.3 Process Monitoring, Control and Safeguarding

The ORF shall be a continuously manned facility, designed to operate will minimal operator /

maintenance intervention during normal operation. Monitoring, control and safeguarding the ORF

equipment and inventories will be executed by Operations personnel via a local, HMI OWS. The

OWS shall be located in the Main Control Room (MCR).

It is envisaged that that process, safety and fire & gas Inputs/Outputs (I/O) from the ORF will be

routed to the central SRT PCS, SIS and FGS for processing, however the CONTRACTOR shall

confirm final design requirements for COMPANY approval.

8.4 Start-up and Restart

The CONTRACTOR shall develop detailed methodologies for start-up and restart of the ORF and

pipeline facilities under all credible operating scenarios for COMPANY approval. It shall be noted that

venting as part of normal start-up and restart will not be accepted.


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9. LOSS PREVENTION PHILOSOPHY

9.1 Fire and Gas Detection

The fire and gas detection system (FGS) is intended to rapidly and reliably detect any flammable gas

leakage and any fire condition in the facility. Continuously operating detection systems shall be

installed at every location where leaks are credible.

The basic requirements of the fire and gas detection and protection system are as follows:

• Detect the presence of combustible or toxic gas in sufficient quantities and concentrations to

initiate an explosion or otherwise endanger personnel (by asphyxiation);

• Detect the presence of a fire in the incipient (early) stages in order to prevent escalation;

• Take appropriate actions to control and reduce the hazard.

The CONTRACTOR shall develop fire and gas detection systems in compliance with the

requirements of all applicable codes, standards and regulations [1] for COMPANY approval.

9.2 Active Fire Protection

The main aim of the active fire protection system is to ensure that an acceptable level of safety will be

achieved in order to protect the personnel, equipment, the installation and the environment against

fire.

The immediate objectives for active fire protection system are to:

• Allow personnel to escape from fire or high radiation areas;

• Prevent/limit escalation of an accident by cooling equipment which contain significant

quantities of either gaseous or liquid hydrocarbons;

• Extinguish liquid hydrocarbon fire;

• Limit the effects of heat radiation;

• Limit damage to structures and equipment;

• Reduce the effects of a fire to allow personnel for undertaking emergency response

activities.

For the facility, the active fire protection system shall consist of:

• Fire water mains network, with hydrants and monitors;

• Water spray systems;

• Portable and mobile dry chemical powder systems.

The CONTRACTOR shall develop active fire protection systems in compliance with the requirements

of all applicable codes, standards and regulations [1] for COMPANY approval.


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9.2.1 Water Spray Systems

When required, spraying systems shall distribute the water flow evenly onto the exposed surfaces. In

this way equipment subjected to radiation shall not reach unacceptably high local temperatures.

Recirculation of used water may be considered where practicable and shall depend on its ability to

remove the transfer heat in a fire of long duration while keeping the integrity and working ability of the

unit.

9.2.2 Portable and Mobile Dry Chemical Powder Extinguishers

Portable and mobile dry chemical powder extinguishers shall be made to the NFPA 10 standard and

shall be provided to use in minor fire incidents. Dry chemical extinguishers shall be provided with

indicators to identify whether they are in ready condition or need of recharging.

Dry powder to be used may be based on one of the following types:

• Sodium bicarbonate;

• Potassium bicarbonate.

The fire extinguishers shall be designed, located, installed, or protected so that they are not subject to

mechanical, environmental, or other conditions that could render them inoperative or cause

inadvertent operation of the system.

The dry chemical extinguisher shall be located near the hazards to be protected, but not where they

will be exposed to a fire or explosion in these hazards. The extinguishers shall be placed so that they

are easily accessible and able to reach the most distant hazard that they are expected to protect.

9.2.3 Manual Alarm Call Points

Manual Alarm Call Points (MAC) shall be provided throughout the installation. Manual Alarm Call

buttons shall generally be located at exits from areas and at the muster stations, in control rooms etc.

Activation of a MAC Button shall initiate audible and visual alarms on the local and remote fire and

gas panel.

9.3 Passive Fire Protection

The passive fire protection shall be specified to maintain the protected equipment or structural

integrity for a duration that will either be:

• The maximum anticipated fire time or flame impingement duration;

• The operating time of the protected equipment (e.g. ESD valves);

Jet fires can lead to damage to equipment or structural members supporting equipment. The actual

failure times of structures due to fires can be determined by detailed heat-up assessment calculations

of each vessels and structural components. It may sometimes be necessary to protect part of the

structure or some equipment in installation handling compressed gas in order to meet the company’s

requirements regarding safety to life, protection of environment and asset protection policy.


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Radiation shielding shall be considered to protect escape routes and access ways at the location

where high radiant heat exists during a fire incident.

The CONTRACTOR shall develop passive fire protection systems in compliance with the

requirements of all applicable codes, standards and regulations [1] for COMPANY approval.


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10. INSTRUMENTATION, AUTOMATION AND TELECOMMUNICATION PHILOSOPHY

10.1 Instrumentation

The term “Instruments” covers all devices used for control and monitoring including local indicators

related to process, utilities, safety and fire and gas functions.

All electronic transmitters and valve positioners shall utilise 4 to 20 mA signalling. Usage of switches

shall be minimised and is strictly prohibited for ESD initiating devices.

All field electronic instruments shall be suitable for installation in Zone 1, Gas Group IIA, Temperature

class T3 area as a minimum. In the event that service conditions dictate a more stringent hazardous

area classification, this shall be governing.

Process control, fire & gas and safety instrumentation shall be segregated and functionally

independent.

10.2 Control Room and Human Machine Interface

The main operator interface for ORF and pipeline process and safeguarding systems shall be at a

control console located in the MCR. The MCR shall be equipped with a number of Operator Work

Stations (OWS), each with double layer flat screen. The console shall also contain:

• ESD manual pushbuttons, lamps, key switches etc;

• Set of critical start-up and maintenance override key-switches;

• Telecommunication workstation;

• Closed circuit television system (CCTV) flat screens;

• 1 off large screen display (LCD or overhead projector) which shall be able to display any

graphic screen;

• 1 off data historian workstation (ORF and pipeline);

• 1 off data historian workstation (SRT – display only of critical process parameters);

• 1 off data SOE workstation; and

• PCS, SIS and FGS Engineering Work Stations (EWS) for systems diagnostics and carrying out

system configurations changes.

The ORF Human Machine Interface (HMI) shall be located in the MCR, which shall be provided with

artificial ventilation.

10.3 Telecommunications

Telecommunication systems shall be provided for the ORF inclusive of Marine VHF radio, UHF radio,

a telephone system, IT network and CCTV system.


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The link between the SRT and ORF shall be via dual redundant (as a minimum) fibre optic cable for

the telephone & CCTV system and IT network. PCS, SIS and FGS linkage shall be as described in

Section 8.2.

The VHF radio system, located in the MCR, will be used for communications with SRT personnel.

The UHF radio system, comprising portable hand units, will be used for communications between

ORF personnel for the operational, security and maintenance purposes.

Monitoring panels for the CCTV system shall be located in the MCR, and will be used to enable

operations personnel to monitor the ORF site remotely for security and safety purposes.

All telecommunication equipment shall obtain type approval and licensed operating frequencies from

the appropriate authority.


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11. MAINTENANCE PHILOSOPHY

The primary objectives of the maintenance function shall be to achieve:

• Technical integrity within COMPANY requirements;

• Optimum equipment availability with the minimum of staffing levels;

• Lowest life cycle cost; and

• Meet legislative requirements with regard to equipment inspections/testing.

The ORF shall be maintained so that it remains in an operable condition to the end of its design life

and can be maintained in service without a major re-build.

During the detailed design phase of the project, maintenance personnel shall be involved in order to

assist in achieving the above objectives (e.g. optimum equipment availability - through careful

selection and equipment arrangement).

A detailed maintenance philosophy for the ORF shall be developed at the detailed design stage. This

shall detail the maintenance strategy to be applied to equipment and systems; either frontline,

preventative, "on condition" or breakdown maintenance. The selection of the maintenance strategy

shall be determined against the objectives set out above.

The optimum means of servicing equipment shall be carefully assessed against maximising ORF

availability.

11.1 Maintenance Management

A maintenance, testing and inspection plan shall be developed by the CONTRACTOR. This shall

outline the type of maintenance required on each item of equipment/system (routine, preventative or

breakdown) against the objectives listed in section Error! Reference source not found.. Maintenance/testing/inspection scheduling shall be based on this plan. As part of this management

process, a through-life database shall be developed to ensure continual improvement and enhanced

technical integrity.

11.2 Frontline Maintenance

Frontline maintenance, such as condition monitoring, control valve repairs, trouble-shooting and

repair of field instrumentation, instrument calibrations and routine equipment servicing (lube oil

change, etc.) shall be carried out by production personnel.

11.3 Condition Monitoring, Testing and Inspection

A maintenance, inspection and test plan shall be developed during the detailed design phase of the

project to cover all safety and production critical equipment. This plan shall outline the requirements

for the following tasks and activities:


Page 27

• Condition monitoring, including monitoring strategy and monitoring data collection and

processing;

• Testing requirements as set out in vendor recommendations. Testing requirements shall also

be reviewed and modified as necessary based on equipment/system historical data;

• Alarm and trip testing of critical trips and alarms;

• Inspection requirements consistent with maintaining technical integrity and meeting legislation

and COMPANY requirements.

11.4 Certification

Early in the detailed design phase, the Certifying Authority shall be appointed. The work scope

definition for the Certifying Authority shall be developed in consultation with the appropriate

government department.

An integrated approach shall be developed whereby the Certifying Authority, design and operations

team work together to achieve the desired level of technical integrity.

11.5 Spares Holding

Spares holding for the ORF shall be based on the results of a reliability, availability and maintainability

study (RAM).

A critical spares listing shall be developed and used for setting the level of spares holding at the ORF.

The criteria for deciding on a critical spare shall be taken to be:

"An item of equipment which in the event of failure shall result in an unacceptable safety risk or a significant business loss"

The sparing philosophy is that the ORF shall warehouse only safety or production critical equipment

spares. Spares shall not be held where equipment/systems are duplicated (spared) within the ORF

(e.g. duty and standby pumps).

Sparing of portable fire fighting equipment on the ORF shall be provided equivalent to 5% of the total

of each type of device so as to provide expedient replacement.

Commissioning, start-up and first year spares shall be identified during the detailed design phase and

are available prior to commencement of commissioning.

11.6 Permit to Work/Work Orders

All maintenance work on the pipeline and ORF shall be carried out under a “Permit to Work” system.


Page 28


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12. ESCAPE, MUSTER, EVACUATION AND RESCUE

Diverse means of escape shall be provided. The main escape routes in ORF will be the access roads

provided around the plant areas. The principal requirements for escape routes from all areas shall

comply with the following:

• An adequate number and space of escape doors on safe distances shall be provided on

control room in order to let all personnel escape to a safe place within the shortest possible

time span.

• All escape doors shall be constructed so that they can be easily open from both sides. The

doors that shall normally open outwards in the direction of the escape will be provided with

panic bars.

• Under all circumstances; escape directions, escape routes and escape doors shall be

univocal so that under emergency conditions of sight and noise; the shortest possible way to

find safety can be found. Univocal information is of extreme importance to maximize the

recognition.

• All areas shall have sufficient emergency lighting to allow safe exit even in the event of

failure of essential services.

• Escape doors and ways shall be sufficiently protected according to hazardous they are

exposed.

Safe places shall be provided that shall remain habitable under all accident events for sufficient time

to enable personnel to muster, monitor and control the incident, communicate with all personnel, and

perform a controlled evacuation should it become necessary. Any muster area shall provide access to

one or several embarkation posts by evacuation routes. All personnel in any area of the facility shall

be made promptly aware that an incident has occurred and the area in which it has occurred.

The philosophy to be adopted for evacuating the facility is to safely and efficiently distance all

personnel from any hazardous event that could render the facility unsafe.


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13. MISCELLANEOUS OPERATIONAL PHILOSOPHIES

13.1 Simultaneous Operations

Simultaneous operations (such as maintenance activities beside “live” plant) are permitted on the

basis that an acceptable level of protection is in place to prevent loss of control.

As a minimum, two levels of protection shall be in place such that loss of any one protection measure

does not result in loss of control. Common protection measures for two or more operations shall be

acceptable.

Functional testing of the agreed protection measures shall be undertaken prior to commencing the

simultaneous operations.

A simultaneous operations procedure shall be developed during the detailed design phase of the

Project, detailing the set of simultaneous operations which are permitted and the measures which are

required to prevent loss of control. This information shall be recorded in the operating manual /

procedures for the ORF and pipeline.

13.2 Materials Handling

Materials handling procedures shall be developed during the detailed design phase based on the

results of the materials handing study. Equipment removal routes to designated laydown areas shall

be identified.

13.3 Accessibility

Good access shall be provided to items of equipment which require frequent (more than once per

year) testing, inspection or maintenance. This shall also apply to the permanent handling/lifting

devices (such as beams, pad eyes) installed for equipment removal.

Scaffolding or other temporary fixtures shall be used where equipment testing, inspection or

maintenance is less frequent (greater than 2 years).

13.4 Impact Protection

The need for dropped object protection or additional protection of “live” process equipment from

dropped objects shall be studied as part of the materials handling study.

Crane and mobile vehicle operations shall be minimised near to or over “live” process equipment.

Dropped object protection shall not be required where infrequent heavy material movements near or

over equipment are carried out when the equipment has been isolated and depressurised.

13.5 General Housekeeping

ORF housekeeping shall be the responsibility of shift personnel. When maintenance work is carried

out, the maintenance team shall leave the area clean and tidy.


Page 31


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14. REFERENCES

[1] WorleyParsons, “Jamaica LNG Project, Basis of Design”, 402010-00260-00-GE-BOD-0001

[2] WorleyParsons, “Jamaica LNG Project, Pipeline and ORF Functional Specification”, 402010-

00260-00-PR-SPC-0002

[3] WorleyParsons, “Jamaica LNG Project, FSRU Operating Philosophy-Permanently Moored

FSRU”, 402010-00260-00-MA-PHL-0001

[4] WorleyParsons, “Jamaica LNG Project – Request for Quotation, Pipeline and ORF Scope of

Work”, 402010-00260-00-GE-SOW-0005

[5] WorleyParsons, “Jamaica LNG Project, LNG FSRU Functional Specification – Permanently

Moored, 402010-00260-00-MA-SPC-0002

Attachment 10 - FSRU Operating Philosophy

GOVERNMENT OF JAMAICA - OFFICE OF THE CABINET JAMAICA LNG PROJECT FSRU OPERATING PHILOSOPHY

Page i

Jamaica LNG Project FSRU Operating Philosophy

402010-00260 – 00-MA-PHL-0001

24 August 2011


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CONTENTS 1 INTRODUCTION ................................................................................................................ 1

1.1 Background ......................................................................................................................... 1

1.2 FSRU Operational Philosophy ............................................................................................ 1

1.2.1 Scope ..................................................................................................................... 1

1.2.2 Objectives .............................................................................................................. 1

1.3 FSRU Overview, Specifications and Utilities System ......................................................... 2

1.3.1 Overview ................................................................................................................ 2

1.3.2 LNG Storage Tanks ............................................................................................... 2

1.3.3 LNG Loading Capability ......................................................................................... 2

1.3.4 Gas Export Rates ................................................................................................... 2

1.3.5 Typical LNG Composition Data .............................................................................. 2

1.3.6 Gas Pressure and Temperature at Delivery Point ................................................. 2

1.3.7 Utility Systems ........................................................................................................ 3

1.4 Abbreviations ...................................................................................................................... 3

1.5 Definitions ........................................................................................................................... 7

2 BASIS OF PHILOSOPHY ................................................................................................... 8

2.1 Health .................................................................................................................................. 8

2.2 Safety .................................................................................................................................. 8

2.3 Environment ........................................................................................................................ 8

2.4 Emergency Equipment ....................................................................................................... 9

2.5 Personal Protective Equipment .......................................................................................... 9

2.6 Emergency Response Plan ................................................................................................ 9

3 STAFFING, COMPETENCY, DEVELOPMENT AND TRAINING .................................... 10

3.1 Staffing .............................................................................................................................. 10

3.2 Competency, Development and Training ......................................................................... 11

4 LNG TANK OPERATING PHILOSOPHY ......................................................................... 12

4.1 Overview ........................................................................................................................... 12

4.2 Gassing-Up of Cargo Tanks ............................................................................................. 12


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4.3 Cool Down of Cargo Tanks ............................................................................................... 13

4.4 Cargo Tank Warm-up ....................................................................................................... 13

4.5 Cargo Tank and System Inerting ...................................................................................... 14

4.6 Aeration ............................................................................................................................. 15

5 LNG TRANSFER PHILOSOPHY ...................................................................................... 16

5.1 Overview ........................................................................................................................... 16

5.2 Transfer Conditions and Requirements ............................................................................ 16

5.2.1 Approval from Authorities ..................................................................................... 16

5.2.2 Weather Conditions ............................................................................................. 16

5.2.3 Night Berthing and Un-berthing Operations ......................................................... 16

5.3 Operational Checks before Manoeuvring ......................................................................... 17

5.3.1 Final Checks on Ship Compatibility ..................................................................... 17

5.3.2 Preparation ........................................................................................................... 17

5.3.3 General Safety Requirements .............................................................................. 18

5.3.4 Navigational Signals ............................................................................................ 18

5.4 Manoeuvring and Mooring ................................................................................................ 19

5.4.1 Basic Berthing Principles ..................................................................................... 19

5.4.2 Fender Positioning ............................................................................................... 19

5.4.3 Size of Fenders .................................................................................................... 19

5.4.4 Mooring Equipment and Preparations ................................................................. 19

5.5 Procedures Alongside ....................................................................................................... 20

5.5.1 Pre-Transfer Procedures ..................................................................................... 20

5.5.2 Tending of Fenders and Mooring Lines ............................................................... 20

5.5.3 Planning for Cargo Transfer ................................................................................. 20

5.5.4 Loading Arm Connection ..................................................................................... 21

5.6 Cargo Transfer Operations ............................................................................................... 21

5.6.1 Loading Arm Handling ......................................................................................... 21

5.6.2 List and Trim ........................................................................................................ 21

5.6.3 Cargo Flow Rates ................................................................................................ 21

5.6.4 Vapour Return ...................................................................................................... 22


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5.6.5 Cargo Transfer – General Requirements ............................................................ 22

5.6.6 Accidental Cargo Release ................................................................................... 22

5.6.7 Metering Requirements ........................................................................................ 22

5.6.8 Completion of Cargo Transfer .............................................................................. 22

5.7 Unmooring ........................................................................................................................ 23

5.7.1 Unmooring Procedure .......................................................................................... 23

5.7.2 Unmooring Checks .............................................................................................. 23

5.7.3 Procedure for Unberthing ..................................................................................... 23

5.8 Parcel Size/Offloading Rate .............................................................................................. 24

5.9 Boil Off Gas ....................................................................................................................... 24

6 REGASIFICATION OPERATION PHILOSOPHY ............................................................. 25

6.1 LNG Pumps on FSRU ...................................................................................................... 25

6.2 LNG Vaporisers ................................................................................................................ 25

6.3 Available Technologies ..................................................................................................... 25

6.3.1 Ambient Air Vaporisation ..................................................................................... 26

6.3.2 Intermediate Fluid Vaporisation ........................................................................... 26

6.4 Shell and Tube Vaporisers ............................................................................................... 27

7 GAS EXPORT SYSTEM OPERATION PHILOSOPHY .................................................... 28

7.1 Overview ........................................................................................................................... 28

7.2 Gas Metering .................................................................................................................... 28

7.3 Pig Launcher ..................................................................................................................... 28

7.4 Gas Pipeline ...................................................................................................................... 28

8 RELIEF AND VENT SYSTEM OPERATION PHILOSOPHY ........................................... 29

8.1 Overview ........................................................................................................................... 29

8.2 Relief Contingencies ......................................................................................................... 29

8.3 Blowdown .......................................................................................................................... 29

8.4 Manual Drains and Vents ................................................................................................. 29

9 CONTROL AND SHUTDOWN OPERATION PHILOSOPHY........................................... 31

9.1 Shutdown .......................................................................................................................... 31

9.1.1 Hierarchy .............................................................................................................. 31


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9.1.2 Total FSRU Shutdown ......................................................................................... 31

9.1.3 Marine Systems Shutdown .................................................................................. 31

9.1.4 Main Deck Systems Shutdown ............................................................................ 31

9.1.5 Regasification Process Shutdown ....................................................................... 32

9.1.6 Unit Shutdown ...................................................................................................... 32

9.2 Regasification Process Control ......................................................................................... 32

9.2.1 General ................................................................................................................ 32

9.2.2 LNG Pumps .......................................................................................................... 32

9.2.3 LNG Vaporiser Control Requirements ................................................................. 32

9.3 Start-up and Restart ......................................................................................................... 33

10 MARINE SYSTEMS PHILOSOPHY ................................................................................. 34

10.1 Availability .................................................................................................................... 34

10.2 Machinery Space .......................................................................................................... 34

10.3 Power Generation ........................................................................................................ 34

10.4 Power Management System ........................................................................................ 36

10.5 Cargo Heater ................................................................................................................ 38

10.6 Low Duty and High Duty Compressor .......................................................................... 39

10.7 Fuel System and Sludge System ................................................................................. 39

10.8 Ballast Water System ................................................................................................... 39

10.9 Fire Water System ........................................................................................................ 39

10.10 Compressed Air Systems ............................................................................................. 39

10.11 Nitrogen System ........................................................................................................... 40

10.12 Fresh Water Systems ................................................................................................... 40

10.13 Seawater Systems ....................................................................................................... 40

10.14 Hypochlorite Generator ................................................................................................ 40

10.15 Diesel Systems ............................................................................................................. 40

10.16 Miscellaneous Marine System ..................................................................................... 40

11 AUTOMATION, INSTRUMENTATION AND COMMUNICATIONS PHILOSOPHY ......... 41

11.1 System Requirements .................................................................................................. 41

11.1.1 Overall Instrumentation and Control Philosophy ................................................. 44


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11.1.2 Systems Interface ................................................................................................ 44

11.1.3 Control Room and Human Machine Interface ..................................................... 45

11.2 PCS Specific Design Requirements ............................................................................. 45

11.2.1 PCS Architecture ................................................................................................. 45

11.2.2 Functional Requirements ..................................................................................... 46

11.2.3 Data Communication ........................................................................................... 47

11.2.4 Tank Level Measuring Instrumentation ................................................................ 47

11.3 Communications Philosophy ........................................................................................ 48

11.3.1 Telephone System ............................................................................................... 48

11.3.2 IT Network ............................................................................................................ 48

11.3.3 Radio System ....................................................................................................... 48

11.3.4 Public Address and General Alarm System ......................................................... 49

11.3.5 Close Circuit TV and Security System ................................................................. 50

11.3.6 Recreational System ............................................................................................ 50

11.3.7 Meteorological System ......................................................................................... 50

11.3.8 Muster Area Communications .............................................................................. 50

11.3.9 Radio Equipment Room ....................................................................................... 51

12 MISCELLANEOUS OPERATIONAL PHILOSOPHIES ..................................................... 52

12.1 Simultaneous Operations ............................................................................................. 52

12.2 Supply and Storage Logistics ....................................................................................... 52

12.3 Supply/Tug Boats ......................................................................................................... 53

12.4 Materials Handling/Accessibility/Dropped Object Protection ....................................... 53

12.4.1 Materials Handling ............................................................................................... 53

12.4.2 Accessibility .......................................................................................................... 53

12.4.3 Impact Protection ................................................................................................. 54

12.5 General Housekeeping ................................................................................................. 54

13 MAINTENANCE PHILOSOPHIES .................................................................................... 55

13.1 Objectives ..................................................................................................................... 55

13.2 Servicing ....................................................................................................................... 55

13.3 Maintenance Management ........................................................................................... 55


Page vii

13.4 Frontline Maintenance .................................................................................................. 56

13.5 Major Shutdowns .......................................................................................................... 56

13.6 Subsea Inspection, Maintenance and Repair .............................................................. 56

13.7 Condition Monitoring, Testing and Inspection .............................................................. 56

13.8 Certification .................................................................................................................. 56

13.9 Spares Holding ............................................................................................................. 57

13.10 Permit to Work/Work Orders ........................................................................................ 57

14 REFERENCES ................................................................................................................. 58

Appendices

APPENDIX 1 LNG TRANSFER CHECK LISTS

TO BE ADVISED BY CONTRACTOR

[TBABC 001] FSRU safety philosophy.................................................................................................... 9

[TBABC 002] FSRU environmental management plan ........................................................................... 9

[TBABC 003] FSRU emergency response plan .................................................................................... 10

[TBABC 004] FSRU SOPEP ................................................................................................................. 11

[TBABC 005] LNG tank operational procedures ................................................................................... 14

[TBABC 006] FSRU safety philosophy.................................................................................................. 34

[TBABC 007] FSRU detailed maintenance philosophy ......................................................................... 59


Page 1

1 INTRODUCTION

1.1 Background
















1.2 FSRU Operational Philosophy

1.2.1 Scope

This document outlines the operational philosophy for the Floating Storage Regasification Unit

(FSRU). It is anticipated that this document shall be updated and re-issued on an “as-required” basis

throughout the development of this project.

Operational philosophies associated with the gas export pipeline and the ORF, which are part of the

Jamaican LNG project, are beyond the scope of this document.

1.2.2 Objectives

The objectives of this operations philosophy are to ensure:

a) Health, Safety and environment (HSE) objectives are achieved;

b) Technical and mechanical integrity are maintained;

c) Life cycle economics are optimised;

d) Legal compliance;

e) To provide an overall vision of how the FSRU shall be operated.


Page 2

This document also presents the key operational requirements to be incorporated into the design of

the FSRU. Operational requirements are set out in general terms; the detailing of which shall be

undertaken in the development of the Basis of Design (BOD) document [1].

1.3 FSRU Overview, Specifications and Utilities System

1.3.1 Overview

The SRT development consists of the following:

a) Hard-berthed, fixed jetty moored FSRU. Alternate mooring arrangements will be considered,

for example a tower-yoke, permanently moored FSRU;

b) The minimum storage capacity is defined in the BOD [1];

c) An LNG regasification unit located on the main deck of the FSRU that shall vaporise the LNG

for export.

1.3.2 LNG Storage Tanks

The LNG storage tanks shall operate at slightly above atmospheric pressure and approximately -

160°C, refer to BOD [1] for actual value.

Each LNG storage tank shall have its own dedicated LNG cargo loading system consisting of

submersible cargo pumps that shall transfer LNG to the regasification plant.

The storage tanks shall share a common boil-off gas (BOG) handling system.

The FSRU shall provide a storage volume onboard the FSRU that can accept a full cargo load of a

157,000-m³ LNG.

1.3.3 LNG Loading Capability

The FSRU is capable of accepting LNG from LNG Carrier (LNGC) ranging in size from 125,000-m³ to

180,000-m³. A one day turn around is assumed for LNG loading, hence the system is required to

load at a rate of 10,000-m³/hr.

1.3.4 Gas Export Rates

The gas supply rates required are available in the BOD [1].

1.3.5 Typical LNG Composition Data

The typical supply LNG composition is available in the BOD [1].

1.3.6 Gas Pressure and Temperature at Delivery Point

The vaporised gas shall be delivered to the pipeline inlet under pressure and temperature control.

The inlet pressure to the pipeline is set by the end user pressure requirements and is detailed in the

BOD [1].


Page 3

1.3.7 Util ity Systems

The key utility systems for the FSRU and their main functions are as follow:

a) N2 generators: nitrogen generation is required for sealing and purging of all LNG systems and

tanks including LNG pumps and the flare system;

b) Compressed air systems: for the supply of two types of compressed air:

i) Plant air, compressed undried air, for air driven tools and other equipment;

ii) Instrument air, compressed dry air, for control and shutdown instrumentation, panel

purging;

c) HVAC system for pressurised spaces in addition to the living quarters;

d) Firewater system, which shall comply with marine as well as offshore safety practices;

e) Service water system for the distribution of seawater throughout the FSRU as service water

where required;

f) Fuel gas system used for the disposal of boil-off gases;

g) Power generation and distribution system onboard the FSRU;

h) Standard marine and hotel services required for LNGC.

1.4 Abbreviations




AAV Ambient Air Vaporisers

ALARP As Low As Reasonably Practical


BA Breathing Apparatus

BOD Basis of Design

BOG Boil-Off Gas

CBTA Competency Based Training and Assessment

CCR Central Control Room


Page 4


CCTS Cargo Custody Transfer System

CCTV Closed Circuit Television

CFC Chlorofluorocarbon

dBA Decibel-A weighted scale

EPIRB Emergency Position Indicating Radio Beacon


EWS Engineering Work Stations

FFB Foundation Field Bus

FGS Fire and Gas System

FSRU Floating Storage Regasification Unit

FVO First Valve On

GMDSS Global Maritime Distress and Safety System


HSE Health, Safety and Environment

I/O Input/Output

ICCS Integrated Control and Safety System

IFV Intermediate Fluid Vaporiser

IG Inert Gas

IGC IMO Gas Code

IGG Inert Gas Generator


Page 5



kPag Kilo-Pascal gauge

LAN Local Area Network



LVO Last Valve Off

MARVS Maximum Allowable Relief Valve Setting

Mbps Mega bits per second

MDO Marine Diesel Oil

MDS Main Deck Systems Shutdown

MIS Management Information System

mmscfd Millions standard cubic feet per day

mmtpa Millions Tonne Per Annum

MSCR Marine Systems Control Room

MSS Marine Systems Shutdown

OPEX Operating Expenses


OWS Operator Work Stations

PA Public Address

PAGA Public Address and General Alarm


Page 6



PFP Passive Fire Protection

PMCS Process Monitoring and Control System

PMS Power Management System

PPE Personal Protective Equipment

ppm Parts per million

PS Process Shutdown

psig Pounds per square inch gauge

PTT Push to talk

RAM Reliability, Availability and Maintainability Study

RER Radio Equipment Room

SART Search and Rescue Radar Transponder

SIS Safety Instrumented System

SOPEP Shipboard Oil Pollution Emergency Plans


STCW Standards of Training, Certification and Watchkeeping

STV Shell and Tube Vaporisers

TCP/IP Transmission Control Protocol/Internet Protocol

TS Total Shutdown

UCP Unit control Panels


Page 7


UPS Uninterruptible Power Supply

US Unit Shutdown

VHF Very High Frequency

WP WorleyParsons

1.5 Definitions













Page 8

2 BASIS OF PHILOSOPHY

2.1 Health

Health hazards shall be identified (such as chemicals, toxic material, noise and heat etc) and

appropriate means incorporated into the design to minimise the risk to personnel from these hazards.

A database of all hazardous materials shall be established during the detailed design phase of this

project. This database shall include Material Safety Data Sheets (MSDS) for all chemicals to be used

on the FSRU, and shall be available electronically and in hard copy.

A separate safety management system for handling/storing and treating exposure to hazardous

materials/chemicals shall be developed during the detailed design phase of this project.

A person qualified to act as a paramedic shall be present on the FSRU at all times.

Asbestos or materials containing asbestos, tar-coal epoxy coatings and heavy metals shall not be

used in the design of or during the operation of the FSRU.

Personnel shall not be subjected to passive smoking.

2.2 Safety

The design and operation of the FSRU shall conform to the requirements of the relevant legislations

and local Jamaican laws and regulation and applicable codes and standards. The safety in design

philosophy shall be one of identification of potential hazards under normal perceived operating

circumstances and designing to reduce the risk from these hazards to ALARP (As Low As

Reasonably Practical).

A separate safety philosophy shall be developed for the FSRU by the CONTRACTOR.

2.3 Environment

The FSRU shall meet the local Jamaican legislative and COMPANY requirements in relation to

environmental management. An environmental management plan shall be developed during detailed

design phase of this project, which shall outline any conditions imposed by local regulators in relation

to environmental management.

Consistent with COMPANY policy and local Jamaican legislative requirements, all reasonable

measures shall be taken to avoid direct discharge of pollutants to the environment. The design and

operation of the FSRU shall allow for containment of minor spills.

A design and operating philosophy of energy conservation shall be pursued where practical.

The use of halon’s or ozone depleting chlorofluorocarbon (CFCs) is prohibited. Alternatives shall be

used which have less effect on the environment (ozone layer).

An on-board flare system is the preferred method to dispose of process vent gases on the FSRU.

However, if cold venting is proposed then CONTRACTOR shall undertake dispersion modeling of the

vent gases to verify that the system shall meet all safety requirements.


Page 9

Operational flaring/venting shall be minimised. The operational design approach of the FSRU shall

be to limit flaring/venting to ALARP.

Monitoring of effluents (gaseous and liquid) discharged to the environment shall be conducted to

provide an overall inventory of pollutant discharges.

2.4 Emergency Equipment

The FSRU shall be equipped with all necessary emergency equipment:

a) Fire fighting equipment (such as monitors, hose reels etc.);

b) First aid room, fully equipped and within accommodation module;

c) Safety showers, eye wash, first aid kits; and

d) Breathing apparatus (BA) sets.

The tug/supply boats used at the SRT shall have a dual function of rescue boat. In the first instance

these vessels shall be used in rescue operations. A dedicated rescue craft shall also be provided to

cover the event whereby a tug is not available.

2.5 Personal Protective Equipment

Staff shall be supplied with personal protective equipment (PPE) to enable safe operation and

maintenance of the FSRU.

2.6 Emergency Response Plan

An Emergency Response Plan shall be developed for the FSRU. This plan shall address all credible

events and shall cover:

a) An emergency including, but not necessarily limited to gas release, fire, explosion, vessel

collision;

b) Medical emergency response;

c) Hurricane plan; and

d) Environmental emergency.

Emergency response simulation exercises shall be carried out and shall be defined within the HSE

Plan. A twice a year a simulation exercise shall be conducted which shall involve the FSRU and the

Emergency Management Team.

Document(s) covering Shipboard Oil Pollution Emergency Plans (SOPEP) shall also be included as

part of the emergency response plan. The SOPEP shall be developed during the detailed design

phase of the project .


Page 10

3 STAFFING, COMPETENCY, DEVELOPMENT AND TRAINING

3.1 Staffing

Staffing numbers shall be sufficient to provide for all routine operations and maintenance (section 13)

such that technical integrity is assured and overall gas export availability is optimised. Additional

contract labour shall be utilised for shutdown and specialist maintenance activities including

inspections of LNG cargo storage.

Crew and contractors shall be Jamaican nationals. For contract labour involved in specialised

operational and maintenance activities, appropriate remuneration rates and conditions shall apply.

For the current functional engineering phase, FSRU normal operational staffing shall include, but not

limited to, the following personnel/disciplines:

a) Offshore operations manager/ Regasification/production superintendent;

b) Facility engineer;

c) Medic/clerk;

d) Safety officer;

e) Regasification/production supervisor;

f) Regasification/production operators and technicians: for handling of LNGC offloading and

regasification operations;

g) Maintenance superintendent;

h) Mechanical engineer;

i) Instrumental/electrical engineer;

j) Materials controller;

k) Technicians, including mechanical, instrumental/electrical and laboratory technicians;

l) Cooks and stewards; and

m) Deck crew.

FSRU staffing shall be optimised to as low as reasonably practical to reduce risk and minimise

operating expenses (OPEX), yet at the same time shall be sufficient to cover two shifts and provide a

typical relief rate of 20%. If, for example, total number of personnel required on the FSRU is 20 per

shift, then including a 20% relief rate, the total number of personnel in the FSRU workforce is 44.

Wherever possible, the staffing strategy shall be to maximise combining staff positions and make use

of multi-skilled operators who are capable of carrying out routine frontline maintenance, testing and

inspection. Contract personnel shall be utilised for corrosion management, storage tank inspection

and major shutdown work under the supervision of the facility maintenance personnel.


Page 11

Note the numbers of personnel noted above are indicative. CONTRACTOR shall determine required

number of personnel required in the crew, as well as the roles and responsibilities required of the

crew.

3.2 Competency, Development and Training

A Competency Based Training and Assessment (CBTA) system shall be established as part of the

management system. The CBTA system shall ensure that individuals are trained in all safety and

production critical activities and they shall be objectively assessed to be competent to perform the

necessary tasks.

Where appropriate the CBTA system shall also include proficiency in English. General cultural

awareness training shall be provided where this is required.

The CBTA system shall be designed and implemented to assure competency of operations personnel

prior to FSRU startup.

Staff development shall be continuously addressed so that the workforce skills base is broadened

with the objective of leading to an improvement in operating efficiency and safety. This shall be

carried out as part of an annual appraisal process.

All technical staff shall be accredited by an independent organisation to comply with SIGTTO LNG

Shipping competency standard 2006 and STCW (Standards of Training, Certification and

Watchkeeping) requirements, as well as any applicable codes, standards, laws and regulations.


Page 12

4 LNG TANK OPERATING PHILOSOPHY

4.1 Overview

The LNG tanks shall be operated in accordance with IGC code, SIGTTO guidelines and applicable

codes, laws and regulations. The detailed LNG tank operational procedures are to be developed

during the detailed design phase of this project, which shall cover the following items below but not

limited to:

a) Gassing-up of cargo tanks;

b) Cool down of cargo tanks;

c) Cargo tank warm up on station;

d) Cargo tank and system inerting; and

e) Aerating.

Each cargo tank needs to be able to be isolated while operation of the remaining cargo tanks is

maintained, i.e. the isolation philosophy is by removing spool pieces and blanking of pipes.

Alternatively, double isolation valves shall be available.

One cargo tank is to be inspected per annum, with all cargo tanks having been inspected within a 5-

year cycle. CONTRACTOR shall provide inspection procedures, specifications, and acceptance

criteria in accordance with applicable codes, standards, laws and regulations.

During preparation an inspection of cargo tanks on station, the regasification unit and the remaining

tanks and tank system shall be able to be operated at a 100% capacity.

4.2 Gassing-Up of Cargo Tanks

During the tow to site and during the installation on site the cargo tanks are filled with N2 only.

LNG liquid is supplied by an LNGC alongside the FSRU through the loading arms and is fed to the

LNG regasification system. The LNG vapour produced is passed at approximately +20°C1

At the start of the operation, the piping system and LNG vaporiser are vapour locked, i.e. the reduced

liquid supply for this purpose may be insufficient to prime the pipework by displacing the vapour,

requiring an alternative venting arrangement.

to the

vapour header and into each tank through the vapour domes.

The stripping/spray header shall be able to be purged into the cargo tanks through the vapour dome

through the arrangement of spray valves and associated control valve until liquid reaches the LNG

vaporiser.

1 20ºC is a typical process value


Page 13

As the LNG vapour is lighter than the inert gas its introduction at the top of the tank creates a defined

interface that forces the inert gas (IG - nitrogen) in the cargo tanks to be exhausted by displacement

up the tank filling line into the liquid header.

The inert gas then vents to the atmosphere, usually through the bow vent mast. The bow vent mast

will likely be in the vicinity of the flare; a gas dispersion model shall provide appropriate location of the

vent and flare system to avoid gas cloud ignition and or gas cloud dispersion towards the

superstructure. The loading arms shall provide for intermittent venting to the main vent to avoid

vapour lock. It should be noted when the loading arms have been connected, prior to loading or

gassing-up, they are purged and pressurised with N2 supplied by the FSRU to an approximate

pressure of 200-kPag (to be in accordance with SIGTTO) in each arm.

When 5% volume of CH4 is detected at the vent mast riser, the exhausting gas is directed via the HD

compressors to the boilers through the gas burning line or an equivalent system to burn the gas e.g.

flaring.

The LNGC manifold shall accommodate a double blocked valve system to allow for the Liquid Header

to Vapour Header and Liquid Header to HD Compressor to be isolated.

4.3 Cool Down of Cargo Tanks

Cool down is the process that brings the containment system to a temperature that shall not cause

excessive boil-off during loading or unacceptable stresses in the support structures. It follows a

procedure that prevents a thermal shock to the primary containment system. Cool down is achieved

by pumping LNG through the spray header and cool down grids at the top of each tank. This allows

the LNG to vaporise at the sprays and allows cold gas to enter the tank.

For Moss type spherical tanks, the cargo tanks are gradually cooled by spraying LNG received from

the loading LNGC through the spray nozzles located round the centre column of the tank. This

operation, which produces cold vapour that has to be returned to the LNGC (excess vapour is to be

directed to the regasification unit/FSRU boil-off gas compressor), must continue until the equatorial

region of the tank is at least approximately -115ºC (typical for Moss Tanks; to be in accordance with

SIGTTO).

LNG enters the cargo tanks through the spray nozzles and the vapour is returned to the LNGC using

the HD compressors as necessary to maintain tank pressures within acceptable limits. The typical

operation duration for cool down of all tanks (180,000-m³) shall not exceed 30-hours, but the cool

down rate shall be limited to avoid thermal over stress in the piping and the inner shell of storage

tanks/cargoes.

During in service cool down, i.e. when only one tank at the time is inspected, the LNG for cool down

shall be taken from the neighbouring tanks.

4.4 Cargo Tank Warm-up

The FSRU shall carry out a maximum discharge from one of the tanks. This process requires that

some of the cargo be shifted into the adjacent tanks. One main cargo pump in the tank is used until it

trips on low ampere loading and/or low discharge pressure.


Page 14

The stripping pump shall remove the residual cargo; the striping pump needs to be able to discharge

to the adjacent tank or to the regasification unit. When all the cargo has been striped, the system is

to be drained back into the tank. The drain back shall be aided by pressure from the FSRU supplied

N2 system for purging the lines. Subsequently the tank warm-up is performed, which is part of the

gas freeing operations performed when preparing tanks for inspection purposes.

A successful warm-up operation is essential preparation for the inerting process. As well as warming

up the tank boundary, efficient warm-up of the insulation is also essential.

By continuing the warm-up process as long as possible, even beyond the target figures stipulated,

cold ingress from the insulation on completion of the warm-up shall be minimised (heat sink effect).

This ensures that the temperature of the cargo vapour remains elevated and so has as low a density

as possible. It also ensures maximum difference against the density of the incoming IG, which in turn

enhances the results of inerting by displacement.

Tanks are warmed-up by re-circulating heated LNG vapour. The vapour is recirculated by the two HD

compressors and heated by the cargo heaters to a preset value, typically first stage = 0°C (to be in

accordance with SIGTTO) and second stage = 75°C (to be in accordance with SIGTTO) i.e. the

FSRU shall provide two stage heating.

In a first step, vapour from the regasification plant is introduced via gas heater onboard the FSRU,

through the filling lines to the bottom of the tanks. This causes any liquid remaining in the tanks to

evaporate. In a second step, when the temperatures have a tendency to stabilise, hot vapour is

introduced through the vapour piping at the top of the tanks (excess vapour generated during the

warm up operation is collected and sent to shore via the boil-off gas compressor). For Moss type

containment systems, the warm-up is considered complete when the temperature of tank equator is

above -20ºC (tank wall temperature approximately +5ºC).

Initially, the tank temperatures shall rise slowly as evaporation of the LNG proceeds. Maximum

venting rate of 8,000-m³/h at 60°C (to be in accordance with SIGTTO) shall be achieved. On

completion of evaporation, tank temperatures shall rise rapidly and the venting rate shall fall to

between 1,000 and 2,000-m³/h (to be in accordance with SIGTTO) at steadily increasing

temperatures.

Temperatures within the tank and insulation are displayed in the CCR on the appropriate system

(DCS or similar).

4.5 Cargo Tank and System Inerting

After the tanks have been warmed up, and before the final aerating stage can begin, the LNG vapour

is displaced with inert gas. Inert gas from the inert gas generator (IGG) passes through the LNG

loading lines to enter at the bottom of the tanks.

Displaced gas from the cargo tanks is collected vented from the top of the tank routed to the boil-off

gas compressor. When less than 88% volume CH4 is detected at the boil-off gas compressor inlet,

the vapour is directed via the HD compressor to the boiler and burned-off. When 5% volume CH4 is

detected at the HD compressor inlet, the vapour is vented to air using the vapour header to vent-mast

located at the flare.

The operation shall take less than twenty hours to complete.


Page 15

In addition to the cargo tank, all cargo pipe work, associated fittings, impulse lines, compressor house

machinery and fuel gas supply lines must also be freed of gas. Fittings and lines are to be filled with

N2.

Before connecting FSRU inert gas generator to the cargo system, start and run the system until the

oxygen content and dew point have reached the recommended levels (O2 content less than 2% and

dew point less than -60ºC to be in accordance with SIGTTO). All unused sections of pipelines, blind

ends, machines, equipment, and instrumentation lines must be able to be purged. The minimum

duration of purging shall be not less than 10-minutes. When the hydrocarbon content sampled from a

tank outlet falls below 1.5% (to be in accordance with SIGTTO) the tank is to be shut-in and isolated.

4.6 Aeration

To be ready for inspection, the cargo tanks need to be aerated. This shall be done by replacing the

inert gas from the previous procedure with dry breathable air. This includes the pipelines (liquid and

vapour), cargo machinery, associated heat exchangers and fittings in this process.

With the inert gas and dry-air plant in dry-air production mode, the cargo tank is be purged with dry air

until a reading of 21% oxygen by volume is reached. Before any personnel can enter a tank, test for

traces of noxious gases (CO2 to be less than 0.5% by volume, and CO to be less than 50-ppm) which

may have been constituents of the inert gas. In addition, take appropriate precautions as given in

ISGOTT and other relevant guidelines. Adjust the pressure in the tanks to approximately 120-mbar.

The FSRU shall be able to complete the aerating of all tanks within twenty hours.


Page 16

5 LNG TRANSFER PHILOSOPHY

5.1 Overview

The LNG transfer philosophy deals with the transfer of LNG from an LNGC to the FSRU. The

following transfer philosophy is developed for a dual berth jetty:

a) Transfer conditions and requirements;

b) Operational preparations before manoeuvring;

c) Manoeuvring and mooring of LNGC; and

d) Unmooring operations.

5.2 Transfer Conditions and Requirements

5.2.1 Approval from Authorities

It is necessary that the CONTRACTOR check with local regulations and to gain local approval during

the functional engineering phase of this project. The GOJ will 'assist' the CONTRACTOR but will not

be directly responsible,

When transfer operations are planned, the SRT operator shall ensure that the FSRU is compatible in

design and equipment and that mooring operations and communications can be conducted safely and

efficiently.

5.2.2 Weather Conditions

Limiting weather conditions under which mooring and LNG operations can be carried out shall be laid

out as a guideline. These guidelines shall be developed from the results of computer simulations

and/or model testing. The limiting conditions shall depend on the effect of the sea and swell on the

motions of the vessels, loads in the fenders & mooring lines and the operating envelope of the loading

arms. The FSRU shall have ballast capabilities, which shall enable the vessel to keep the freeboard

constant.

All available weather forecasts for the area should be obtained before and during operations.

Throughout any berthing operations, the visibility should be good enough for safe manoeuvring,

taking into account safe navigation and collision avoidance requirements. Manoeuvres should only

start when the Master of the FSRU and the pilot are satisfied that conditions are suitable for mooring

and cargo transfer.

5.2.3 Night Berthing and Un-berthing Operations

Normal berthing and un-berthing operations shall be conducted during daylight hours only. However,

the facility shall be designed to be able to facilitate night time operations as well.


Page 17

5.3 Operational Checks before Manoeuvring

5.3.1 Final Checks on Ship Compatibil ity

5.3.1.1 COMMUNICATIONS

Satisfactory communications between the SRT and FSRU should be confirmed by checking:

a) That the FSRU is fitted with operational VHF;

b) The VHF frequencies (channels) to be used;

c) Whether it is possible to communicate readily in English; if not, the alternative common

language that is to be used.

If the above checks find a serious communication problem or lack of understanding of the operation

among either of the crews, then action should be taken to solve this issue by, for example,

transferring an experienced person from one vessel to the other, before operations begin.

5.3.1.2 MOORING CHECKS

The FSRU should exchange the following information with the SRT mooring Master:

a) The length overall and parallel body length of the vessel;

b) The distance from the cargo manifold centre to the stern;

c) Whether the vessel’s side to be used for mooring is free of obstructions;

d) The number of enclosed fairleads and mooring bitts and their distance from the bow and the

stern on the side of the vessel used for berthing. In this respect the Master having overall

advisory control should prepare a sketch of the proposed mooring layout with distances marked

thereon; and

e) The maximum expected freeboard. The FSRU shall the ability, by design, to maintain a

constant relative free board. This is essential in order to stay within the operability envelope of

the loading arms, and it is not intended for the mooring lines to have a vertical orientation.

5.3.1.3 LOADING ARM AND CONNECTION CHECKS

LNG transfer is through loading arms, hoses shall not be used. The SRT mooring Master should

confirm with the FSRU:

a) The diameter and class (ANSI (ASA), DIN, etc.) of cargo manifold flange to be used;

b) The anticipated minimum and maximum height of the cargo manifold from the waterline during

the transfer operation.

5.3.2 Preparation

The following preparations should be made by the Master of the FSRU before manoeuvres begin:


Page 18

a) A study of the cargo transfer procedures developed as part of this project, supplemented by

instructions issued by COMPANY;

b) Appropriate checks, such as the testing of essential cargo equipment. Procedures of this type

are described in the Tanker Safety Guide (Liquefied Gas) [2];

c) Crews fully briefed in procedures and hazards, with particular reference to mooring and

unmooring;

d) Checks made to ensure that each ship shall be able to comply with all requirements of the

Operational Safety Check Lists, Appendix 1 LNG Transfer Check Lists;

e) Engine controls, steering gear and all navigation and communications equipment confirmed to

be in working order;

f) FSRU is upright (having no list) and at a suitable trim;

g) Cargo manifolds prepared;

h) Area weather forecasts for the transfer period obtained; and

i) Mooring equipment checked.

5.3.3 General Safety Requirements

5.3.3.1 CHECKLISTS

Checklists are essential reminders of the principal safety factors to be considered. They should be

supplemented by continuous vigilance throughout the whole operation. Operational Safety Checklists

to be used during the various stages of the operation are given in the Appendix 1 LNG Transfer

Check Lists.

Before mooring operations commence, each vessel should confirm with the other that all items on

Checklists 2 and 3 have been checked and found correct.

5.3.3.2 ACTION IN CASE OF INFRINGEMENT OF SAFETY

If the FSRU fails to observe any of the safety requirements at any time during LNG transfer

operations, this should be brought to the attention of the Master of the FSRU and operations

suspended until the situation is rectified.

5.3.4 Navigational Signals

The navigation lights and shapes to be shown, and the sound signals made, during transfer

operations are those required by the International Regulations for Preventing Collisions at Sea [3] and

local port regulations.

From the start of the approach manoeuvre by the FSRU the vessel should display the appropriate

visual signals and should keep them displayed until the operation is completed.


Page 19

5.4 Manoeuvring and Mooring

5.4.1 Basic Berthing Principles

In weather conditions anticipated at the sites, successful berthing operations of the FSRU can be

undertaken at the SRT. Tugs shall be in position to assist with the mooring and unmooring

operations. Typically normal berthing operations are not attempted when the tidal stream is due to

change. Regardless of the tidal conditions, in an emergency, safe unmooring and separation can be

carried out.

Approach, mooring and unmooring operations shall be carried out with the operator's pilot/berthing

Master on board the FSRU. When approaching the jetty the FSRU shall ensure that the approach

angle is not too excessive. The FSRU shall approach the jetty from broad on the quarter. Tugs shall

be made fast as per the pilot's advice. On closer approach the FSRU would parallel the orientation of

the jetty, about 50 to 100-m off. The pilot on the FSRU shall line up vessel's cargo manifold with the

loading arms of the jetty, and with tugs assistance, contact shall be made with the fenders.

Mooring lines shall be passed and the FSRU/ made fast to the jetty. With tugs assistance, any

possibility of the FSRU making an unplanned contact with the jetty shall need to be eliminated.

5.4.2 Fender Positioning

The SRT shall have installed permanently positioned foam filled or pneumatic fenders. The type and

size, and number of the fenders shall be established by means of a detailed mooring analysis, with

the site specific metocean conditions as an input. The fenders shall be sized to prevent the FSRU

from making contact with the jetty structure while they are alongside.

Primary fenders shall be secured in place on the jetty. Typical fendering arrangement has the

primary fenders along the parallel body. Should the detailed analysis indicate the need to provide

additional secondary fenders, fore and aft of the parallel body, these shall be provided for.

The FSRU, with tugs assistance, shall ensure that the vessel can be moored in a manner that

ensures contact only along the parallel body. Unmooring can also be accomplished similarly, with the

FSRU maintaining a parallel orientation to the jetty.

5.4.3 Size of Fenders

The size of the fenders would be dictated by the site specific mooring analysis carried out. Typically

the diameter of each fender should be no more than half the minimum freeboard of the smaller ship.

5.4.4 Mooring Equipment and Preparations

The importance of good quality mooring lines, efficient winches and deck machinery should be

recognized. This is especially true on board the FSRU whose mooring lines shall be used most

commonly. This should also be addressed at the jetty, where rope-messengers have to be made

ready between fairleads and winches.

Mooring operations shall be managed to ensure expeditious mooring line handling. Moorings shall be

arranged and rigged to allow safe and effective line tending when the FSRU is secured to the jetty.


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As a general guide, a combination of head, stern, spring and breast mooring lines should be used,

with the spring lines running from fore/aft of the jetty to the aft/fore of the FSRU, and breast lines

typically located at the fore and aft. The purpose of the spring lines is to prevent longitudinal motions

between the vessel and jetty, whilst the breast lines prevent fore and aft separation of the vessel.

It is important when agreeing on a mooring plan to ensure the following:

a) Mooring lines are of sufficient length to avoid overstressing during freeboard changes;

b) Mooring lines are not too long so allowing unacceptable movement between jetty and vessel;

c) Mooring lines leading in the same direction are of similar material;

d) Mooring lines are not likely to escape from open fairleads. The FSRU itself shall have closed

fairleads;

e) Mooring line dynamics and loading arm operational envelope has been taken into account;

f) Only one line connects to each quick release hook (alternated).

5.5 Procedures Alongside

5.5.1 Pre-Transfer Procedures

Once the FSRU and LNGC are securely moored, the Masters of both vessels should ensure that

Check List 4, Appendix 1 LNG Transfer Check Lists, has been satisfactorily completed and that a

safe condition has been established.

5.5.2 Tending of Fenders and Mooring Lines

Throughout cargo transfer, fenders should be in the agreed positions and mooring lines should be

watched for excessive loads. In addition, power for the mooring winches should always be available.

5.5.3 Planning for Cargo Transfer

An example for the planning of a cargo transfer operation is depicted below. Specific items may need

to be addressed when a detailed LNG cargo transfer plan is developed. As an example the plan shall

include information on the following:

a) Line cooling;

b) Initial transfer rate;

c) Maximum transfer rate;

d) Procedures for the use of a booster pump;

e) Maximum Allowable Relief Valve Setting (MARVS) including port and sea settings, if

applicable;

f) Procedures agreed for vapour control or vapour return;

g) Signal for slowing down transfer;


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h) Signal for stopping transfer;

i) Emergency stop signal;

j) Emergency Shut-Down (ESD) arrangements;

k) Manifold valve closing period;

l) Contingency plans for emergencies such as leakage or spillage; and

m) Ballasting and deballasting.

5.5.4 Loading Arm Connection

5.5.4.1 MANPOWER FOR LOADING ARM CONNECTION

The SRT shall provide suitable competent personnel for operations involving connection of the

loading arm.

5.5.4.2 INSULATING FLANGE

During loading arm, connection and disconnection, vendors’ recommendations regarding handling,

connecting and disconnecting shall be strictly followed. If an insulating flange is provided, it must not

be allowed to touch any part of the ship’s decks or other structures. Such contact would short circuit

the flange, so defeating its purpose, and run the risk of electrical arcing at the cargo manifold. In

addition, a ground cable shall be provided to ground the FSRU with the jetty.

5.6 Cargo Transfer Operations

5.6.1 Loading Arm Handling

All personnel tasked with handling the loading arm shall be trained with the CONTRACTORS

procedures. Their competency shall be assessed and documented before they are allowed to be

involved in the operation of the loading arms. Strict adherence with the CONTRACTORS guidelines

with regard to the operation and maintenance shall be ensured.

5.6.2 List and Trim

During cargo transfer, ballast operation shall be performed in order to maintain a constant freeboard.

Listing of the FSRU should be avoided.

Before cargo transfer commences, good communications should be established between essential

personnel on each ship and the pre-transfer checks (Check List 4) should be satisfactorily completed.

In addition, attention should be given to the appropriate checks from ISGOTT [4].

5.6.3 Cargo Flow Rates

Before starting cargo transfer, the LNGC must be informed by the FSRU of the flow rates required for

the different phases of the cargo operation. If variations in transfer rate become necessary, the

FSRU should advise the LNGC accordingly.


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The agreed transfer rate shall not exceed the recommended flow rates for the loading arms in use.

During cargo transfer, the maximum transfer rate should be kept consistent with the receiving ship’s

receiving capacity.

5.6.4 Vapour Return

The vapour return connection limits the need for vapour release to the atmosphere, and may improve

the transfer rates as well. A vapour return connection is mandatory for the FSRU.

5.6.5 Cargo Transfer – General Requirements

Throughout cargo transfer operations, the LNGC and the FSRU should station a responsible person

at the designated control rooms. The manifold area on the FSRU is constantly monitored by CCTV's

with the monitors placed in the CCR. In addition, on the LNGC, throughout the cargo transfer, a

responsible person equipped with a portable radio should be stationed at or near the cargo pump

controls to take action as required.

Cargo transfer should begin at a slow rate to enable the FSRU to check that the cargo pipeline

system is correctly set. The transfer rate should be reduced when the FSRU’s tanks are reaching

their filling limits.

Towards the end of transfer and at other critical periods, visual contact should be established

between responsible officers on both ships. This should be in addition to portable radio

communication.

5.6.6 Accidental Cargo Release

Any leakage or spillage should be reported immediately to the officer in charge who should stop the

cargo transfer.

5.6.7 Metering Requirements

It is not currently considered necessary to install a dedicated LNG loading metering system on the

FSRU. The custody transfer content from the LNGC to the FSRU shall be established by ullage.

5.6.8 Completion of Cargo Transfer

After completion of cargo transfer the following operations shall be carried out:

a) Purging requirements to be complied with SIGTTO guidelines (LNG operational practice);

b) Loading arm disconnected, taking precautions to ensure that no liquid is left in the cargo

transfer system. The pressure in the system should be released through an appropriate device;

c) Cargo manifolds securely blanked;

d) Authorities informed of completion of cargo transfer and the anticipated time of unmooring; and

e) The FSRU N2 system shall be capable to purge the FSRU, SRT and LNGC cargo and vapour

lines. The loading arm purging procedure as stipulated by the manufacturer shall be followed.


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5.7 Unmooring

5.7.1 Unmooring Procedure

During unmooring operations, the pilot/berthing/loading/discharge Master is on board the FSRU.

Unmooring operations are always carried out under the advice of the pilot.

5.7.2 Unmooring Checks

Sufficient crew should be allocated to unmooring stations and consideration should be given to the

following points:

a) Side of cargo transfer cleared of obstructions, including derricks or cranes;

b) Method of disengagement and of letting go mooring lines agreed;

c) Fenders, including their towing and securing lines, checked to be in good order;

d) Winches and windlass ready for immediate use;

e) Rope messengers and rope stoppers ready at all mooring stations;

f) Fire axes available at each mooring station;

g) Crew at stations;

h) Communications confirmed between ships;

i) Communications established with mooring gangs;

j) Mooring gangs instructed to let go mooring lines only as requested by the pilot; and

k) Shipping traffic in the vicinity checked.

5.7.3 Procedure for Unberthing

The order of letting go the mooring lines shall be decided by the pilot. The entire sequence of events

shall be discussed with the Master on the FSRU. Their acceptance is essential prior to

implementation of the unberthing process.

Unberthing operations shall be carried out with tugs assistance, which shall be in attendance.

Experience has shown that satisfactory unmooring can be achieved by singling up fore and aft, then

letting go the remaining forward mooring and allowing the bow to swing away from the jetty to a

suitable angle (about 5°), at which time the remaining stern mooring line is let go and the carrier is

drawn clear. After disengaging, the FSRU should not attempt to steam ahead or fall astern, until the

ship and jetty are well separated.

After singling-up, some pilots prefer to let go the aft mooring line first and then let go the remaining

forward mooring line. In either case, the angle of disengagement should be small, about 5°.


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5.8 Parcel Size/Offloading Rate

LNG offloading frequency and parcel size shall be analysed over the design life of the project in order

to optimise the economies of the project. In reviewing this aspect of the FSRU’s design, safety

considerations shall be taken into account (such as impact on safety of more frequent, but smaller

parcels). Minimum parcel size to be accepted is 125,000-m³, minimum offloading rate is 10,000-m³.

5.9 Boil Off Gas

Boil off gas (BOG) results from the storage and loading of LNG. LNG stored in the tanks shall boil off

due to heat leakage, while loading shall generate additional BOG due to a reduction in vapour space.

The BOG from the FSRU LNG storage tanks shall be sent to the LP BOG compressors. The LP

compressed boil off gas shall be used as fuel gas for power generators or re-injected into the LNG at

the suction of the LNG booster pumps. During LNG loading from an LNGC, the BOG may also be

transferred to the LNGC via the vapour return line.

Excess BOG from the LP compressors is sent to the HP BOG compressors. The HP compressed

gas is then injection into the export pipeline to be sent to ORF.

Only under adverse circumstances shall BOG be sent to the flare system or tank vents for disposal.

In general, the BOG shall be used for power generation on the FSRU.


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6 REGASIFICATION OPERATION PHILOSOPHY

The LNG vaporisation (or regasification) process shall consist of the following equipment items as a

minimum:

a) HP LNG pumps, also known as LNG booster pumps;

b) LNG vaporisation units.

Refer to the regasification plant functional specification [7].

The LNG is provided to the process plant at a pressure of 250-kPag and temperature of -160°C by

the LNG tank pumps to the suction manifold of the HP LNG pumps. The design and arrangement of

the pumps and vaporisation units depends on the technology selection (section 6.2). The vaporised

LNG is collected via a manifold before being metered and sent to the ORF via pipeline.

6.1 LNG Pumps on FSRU

Each LNG storage tank shall have its own submersible LNG cargo pumps to deliver LNG to the

regasification plant. The cargo pumps are rated to 500-m³/h minimum and 250-kPag discharge

pressure to feed into the LNG booster pumps located at the regasification plant. The cargo pump’s

rating of 500-m³/h and 250-kPag nominal values and shall be confirmed during detailed design phase

of the project.

The LNG cargo transfer system shall comply with standard LNGC requirements and design.

The LNG booster pumps shall be a variable speed electric drive vertical canned pumps (suction

vessel mounted). The pump speed shall be controlled primarily by the required gas export pressure,

secondarily by the pump protection system.

The pumping system shall typically consist of 3 duty pumps and 1 standby pump. The number of

LNG pumps required shall be determined by CONTRACTOR during detailed design phase of this

project.

6.2 LNG Vaporisers

Refer to the regasification plant functional specification [7].

6.3 Available Technologies

The details of the vaporisation technology have not been finalised and hence specific operating

requirements are not provided herein. Three types of vaporisation technologies have been selected

as most suitable for this project:

a) Ambient air vaporiser (AAV) is modular and segregation into “production trains” is not required.

The LNG booster pumps can be manifolded on the discharge and the pressurised LNG

distributed to the vaporisation cells;

b) Intermediate fluid vaporiser (IFV) is not modular and hence manifolding of the booster pump

discharge may not be feasible as dedicated “production trains” are required;


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c) Shell and tube vaporisers (STV).

6.3.1 Ambient Air Vaporisation

AAV technology uses air as the heating medium. The vaporisers are vertical, finned tube exchangers

with the air circulated by fans on top of the units.

The gas outlet temperature does not need to be controlled and hence the fans can be fixed speed.

During the LNG vaporisation process, moisture from the air shall condense on the heat exchanger

tubes and then freeze. As the ice layer builds up, the gas outlet temperature decreases. At a

nominated gas outlet temperature, the AAV shall stop production and perform a defrost operation to

remove the ice layer. This operational requirement is incorporated into the design of the system in

that the AAV system shall have excess vaporisation cells to allow for defrosting without impacting in

overall system capacity. The number of excess vaporisation cells required for the AAVs shall be

determined during detailed design phase of the project to ensure required availability of the FSRU is

maintained.

6.3.2 Intermediate Fluid Vaporisation

6.3.2.1 GENERAL

Intermediate fluid vaporisation uses seawater to vaporise the LNG. The key process equipment is a

stainless steel shell-and-tube heat exchanger where the cold LNG vaporises to form warm export

gas. The process has the same concept as AAV except that seawater is the heat transfer medium

instead of air.

Seawater is drawn in through a sea chest and pumped through the seawater glycol/propane

exchangers. The cold glycol/propane returning from the process area is warmed by the seawater; the

cold seawater is discharged.

The warm glycol/propane is circulated to the LNG vaporiser where the warm glycol/propane is cooled

by the vaporising LNG. The cold glycol/propane enters the glycol/propane expansion vessel on

exiting the LNG vaporiser. The cold glycol/propane is then returned to the seawater heat exchangers.

6.3.2.2 GLYCOL/PROPANE WATER SYSTEM

The glycol/propane system is expected to circulate at constant flow under all gas export rates. This

shall reduce the process response time on increasing demand as well as providing a simple operating

scheme.

The cold glycol/propane returning from the process area via the expansion vessel is pumped by high

volume, low head pumps into the seawater-glycol/propane plate heat exchangers. The

glycol/propane is warmed up and the sea water is in turn cooled.

Warm glycol/propane is distributed to the four LNG vaporisation trains under flow control. The

glycol/propane is cooled by the vaporising LNG. The cold glycol/propane leaving the LNG vaporiser

flows into the glycol/propane expansion vessel. The vessel has two purposes:


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a) Expansion/capacity vessel to maintain a liquid seal to the glycol/propane pumps under all

operating conditions;

b) Disengaging of gas in the event of a vaporiser tube rupture. High pressure gas and LNG shall

enter the glycol/propane stream. The gas is passed to the flare system for disposal and at the

same time prevents LNG entering the glycol/propane pump suction.

The expansion vessel is buffered with nitrogen. The gas outlet nozzle of the vessel is connected to

the flare system.

The liquid outlet nozzle of the vessel has a shutdown valve; in the event of high pressure or low level

in the vessel, the shutdown valve closes to protect the glycol/propane loop from gas ingress.

6.3.2.3 SEAWATER SUPPLY AND TREATMENT

The seawater system requires filtration to remove debris and marine life. This protects the seawater-

glycol/propane exchangers from blockage by solids.

In addition, the seawater is chlorinated to minimise the growth of marine life inside the pumps, heat

exchangers and piping. Chlorination is expected to be in-situ using a hypochlorite generator or

similar BCC system. Systems that require external injection of hypochlorite are not preferred due to

the additional chemical handling and transport requirements.

It is expected that the seawater flow shall remain constant under all operating conditions.

6.4 Shell and Tube Vaporisers


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7 GAS EXPORT SYSTEM OPERATION PHILOSOPHY

7.1 Overview

The gas export system receives the LNG vapour from the vaporisation trains. The gas is metered in

preparation for injection into the pipeline to the ORF.

Analysis of the export gas, such as composition, calorific value and Wobbe index, shall not be

performed on the FSRU.

Odorisation of the gas is not required under the current project scope, though this may be subject to

change during the detailed design phase of the project.

The gas export system will also provide a take-off to allow gas to be returned to the storage tanks to

maintain tank pressurisation.

7.2 Gas Metering

Gas metering is expected to be of custody-transfer accuracy. In addition, the gas meters shall form

part of the pipeline inventory management and leak detection system.

The gas metering system shall also form part of the topsides control and shutdown system in

detecting low gas export temperatures, preventing liquid LNG entering the pipeline.

The fiscal metering shall be located at the ORF.

7.3 Pig Launcher

The pig launcher shall be provided, either as installed or as allocated space, to allow pigging of the

pipeline. As the export gas is non-corrosive and does not contain liquids, it is expected that pigging

shall only be required on initial commissioning and afterwards only for intelligent pig surveys as

required by the regulatory authority.

7.4 Gas Pipeline

The gas pipeline shall be a carbon steel pipeline connecting the FSRU with the ORF via 2 x high

pressure gas send-out loading arms.

Standard external corrosion protection of the pipeline shall be provided.

The pipeline shall be fitted with a “Last Valve Off” (LVO) located in a protected area of the riser as

well as a “First Valve On” (FVO) at the ORF to protect the FSRU, pipeline and ORF.


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8 RELIEF AND VENT SYSTEM OPERATION PHILOSOPHY

8.1 Overview

A relief and vent system is required to dispose of process vapours and liquids in the event of an

emergency. The flare and vent systems shall comply with API STD 521 and shall be separate from

the LNG tank vents (marine systems).

Vapours are captured in the flare headers and sent to the flare drum. Liquids are captured by a

closed drain system and routed to the flare drum for recovery and disposal. The flare drum has an

internal electric heater to help with the disposal of cold liquids.

Vapour from the flare drum shall be sent to the flare gas heater before flowing to the elevated flare tip

for disposal. The flare gas heater is intended to prevent low temperature gases entering the flare

system.

8.2 Relief Contingencies

Relief contingencies shall be addressed in more detail as part of the relief and blowdown philosophies

to be developed during detail design phase of the project. At this stage the major relief events shall

be:

a) A blocked discharge of the LNG vaporisers, equivalent to the maximum production capacity of

the FSRU;

b) IFV or STV tube failure.

Additional relief events are expected to be blocked discharge of the BOG compression system.

8.3 Blowdown

Blowdown and release of gas and liquid to the flare system is not expected to be a common

occurrence. The process shall be designed to retain all fluids within the equipment under all


Blowdown is expected to occur mainly due to events external to the process e.g. fire and gas alarm,

maintenance etc. Blowdown shall be constrained to hydrocarbon bearing equipment such as

vaporisers, LNG pumps, BOG compression and gas export.

Emergency blowdown shall comply with the requirements of API STD 521 and sent to the flare

system for disposal. Blowdown of liquid sources shall be minimised; blowdown of vapour streams is

preferred.

8.4 Manual Drains and Vents

The process area will be serviced by at least 3 drains systems: open drains, closed drains and

cryogenic drains.


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The open drains system will collect all liquid discharges from equipment via tundishes. The open

drains system is expected to tie into the FSRU’s slops system for disposal. Deluge and rainwater will

shall be able to be routed and disposed of via this route, but in general would be discharged directly

overboard.

The closed drains system will collect all pressurised liquids, such as equipment drains, for equipment

that operates at ambient temperatures. The closed drains system will connect into the LP flare drum.

The cryogenic drains system will collect all pressurised low temperature liquids from equipment

drains. The cryogenic drains system will connect to the LP flare drum at a location separate to the

closed drain tie-in to prevent ice/wax formation.

Process and equipment vents will be connected to the LP and HP flare headers as appropriate for the

disposal of all vapours.


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9 CONTROL AND SHUTDOWN OPERATION PHILOSOPHY

9.1 Shutdown

9.1.1 Hierarchy

The FSRU shall be in accordance with the FSRU safety philosophy document. The FSRU shall have

two separate programmable shutdown systems as follow:

a) Fire and Gas System (FGS): detects gas, flame, heat and smoke, operates warning sirens and

lamps and electrically isolates power systems and batteries as well as initiating the release of

fire fighting systems;

b) Safety Instrumented System (SIS): detects process parameter excursions outside normal

control band and settings;

c) Loading arm emergency release safety system;

d) Fully integrated with the jetty FGS or SIS system

9.1.2 Total FSRU Shutdown

A Total Shutdown (TS, ESD 1) is the highest level of shutdown and shall result in total shutdown of

the FSRU in preparation for abandonment.

An ESD 1 shall be initiated by activation of the ESD 1 pushbuttons or confirmed gas, fire or smoke in

safe areas such as the accommodation module or electrical/instrument room. Activation of an ESD 1

shall shutdown the FGS, SIS and the Process Control System (PCS), shutdown the engine room,

living quarter’s module, the emergency generator and the communications.

9.1.3 Marine Systems Shutdown

A Marine Systems Shutdown (MSS, ESD 2) shall result in power generation shutdown and isolation

of the FSRU from the pipeline.

An ESD 2 shall be initiated by activation of the ESD 2 pushbuttons or a confirmed fire in the process

or utility areas. Activation of an ESD 2 shall initiate the FGS, shutdown power generation and close

the Last Valve Off (LVO) to isolate the FSRU.

9.1.4 Main Deck Systems Shutdown

A Main Deck Systems Shutdown (MDS, ESD 3) shall cause a general FSRU shutdown.

An ESD 3 shall be initiated by activation of the ESD 3 pushbuttons, by confirmed high levels of gas in

the process or utility areas or by critical process shutdowns within the regasification process area

such as a high-high level in the flare knock-out drum. Activation of an ESD 3 shall shutdown the

process regasification system, the LNG loading arms and LNG loading pumps and the BOG system.


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9.1.5 Regasification Process Shutdown

A Regasification Process Shutdown (PS, ESD 4) shall cause a shutdown of the various process

systems within the Regasification process area and initiate a blowdown of these systems.

An ESD 4 shall be initiated by activation of the ESD 4 pushbuttons or by high importance process

shutdowns such as low-low temperature in the vapour line from the LNG vaporisers.

9.1.6 Unit Shutdown

A unit shutdown (US) is caused by less critical deviations such as low-low flow at the LNG pump,

where the only action is to shutdown the pump. For a unit shutdown, the specific unit, or train of units

(e.g. LNG pump and LNG vaporiser) shall be shutdown.

9.2 Regasification Process Control

9.2.1 General

Control of the operation of the processing facilities on the FSRU is by a Process Control System

(PCS). The intent of the control functions shall be to maintain stable operations as well as minimise

process excursions to avoid initiation of shutdowns. The SIS sends information to the PCS and

initiates pre-alarms in the PCS. Detailed description and operation of the PCS is provided in section

11.

Particular attention needs to be paid to the continued gassing of the cryogenic process equipment

under shutdown conditions. On a process shutdown, the residual LNG will continue to vaporise in the

LNG pumps, header and heat exchangers and this vapour should be sent primarily to pipeline or the

BOG system rather than to the flare system.

9.2.2 LNG Pumps

The LNG Pumps shall transfer LNG from the LNG collection header to the LNG vaporiser. An

ultrasonic flow meter located downstream of the pump shall indicate the flow through the pump. A

recycle flow control valve driven by flow controller at the pump discharge shall keep the pump

operating above its minimum continuous stable flow during low flow operation.

The pumps shall be stopped when any of the following is activated:

a) High-high pressure on the vapour outlet of the vaporiser;

b) Low-low temperature on the outlet vapour outlet of the vaporiser;

c) High-high pressure on the pump discharge; or

d) Pump seal failure.

9.2.3 LNG Vaporiser Control Requirements

The details of the vaporisation technology and hence control requirements are to be determined.


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9.3 Start-up and Restart

The start-up and restart methodologies will depend on the state of the equipment and length of

shutdown. Shock-cooling of equipment represents the major hazard due to the induced thermal

stresses.

Whenever cryogenic equipment is allowed to heat up a cool-down phase is required as part of start-

up to prevent vapour locking, liquid surges and shock-cooling. Therefore, it is preferable to operate

process trains at minimum turn-down rather than stop through-put.

Start-up and restart should occur at minimum capacities to allow equipment temperature profiles to

stabilise before increasing throughput to the required production rate.

The detailed procedures for start-up and restart will depend on the technology selection; IFV, STV

and AAV will require different approaches.

Under all scenarios it is endeavoured that vaporised LNG is sent to the pipeline as sales gas or to the

BOG system for recovery. Flaring and venting as part of normal start-up and restart will not be

accepted.


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10 MARINE SYSTEMS PHILOSOPHY

10.1 Availability

All marine systems onboard the FSRU shall be selected to achieve the level of reliability, availability

and maintainability required for continuous operations as FSRU in accordance with the BOD [1].

10.2 Machinery Space

The FSRU shall have an aft machinery space located aft of the cargo tank area. The expectation is

that a minimum of three generator sets will be required (3 x 50% redundancy). However, the exact

number of generator sets is to be determined by CONTRACTOR. The generator sets with all

necessary auxiliary equipment shall be arranged in this space. Further, all other equipment

necessary for serving the accommodation block are located in separate compartments of the

machinery space from the power generation compartments.

The decision on engine or turbine driven power generation will depend on the CONTRACTOR

proposed FSRU design.

10.3 Power Generation

The FSRU onboard power generation plant shall provide electricity for operation of all onboard

services. As a minimum these include but not limited to the following:

a) Emergency, communications, safety and lifesaving systems;

b) Regasification plant;

c) LNG offloading/loading operations;

d) Mooring system;

e) Full accommodation “Hotel Load” (including HVAC);

f) Ballast system;

g) Nitrogen generator;

h) Instrument air;

i) Fresh water supply;

j) One main fire fighting pump and one firewater jockey pump;

k) Diesel fuel transfer system;

l) Machinery room ventilation; and

m) Auxiliary support systems.

All equipment and services shall be arranged for unmanned machinery space operation with remote

control at the machinery control room and at the main control room.


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The engines shall be arranged for remote starting; automatic synchronization; load sharing, shedding

and stopping. The power supply system for FSRU shall follow existing ship electricity specification

and the system shall consist of:

a) Main Generator (Steam or LNG and/or MDO) for normal loads.

The main power generators will be sized to supply all FSRU electrical loads under all operating

conditions, under the worst case load and ambient conditions, with one main power generator

off-line.

b) Emergency Diesel Generator (MDO only) for essential load

The emergency diesel generator shall be sized to maintain power to essential users only. The

emergency generator will be connected directly to the FSRU Essential Switchboard, which

shall be single bus section with two incomers. One incomer will be connected to the normal

supply and this will be closed during normal operation. The second incomer will be connected

to the emergency generator. On loss of voltage at the essential switchboard, the emergency

generator shall automatically start up and regulate its speed and voltage. The supply from the

normal power supply will automatically disconnect, and then the incomer from the emergency

generator will automatically close to energise the switchboard. The controls for the essential

switchboard shall be designed so that after the automatic operation, it will be possible to re-

close back to the normal switchboard so that normal users can be supplied from the essential

power supply. This operation however shall be manually initiated and operating procedures

shall be written to ensure in this event the generator is not overloaded by normal users.

Essential loads are generally those loads listed below:

i) Feeders to all critical power supplies

ii) Emergency and escape lighting

iii) HVAC systems for rooms containing essential equipment

iv) Safe and Controlled Shutdown

v) Hazardous drain pumps (for continuous drain systems only) and flare/vent scrubber

pumps

vi) Instrument and utility air compressors

Where there are two redundant essential loads (e.g. pump A and B in a duty/standby

arrangement) one shall be fed from an essential switchboard and the other from a normal

switchboard.

c) Uninterruptable Power Supply (UPS) for critical load.

Critical Power Supplies are derived from storage batteries and distributed to critical users as

either AC or DC supply from UPS systems. The purpose of critical power supplies is to provide

the most reliable power supply for critical users. The autonomy time for the main UPS system

shall be 2-hours. Main UPS systems will be three phase or single phase dependent upon total

load requirements. UPS Power equipment shall be provided as 2 x 100% redundant


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rectifier/inverter units (UPS A and UPS B) and 2 x 50% batteries based on the calculated

design load for all connected critical users.

Critical loads are those loads necessary for the operation of safety systems and for facilitating

or assisting safe evacuation. It is generally not appropriate for any break in power supply for

critical users, even for a short duration. Critical users are generally those users listed below:

i) Fire & Gas safety systems

ii) Shutdown & Process Control Systems (ESD & DCS)

iii) Telecommunications systems (Voice & Data)

iv) Switchgear tripping and closing supplies

v) Generator backup lube oil pumps

vi) Emergency generator starting and control

vii) Diesel engine fire pump starting and control

viii) Escape routing lighting (self contained with integral battery)

ix) Exit lighting (self contained with integral battery)

Control systems, telecommunications are typically supplied from common UPS systems which also

supply other critical users of various systems and packages. Battery systems for diesel engines,

backup lube oil systems etc will normally be provided as part of the package supply. Diesel engine

driven generators and firewater pumps will have battery systems sized for cranking duty rather than

autonomy time.

The power generation system shall be capable of taking fuel gas from the boil-off gas compressor

and the regasification unit, as well from a marine system cargo heater system. The fuel gas

temperature is to be 15°C whilst the fuel gas pressure shall be determined by system requirements

during the detailed design phase of this project.

Cooling water requirements for the power generation system shall be of an approved marine standard

with an inlet temperature of 38°C. The fresh air water heat exchanger shall be of the double tube

type.

10.4 Power Management System

The Power Management System (PMS) shall be a dedicated system to allow smooth uninterrupted

transfer and shall accommodate the large regasification plant consumers.

The safe transfer of power shall be accomplished by automatic synchronisation and

connection/disconnection processes. The change over shall not result in disruption of power supply

to the regasification unit.

The power generation capacity shall provide a minimum 2 (+1 spare) generator capacity with each

generator providing 50% of the power required to operate 100% of the equipment listed above at

section 10.3. However, the CONTRACTOR shall propose a system that will guarantee 99.5%

availability.


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Table 10.1: Cause-Effect Scenarios on FSRU Operations

No Scenario Cause Effect on FSRU Operations

Power Management Action

1 Sudden loss of

power

onboard

FSRU (total

black-out)

• ESD

condition

onboard

FSRU

• Uncontrolled

black out

condition

onboard

FSRU

• Instantaneous black out

• Emergency services on

emergency power

supply

• Temporary interruption

of

cargo operations

• Essential load

transferred to onboard

emergency power

supply

• Resume normal

operations with

applicable restrictions

• Process control system,

process shut down

system, emergency

shutdown system, Fire &

Gas system will be

supplied by UPS

• Automatic start of

emergency generator


emergency power

supply

• Automatic start of main

generators

• Sequential start of

essential services

• Load sharing and

balance control

• Sequential start of non-

essential services

• Monitoring and control

of local power

generation supply mode


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No Scenario Cause Effect on FSRU Operations

Power Management Action

2 Sudden loss of

power

onboard

FSRU on one

generator

• ESD

condition

onboard

FSRU

• Uncontrolled

black out of

one

generator

condition

onboard

FSRU


emergency power

supply

• No temporary

interruption of

cargo operations

• Essential load

transferred to onboard

emergency power

supply

• Normal operations with

applicable restrictions


emergency generator


emergency power

supply


redundant generator

• Sequential start of

essential services


balance control

• Sequential start of non-

essential services


of local power

generation supply mode

3 Pre-planned

power transfer

from GENSET

to GENSET

• Anticipated

operational

conditions

• No interruption of

cargo regasification

operations

• No blackout

• Control the load to

below the capacity of

the onboard generators

• Start of generator

• Synchronisation and

power transfer from

generator to generator


balance control


of local power

generation supply

mode.

10.5 Cargo Heater

The cargo heater system shall provide two stages heating:

a) First stage = 0°C (to be in accordance with SIGTTO);

b) Second stage = 75°C (to be in accordance with SIGTTO).


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The cargo heater system shall also provide sufficient capacity to allow for warming up of one cargo

tank while simultaneously providing fuel gas to the power generation unit. The system shall comply

with the Classification Society, IGC Code – Liquefied Gas Carrier Code. The proposed system is to

be approved by COMPANY.

10.6 Low Duty and High Duty Compressor

Low and high duty compressor are required with 100% redundancy, and shall be placed in a cargo

compressor room. The system shall have surge control and surge control valves.

The system shall comply with the Classification Society, IGC Code – Liquefied Gas Carrier Code.

The proposed system is to be approved by COMPANY.

10.7 Fuel System and Sludge System

The fuel used onboard the FRSU shall be natural gas and MDO. All system shall be capable of

running on MDO, however, the normal FSRU operation shall be on natural gas with MDO as pilot fuel

(if required).

Oily water separators are to be provided for the MDO system and the sludge system shall have a

minimum storage capacity of 400-m³. The FSRU shall not use heavy fuel oil.

10.8 Ballast Water System

During normal operation of the FSRU, the LNG storage tanks will be required to be filled over a period

of approximately 18-hours, excluding ramp up and ramp down. The ballast tanks are required to be

emptied over the same period during these operations. The ballast system will allow both pumping

and gravity flow to/from the ballast tanks from/to the sea for the double bottom water ballast tanks.

The ballast system shall be able to provide a constant draught during FSRU loading operations.

10.9 Fire Water System

The FSRU shall be provided with fire extinguishing and fire fighting apparatus in accordance with flag

state requirements, the requirements of SOLAS 1974 and Consolidated 2001 version with

amendments, the Classification Society, IGC Code – Liquefied Gas Carrier Code, NFPA and API

requirements.

10.10 Compressed Air Systems

Compressed air will be required as plant/utility air and instrument air.

The air distribution system will be fitted with a priority system that ensures instrument air is supplied in

preference to utility air.


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10.11 Nitrogen System

Nitrogen will be generated by a nitrogen generation system using compressed air. The nitrogen will

be reticulated to engine room and deck users. The system will be fitted with (an) adequate nitrogen

capacity vessel(s) to ensure emergency nitrogen demands and start-up requirements are covered.

10.12 Fresh Water Systems

Fresh water will be generated on board the FSRU from sea water. Bunkering of fresh water will only

be considered in emergencies.

10.13 Seawater Systems

Seawater will be circulated to the engine room and deck users. If IFV or STV are chosen as the

process system, a decision has to be made whether or not to segregate the process seawater system

(IFV/STV only) from the engine room and deck users. The segregation will depend on space

requirements, equipment redundancy and equipment commonality.

The seawater is drawn in through the seachests, strained to remove particulates and debris before

being distributed to the end users.

The disposal method of the seawater will depend on location of users and volumetric requirements.

10.14 Hypochlorite Generator

As noted previously, hypochlorite will be generated in-situ using electrochlorinators or similar. The

level of hypochlorite shall comply with NEPA requirements and shall take the specific Portland Bight

protected zone requirements into account.

10.15 Diesel Systems

MDO will be distributed in the engine room and to the generators as required

10.16 Miscellaneous Marine System

Miscellaneous marine system shall conform to marine standards (IGC code and classification society

regulations) as well meet the availability and maintainability required for continuous operations of the

FSRU. The cargo heater, dry air systems and IGG (Inert Gas Generator) systems shall be able to

facilitate tank gassing-up, tank warming and tank cool down and aeration while maintaining the

remaining systems 100% operational. The IGG system shall meet the ability to purge all the FSRU

gas and vapour lines and shall be able to purge the LNGC vapour and loading lines after LNG

transfer.


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11 AUTOMATION, INSTRUMENTATION AND COMMUNICATIONS PHILOSOPHY

11.1 System Requirements

The FSRU shall be equipped with a fully integrated system, the Integrated Control and Safety System

(ICSS). This shall be scalable, single system architecture with integrated control and data

management system.

The ICSS, preferably from single manufacturer of common hardware, shall be an integrated system,

comprising of the following:

a) Process Control System (PCS);

b) Safety Instrumented System (SIS);

c) Fire and Gas System (FGS);

d) Loading Arm Control System;

e) Power Emergency Release System;

f) Position Monitoring System;

g) Steam/Gas Turbine Control System;

h) Vibration Monitoring System;

i) Compressor Control System;

j) Marine and Navigation Control System.

It is intended to be used for control, monitoring and safeguarding the FSRU facilities. The system

architecture proposed for the ICSS shall be defined in a Control, SIS and FGS System Architecture

Block Diagram during the early stages of the detailed design phase of the project. SIS and FSG shall

be SIL3 rated.

Although the ICSS shall comprise of a PCS, SIS and FGS as separate stand alone systems, they

shall be integrated seamlessly without duplication of functions.

The ICSS architecture and hardware shall be based on conventional, latest state of the art, distributed

control system with safeguarding system of a fault tolerant, TUV approved system.

System architecture shall be for optimum multiple communication and multi-supplier interoperability

without extensive and costly application programming.

A Management Information System (MIS) highway shall be configured to provide an upper level

monitoring, supervisory and data exchange functionality with other users. This network shall use

TCP/IP over Ethernet bridges. The network and its Ethernet bridges shall be dual redundant.

The MIS shall be unified direct from the field sensor to the FSRU via the stern mounted mooring

system of the FSRU in real time.


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The SIS and FGS systems being a sub-system of the ICSS shall meet the requirements of

COMPANY specifications for SIS and fire and gas system design.

An overall schematic of the automation, instrumentation and communications system of the FSRU

and its communications with the ORF is illustrated Figure 11.1.


Page 43

Figure 11.1: Automation, Instrumentation and Communications System Outline (Note: PLC System to be integrated but not shown)

FSRU

Forward Aft

Fibre Cable Link

Management Information Highway

ORF

DCS DCS DCS

FGS FGS ESD ESD ESD FGS

Process Control Highway

Loss Prevention Highway

Management Information Highway

Process Control Highway

Loss Prevention Highway

Operations Stations Operations Stations

Field

Transmitters

Field

Transmitters

Field

Transmitters

Input

Input

Input


Page 44

11.1.1 Overall Instrumentation and Control Philosophy

The overall philosophy shall be to use the appropriate level of technology, consistent with prevailing

HSE regulations, industry best practice and codes that shall provide the required reliability to meet the

project’s business targets. All existing instrument equipment (hardware and software) shall be

replaced.

The primary objective of this philosophy is to describe the requirements for a system which shall

minimise downtime and operating costs without a negative impact upon safety, the environment or

the operation of the combined facilities. The design shall maintain simplicity in system operation; and

shall facilitate diagnostics and faultfinding of operational issues or the maintenance of equipment.

The system equipment shall be selected based upon well proven design, service history, reliability

and integrity. All system equipment shall be standardised, wherever possible and practical, with the

equipment installed on the FSRU.

Field devices certified for use in hazardous areas shall utilise Ex ‘d’ (explosion proof) methods of

protection wherever possible and practical.

The general philosophy shall be to utilise Foundation Field Bus (FFB) field devices for all PCS field

devices where appropriate. FFB field devices shall not be used for accommodation/utility/marine

systems services and on the SIS or FGS. The use of FFB instrumentation for packaged equipment

shall be dependant on each vendor’s standard.

11.1.2 Systems Interface

Control data communications between elements of the ICSS shall use the ICSS vendor’s proprietary

communications system, or a recognised alternative i.e. Industrial Ethernet, as approved by

COMPANY. This control network shall be extended where required through OPC Gateway Units to

the PCS on the FSRU. For control data communications with other control systems external to the

ICSS, the use of OPC is preferred. Where communication interfaces are serial, they shall conform to

industry standard Modbus RTU communication protocols (RS-485, RS-422 or RS-232) and be

standardised throughout the facility. Each high-speed communication link shall be dual redundant.

ICSS control and asset management functionalities are to operate independently.

Dual redundant data links are required for the PCS to interface to large sub-systems such as:

• Offloading System;

• Regasification Control Systems.

• Marine Systems

Fibre-optic, multi-core cable shall be utilised for the data links, as it provides faster data

communications, is much more resistant to signal interference and is generally now the Vendor’s

standard data transmission cable type.

Unit Control Panels (UCP) for packaged equipment shall be utilised to operate major items of plant

equipment; with the SIS and FGS inputs and logic in the FSRU SIS and FGS systems.


Page 45

a) UCPs for new packaged equipment shall be PLC based and use a common hardware and

software as specified by COMPANY. In addition, status and alarm monitoring, shall also be

provided in PCS;

b) In the event that a vendor does not offer the above common PLC equipment, COMPANY’s

approval shall be sought for the proposed PLC system;

c) Local display shall be provided as part of the UCP for control, monitoring and diagnostics of the

packaged equipment.

11.1.3 Control Room and Human Machine Interface

The main operator interface for FSRU process and safeguarding systems shall be at a main control

console located in a CCR. The CCR and the Marine Systems Control Room (MSCR) – which

contains the cargo control and ballast control functions – shall either be combined in one room or be

immediately adjacent. They shall be equipped with a number of Operator Work Stations (OWS), each

with double layer flat screen to provide interfaces with both the FSRU process and the relevant

marine/utility systems. The Console shall also contain:

a) ESD manual pushbuttons, lamps, key switches etc;

b) Set of critical start-up and maintenance override key-switches;

c) Telecommunication workstation housing telephone handsets, PAGA access and crew radio

sets;

d) Closed circuit television system (CCTV) flat screens;

e) 1 off large screen display (LCD or overhead projector) which shall be able to display any ICSS

graphic screen;

f) 1 off ICSS data historian workstation;

g) 1 off ICSS data SOE workstation; and

h) PCS, SIS and FGS Engineering Work Stations (EWS) for systems diagnostics and carrying out

system configurations changes shall be installed in an adjacent Instrument Equipment Room.

11.2 PCS Specific Design Requirements

11.2.1 PCS Architecture

The PCS shall be based on a standard distributed control system open architecture with industry

standard high-speed data communication network. The PCS shall allow functional and geographical

distribution and integration of foreign devices.

The PCS shall provide an infrastructure for advanced control application, plant information network,

distributed plant performance review stations, FFB field devices and plant expansions.

Any OWS operating with the same database shall ensure 100% redundancy of the process control

system display. These OWS shall be mounted on an ergonomically designed control console.


Page 46

The operating system for all OWS and EWS should be Microsoft Windows based. Interface adapters

shall be provided on the workstation allowing connection to the Ethernet based MIS information

domain. The workstation shall be able to work as server to clients in the MIS connected to Ethernet

LAN.

The controllers are stand alone process control and data acquisition systems and interface the field

signals to the communication network via I/O termination assemblies, I/O modules, control processors

and network communication modules.

Interfaces to the SIS and FGS shall be carried out on a common control/SIS Highway. The

requirements for this highway shall be addressed in an Emergency Shutdown System Operating

Philosophy to be developed during the detailed design phase of this project.

11.2.2 Functional Requirements

The primary objective of the PCS shall be to facilitate control and monitoring (including the production

of written reports) by fast acquisition and processing of the parameters, to enhance the operator's

overall knowledge of the plant conditions and operational conditions.

The system is expected to monitor all points collected from various parts of the plant and present the

required information on the OWS screens in suitable formats at the operator's request thereby

offering a suitable operating interface.

The objectives can be summarised as:

a) Data acquisition and processing of inputs and displaying them on OWS for open loops, to

perform control tasks to generate control signal outputs in case of closed loops, and displaying

the data on OWS. It shall have self-tuning capability for the control loops;

b) It shall exchange the required information with the other nodes of the data network (including

OWS) to facilitate operation of control algorithms and also the functions of the operator

interfaces and algorithms of the other workstations;

c) It shall carry out extensive self-diagnostics and provide detail diagnostics display on the OWS.

The diagnostics shall cover all elements of the ICSS, and other sub systems including power

supply;

d) Plant and equipment monitoring, including alarming, trending archiving events and recording;

e) The PCS shall provide facilities for user application software development, system

configuration changes, process and safety picture development in on-line and off-line modes

including diagnostics;

f) It shall also have the capability for on-line modification of measurement and control

parameters, without impact on the running system; and

g) Plant management information and logs.

A large historical database shall be maintained for keeping the process value in suitable formats

enabling the operator to print out reports on-demand.


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11.2.3 Data Communication

Data communication between the system interfaces shall be at least 100-Mbps for nodes and 10-

Mbps for LAN. It shall be fault tolerant and dual redundant. The medium of data transmission shall be

fibre optic cables.

PCS system performance shall not be impaired by the loss of a single channel in the process bus. In

the event of a temporary loss of communications in the control network, all elements of the ICSS and

connected UCPs shall continue to operate independently to maintain the FSRU’s operations. A

communications watchdog shall monitor the correct operation of the control network communications,

and shall initiate a critical alarm in the event that communications are lost.

Selected data from PLC controlled packages shall be made available in the PCS. This shall cover

data for monitoring and normal control of package equipment from the PCS and common alarms for

diagnostics. This includes but not limited to:

a) Detail displays;

b) Graphics for process and diagnostics;

c) Configuration software;

d) Real time trends;

e) Overview;

f) Alarm display; and

g) Critical event archiving.

Data available from the intelligent motor control centre shall be made available in the PCS.

11.2.4 Tank Level Measuring Instrumentation

The cargo tank level measuring system of the FSRU is required to be fully redundant, based on two

different tank cargo level measuring principles. At this stage, it is proposed that a guided wave radar

beam shall be the principle method, with a floating sensor system as the secondary/check system.

The uncertainty in level measurements shall be in accordance with COMPANY’s specifications. The

achievement of the required level of performance associated with the tank level measurement system

shall be demonstrated during commissioning – with the design CONTRACTOR responsible for the

production of a validation procedure which demonstrates – both empirically and in reference to the

calculations results provided by the two systems installed – the measured uncertainty of the metering

instrumentations.

The cargo tanks shall be internally surveyed as part of detailed design modifications to accurately

establish their volume. The results shall be certified by an authorised surveying company to ensure

that the overall accuracy of the system is achieved. These measurements shall be used to produce

capacity tables for tank volume verification.


Page 48

11.3 Communications Philosophy

11.3.1 Telephone System

Telephone equipment shall be supplied to enable analogue extensions to be located on the FSRU to

be connected to the PABX at the ORF.

a) Telephones are to be located as a minimum in the following areas:

i) CCR/MSCR;

ii) Instrument Equipment Room;

iii) Restroom;

iv) Communications/IT Server Room/Radio Equipment Room (RER).

b) The following locations shall have telephones which are certified as suitable for a hazardous

area:

i) Musterpoint/Temporary Safe Refuge;

ii) Alternative Temporary Safe Refuge.

c) An analogue line is also required for PAGA system access.

11.3.2 IT Network

The FSRU IT network shall be extended to the ORF. This shall be implemented using a fibre cable

direct to the data network, via the FSRU electrical and communications swivel.

The network shall be implemented on CAT9 Structured cable. The telephone system shall use the

same structured cable network. There shall be no differentiation between the two systems, i.e. same

patch panels, numbering and outlet types.

11.3.3 Radio System

a) Marine VHF Radio

The FSRU operations are based on the VHF maritime radio frequencies. A specific channel

shall have been allocated for use in the field.

The same radio frequencies and channels used for the operations channels and marine

operations channel (VHF band) shall be used at the ORF. The radio signals shall be

broadcast/received at the FSRU by local aerials for the marine VHF services. Radiax (or other

similar leaky feeder) shall be used to broadcast/receive the signals within the safe internal

areas, e.g. equipment rooms, and workshops.

Two radios shall be installed in 19” racks and located in the RER; both shall have remote head

units located in the CCR. Additional remote head units shall be installed in key work areas

such as Workshop, First Aid Room, Instrumentation Room and Electrical Room.


Page 49

In the event of confirmed gas detection at any location of the FSRU, radio output power shall

automatically be reduced to 1-watt by the radio unit. The radio shall be Explosion Proof (Class

1 Div.2) type. CONTRACTOR shall advise if new frequency permit is required.

The aeronautical channel (VHF band) shall be required on the FSRU.

b) Crane Radio

The main cranes shall require Marine VHF radio for workboat communications. The radios

shall be a mobile type with remote head capable of interfacing to a boom microphone and Push

to Talk (PTT) interfaced to the crane joystick, a remote speaker shall also be required in the

crane cab for receive voice clarity. Each of the two main cranes shall be supplied (by others)

with access to local PA speakers for deck operations.

c) Survival Craft Radio

The lifeboat shall be equipped with a GMDSS (Global Maritime Distress and Safety System)

compliant Marine VHF radio able to operate on public and private marine channels. The radio

shall have a battery supply, which shall be float charged from the FSRU’s power system to the

survival craft. This charging circuit shall automatically isolate and disconnect when the craft is

launched.

In addition an Emergency Position Indicating Radio Beacon (EPIRB) capable of transmitting on

121.5-MHz and 406.025-MHz shall also be fitted. The EPIRB shall have manual release and

automatic hydrostatic release mechanisms and shall automatically activate on contact with the

ocean.

A Search and Rescue (Radar) Transponder (SART) shall be installed in the survival craft.

11.3.4 Public Address and General Alarm System

A PAGA system shall be installed on the FSRU. The FSRU system shall distribute audio alarms,

visual alarms and emergency messages, and shall be interfaced to the SIS for alarm input.

The PAGA system shall also be used for general announcements. As such it shall be zoned so as

not to interfere with sleeping personnel.

No single failure in equipment or cables, nor any single external event, shall cause significant

reduction of PAGA sound level in any area.

The PAGA system shall provide microphone input stations at selected locations throughout the

facility.

PABX access to the PAGA system shall be available for select users. This shall be achieved using

the PABX class of service restriction access.

The FSRU FGS system shall interface with the PAGA system for the annunciation of emergency

tones.

The PAGA system shall also activate alert beacons, where noise limits exceed 85-dBA.


Page 50

11.3.5 Close Circuit TV and Security System

A CCTV system with associated security functionality shall be installed on the FSRU. This shall not

be directly connected to other CCTV and security systems installed elsewhere in the field.

Colour CCTV cameras with heavy-duty pan/tilt and zoom mountings suitable for use in hazardous

areas shall be installed on the deck levels. Colour television monitors with a screen diagonal

dimension of a minimum 24” shall be installed in the CCR, with camera control keyboards. A LAN

interface shall be provided, such that cameras may be viewed over the LAN by using software

provided for installation on selected computers.

The camera controller and switcher unit shall be installed in the RER.

The CCTV system shall be used to maximise the visibility and safety of processing equipment during

operations. It shall be equipped with “flame flicker” fire detection, leakage and motion detection

functionality. This shall automatically initiate an alarm on the CCR central control console

human/machine interface, but not a Facility Fire Alarm; details of this alarm initial shall be covered in

the Emergency Shutdown System Operating Philosophy document to be developed during the

detailed design phase of the project. The CCTV system shall be pre-programmed so that the

activation of a fire or gas detector in the process areas shall automatically cause a CCTV camera

covering that fire zone to focus on the area identified.

An intruder alarm and security system shall be incorporated with the CCTV system; it shall

automatically initiate alarms both locally in the CCR and in the CCR’s at the FSRU and the ORF. The

system shall be interconnected to a digital video recorder to enable recording and later playback of

any potential safety or security events.

11.3.6 Recreational System

The FSRU is to be fully reticulated for distribution of recreational TV/radio programming.

This system shall provide radio/television antenna outlets in the living quarter’s accommodation

rooms, offices and in the TV/Video room for television and radio programs.

The cable distribution network shall terminate in the RER.

TV’s are to be provided in the entertainment areas and shall include DVD and video recording ability.

11.3.7 Meteorological System

The meteorological system shall provide weather recording and archiving facilities for the FSRU. The

system shall include the ability for authorised personnel to view weather data via the FSRU’s LAN.

The weather data shall be displayed on a graphical or numerical display capable of showing both

instantaneous readings and historical readings in user selectable intervals.

11.3.8 Muster Area Communications

The primary muster area is to be provided at the escape boats. An emergency response

communications panel and emergency equipment cupboard are located in this space. PAGA system


Page 51

access and control is needed as is VHF marine radio access. A single satellite phone (mobile Sat or

similar) shall be installed in this location for use in an emergency.

An alternate muster area is to be within the LQ, within the galley/mess room. An emergency

response communications panel and emergency equipment cupboard are located in this space. PA

system access and control is needed as is VHF marine radio access. A single satellite phone (mobile

Sat or similar) shall be installed in this location for use in an emergency.

11.3.9 Radio Equipment Room

The RER is to contain the telecommunications and entertainment equipment. Space is also to be

provided for a platform control system monitor. LAN connection outlets are to be provided in the

RER.


Page 52

12 MISCELLANEOUS OPERATIONAL PHILOSOPHIES

12.1 Simultaneous Operations

Simultaneous operations (such as maintenance activities beside “live” plant) are permitted on the

basis that an acceptable level of protection is in place to prevent loss of control.

As a minimum, two levels of protection shall be in place such that loss of any one protection measure

does not result in loss of control. Common protection measures for two or more operations shall be

acceptable.

Function testing of the agreed protection measures shall be undertaken prior to commencing the

simultaneous operations.

A simultaneous operations procedure shall be developed during the detailed design phase of the

project, detailing the set of simultaneous operations which are permitted and the measures which are

required to prevent loss of control. This information shall become the permitted operations, which is

part of the operating manual for the FSRU.

LNG regasification during offloading of LNG from an LNGC to the FSRU is a normal operating mode

and therefore is a permitted simultaneous operation. The protection measure in place is the loading

arms ERS. This system shall be function tested prior to loading commencing.

12.2 Supply and Storage Logistics

A philosophy of minimum storage provision on the FSRU shall be pursued, whereby only safety or

production critical equipment spares shall be stored.

All supply and logistics services including warehousing should be contracted.

It is assumed that the supply base shall be located at an available berth in the Port Esquivel area and

dedicated tug/supply boats shall provide all supplies to the FSRU using the public wharf and port

stevedoring services.

Transportable bulk liquid tanks for the supply of chemicals shall be used where practical. These shall

be designed for direct connection into the appropriate chemical injection system. Containers should

be limited in size, for ease of handling to 2500-litre mini ISO containers.

Provision for storage of liquid nitrogen shall be made, to be used for purging and refrigerant make up.

Provision shall be made for the storage of industrial waste/refuse skips on the basis of the frequency

of the tug/supply boat re-supply period. Temporary storage arrangements shall be acceptable in the

event of restricted marine operations preventing the backloading of refuse. Such temporary

arrangements shall be identified and developed to be included in the operating manual to be

generated during detailed design phase of this project.

Compaction units shall be considered in order to reduce space requirements.

For CO2 and FM-200 or equal systems, no storage of additional stocks shall be provided on the

FSRU on the basis that the design of the systems provides duty and standby units (storage bottles).


Page 53

No specific storage of personnel protective gear (e.g. overalls, safety boats, etc.) is required other

than nominal quantities for visitors, as personnel shall be expected to procure this gear from onshore

stores.

Storage space for catering goods (food, etc.) shall be provided based on the frequency of supply/tug

boats re-supply.

A separate secure drum storage area for chemicals shall be provided on the facility. Where practical

this shall also be used for the storage of dangerous goods. Segregation requirements shall be

established and met. All dangerous goods shall be labelled in accordance with the dangerous goods

code.

12.3 Supply/Tug Boats

The principal method of material supply to the FSRU shall be via the jetty. It shall be assumed that

marine operations for the purpose of re-supply can be halted for 7-days due to weather conditions.

However, a review shall be conducted during the detailed design phase of this project to confirm the

period over which marine operations may be halted due to weather conditions.

The supply/tug boats shall have a sufficient bollard pull to assist in offloading operations. In addition,

fire fighting equipment and a pilot platform for transfer of personnel between the FSRU and LNGC

shall also be provided by the supply/tug boats.

The tug/supply boats shall be either owned, leased or on long term contract, and in either case, the

management of the vessels shall be contracted.

The number of dedicated tug/supply boats shall be decided on the basis of being able to service all

FSRU supply needs, with some level of redundancies included to cater for events where supply/tug

boats are out of operation.

12.4 Materials Handling/Accessibility/Dropped Object Protection

12.4.1 Materials Handling

Materials handling procedures shall be developed during the detailed design phase based on the

results of the materials handing study. Equipment removal routes to designated laydown areas or

other areas as necessary, which are easily accessible by the FSRU’s cranes, shall be identified.

12.4.2 Accessibil ity

Good access shall be provided to items of equipment which require frequent (more than once per

year) testing, inspection or maintenance. This shall also apply to the permanent handling/lifting

devices (such as beams, pad eyes) installed for equipment removal.

Scaffolding or other temporary fixtures shall be used where equipment testing, inspection or

maintenance is less frequent (greater than 2-years).


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12.4.3 Impact Protection

The need for dropped object protection or additional protection of “live” process equipment from

dropped objects shall be studied as part of the materials handling study.

Crane and mobile vehicle operations shall be minimised near to or over “live” process equipment.

Dropped object protection shall not be required where infrequent heavy material movements near or

over equipment are carried out when the equipment has been isolated and depressurised.

12.5 General Housekeeping

FSRU housekeeping shall be the responsibility of shift personnel. When maintenance work is carried

out, the maintenance team shall leave the area clean and tidy.


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13 MAINTENANCE PHILOSOPHIES

13.1 Objectives

The primary objectives of the maintenance function shall be to achieve:

a) Technical integrity within COMPANY requirements;

b) Optimum equipment availability with the minimum of staffing levels;

c) Lowest life cycle cost; and

d) Meet legislative requirements with regard to equipment inspections/testing.

The FSRU shall be maintained so that it remains in an operable condition to the end of its design life

and can be maintained in service without a major re-build or dry-docking.

During the detailed design phase of the project, maintenance personnel shall be involved in order to

assist in achieving the above objectives (e.g. optimum equipment availability - through careful

selection and equipment arrangement).

A detailed maintenance philosophy for the FSRU shall be developed at the detailed design stage .

This shall detail the maintenance strategy to be applied to equipment and systems; either frontline,

preventative, "on condition" or breakdown maintenance. The selection of the maintenance strategy

shall be determined against the objectives set out above.

13.2 Servicing

The optimum means of servicing equipment shall be carefully assessed against maximising FSRU

availability. The servicing options, which shall be evaluated, are:

a) Maintain/repair onsite or in the facility workshop; and

b) Remove equipment and repair onshore.

Consistent with the philosophy of minimum staffing, onshore repair or maintenance shall be pursued.

Additionally the option of vendors providing full or part servicing of equipment shall be reviewed

during the design to determine the optimum strategy.

13.3 Maintenance Management

A maintenance, testing and inspection plan shall be developed by the FSRU CONTRACTOR. This

shall outline the type of maintenance required on each item of equipment/system (routine,

preventative or breakdown) against the objectives listed in section 13.1.

Maintenance/testing/inspection scheduling shall be based on this plan. As part of this management

process, a through-life database shall be developed to ensure continual improvement and enhanced

technical integrity.


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13.4 Frontline Maintenance

Frontline maintenance, such as condition monitoring, control valve repairs, trouble-shooting and

repair of field instrumentation, instrument calibrations and routine equipment servicing (lube oil

change, etc.) shall be carried out by production personnel.

13.5 Major Shutdowns

Major planned shutdowns shall be necessary to meet required storage tanks inspections (either set

by legislation including classification society rulings or technical integrity considerations) and the

replacement components associated with the regasification units.

Major shutdowns shall be planned to minimise the time offline by having a 24-hour working period

with a maximum labour input consistent with safe and efficient practices. Major shutdowns shall be

managed by using existing maintenance staff supported by additional contracted maintenance

personnel and specialist vendor personnel.

13.6 Subsea Inspection, Maintenance and Repair

Subsea inspection, maintenance and repair of the FSRU shall be carried in accordance with

recognised industry practices for a permanently moored facility. An inspection, maintenance and

repair plan shall be developed during the detailed design phase of this project to ensure continuous

operation of the FSRU for the year design life.

13.7 Condition Monitoring, Testing and Inspection

A maintenance, inspection and test plan shall be developed during the detailed design phase of the

project to cover all safety and production critical equipment. This plan shall outline the requirements

for the following tasks and activities:

a) Condition monitoring, including monitoring strategy and monitoring data collection and

processing;

b) Testing requirements as set out in vendor recommendations. Testing requirements shall also

be reviewed and modified as necessary based on equipment/system historical data;

c) Alarm and trip testing of critical trips and alarms;

d) Inspection requirements consistent with maintaining technical integrity and meeting legislation

and COMPANY requirements.

13.8 Certification

Early in the detailed design phase, the Certifying Authority shall be appointed. The work scope

definition for the Certifying Authority shall be developed in consultation with the appropriate

government department.

An integrated approach shall be developed whereby the Certifying Authority, design and operations

team work together to achieve the desired level of technical integrity.


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13.9 Spares Holding

Spares holding for the FSRU shall be based on the results of a reliability, availability and

maintainability study (RAM). In particular, spares shall be established for the regasification system

selected.

A critical spares listing shall be developed and used for setting the level of spares holding on the

FSRU itself.

The criteria for deciding on a critical spare shall be taken to be:

"An item of equipment which in the event of failure shall result in an unacceptable safety risk or a significant business loss"

The sparing philosophy is that the FSRU shall warehouse only safety or production critical equipment

spares. Spares shall not be held where equipment/systems are duplicated (spared) within the FSRU

(e.g. duty and standby pumps). Non-critical spares and consumables can be stored in a suitable

supply base/warehouse located onshore.

Sparing of portable fire fighting equipment on the FSRU shall be provided equivalent to 5% of the

total of each type of device so as to provide expedient replacement.

Commissioning, start-up and first year spares shall be identified during the detailed design phase and

are available prior to commencement of commissioning.

13.10 Permit to Work/Work Orders

All maintenance work on the LNG Facility shall be carried out under a “Permit to Work” system. Work

orders shall be generated and shall be prioritised (refer to section 13.3). In all cases, apart from an

emergency or breakdown, work orders shall be issued by the onshore maintenance support

personnel.


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14 REFERENCES

[1] WorleyParsons, “Jamaica LNG Project, Basis of Design”, 402010-00260-00-GE-BOD-0001.

[2] ICS, “Tanker Safety Guide (Liquefied Gas)”

[3] IMO, “International Regulations for Preventing Collisions at Sea”

[4] OCIMF, ICS IAPH, “International Safety guide for Oil Tankers and Terminals (ISGOTT)”

[5] WorleyParsons, “Jamaica LNG Project, Jetty Moored FSRU Functional Specification” 402010-

00260-MA-00-SPC-0006.

[6] WorleyParsons, “Jamaica LNG Project, Jetty Design Philosophy”, 402010-00260-MA-00-PHL-

0002.

[7] WorleyParsons, “Jamaica LNG Project, Regasification Plant Functional Specification”, 402010-

00260-00-PR-SPC-0001.

[8] WorleyParsons, “Jamaica LNG Project, ORF & Pipeline Functional Specification”, 402010-

00260-00-PR-SPC-0002.


Appendix

Appendix 1 LNG Transfer Check Lists


Appendix

Ship to Ship (STS) Transfer Check List 1: Pre-Fixture Information (For Each Ship) (Between Ship Operator/Charterer and STS Organizer)

Ship’s Name: Ship Operator: Ship

Charterer STS Organizer

Ship Operator’s Confirmation

Remarks

1. Is the transfer area agreed?

2. Are fendering arrangements agreed as being satisfactory?

3. Are communication procedures advised to each ship?

4. Is the centre of the ship’s cargo manifold X-m or less either forward or aft of midship position?

5. Is the centre of cargo manifold at least X-m above the deck (or above the working platform if fitted)?

6. Is the height of the centre of cargo manifold no greater than X-m above the deck (or above the working platform if fitted)?

7. What is the horizontal spacing between liquid and vapour returned manifold connections, measured centre to centre?

8. Is the ship able to present liquid and vapour return manifold connections?

9. Is the ship fitted with sufficient enclosed fairleads to receive all the other ship’s mooring lines?

10. Are two enclosed fairleads fitted for the other ship’s spring lines and are they positioned within X-m forward and within X-m aft of midship position?

11. Can the ship supplying the mooring provide soft mooring ropes or soft rope tails?

12. Are there mooring bitts of sufficient strength (suitably located) near to all enclosed fairleads to receive mooring ropes’ eyes?

13. Are both sides of the ship clear of any overhanging projections?

14. Is a contingency plan established for the transfer area?

For Ship Operator/Charterer:

Position:

Signature: Date:


Appendix

Ship to Ship (STS) Transfer Check List 2: Before Operations Commence Discharging Ship’s Name:

Receiving Ship’s Name:

Date of Transfer:

Discharging Ship Checked

Receiving Ship Checked

Remarks

1. Have the two ships been advised by the shipowners that Check List 1 has been completed satisfactorily?

2. Are radio communications well established?

3. Is language of operations agreed?

4. Is the rendezvous position agreed?

5. Are berthing and mooring procedures agreed and is it decided which ship shall provide the moorings ropes?

6. Is the ship upright (having no list) and at a suitable trim?

7. Are engines, steering gear and navigational equipment tested and found in good order?

8. Are the engineers briefed on engine speed (and speed adjustment) requirements?

9. Has a weather forecast been obtained for the transfer area?

10. Are loading arms checked and in operational condition?

11. Are fenders and fender pennants in good condition?

12. Are the crew briefed on the mooring procedure?

13. Is the contingency plan agreed?

14. Have local authorities been advised about the operation?

15. Has a navigational warning been broadcast?

16. Is the other ship advised that Check List 2 is satisfactorily completed?

For Discharging-ship/Receiving-Ship (Delete as appropriate)

Name:

Rank:

Signature: Date:


Appendix

Ship to Ship (STS) Transfer Check List 3: Before Run-In and Mooring Discharging Ship’s Name:


Date of Transfer:



Remarks

1. Has Check List 2 been satisfactorily completed?

2. Are primary fenders floating in their proper place? Are fender pennants in order?

3. Are secondary fenders in place, if required?

4. Have over-side protrusions on side of berthing been retracted?

5. Is a proficient helmsman at the wheel?

6. Are cargo manifold connections ready and marked?

7. Has course and speed information been exchanged and understood?

8. Is engine speed adjustment controlled only by changes to revolutions?

9. Are navigational signals displayed?

10. Is adequate lighting available, especially overside in vicinity of fenders?

11. Is power on winches and windlass, and are they in good order?

12. Are rope messages, rope stoppers and heaving lines ready for use?

13. Are all mooring lines ready?

14. Are the crews standing by at their mooring stations?

15. Are communications established with mooring agents?

16. Is the anchor on opposite side to transfer made ready for dropping?



Name:

Rank:

Signature: Date:


Appendix

Ship to Ship (STS) Transfer Check List 4: Before Cargo Transfer Discharging Ship’s Name:


Date of Transfer:



Remarks

1. Are all requirements form the International Ship/Shore Safety Check List complied with?

2. Is the gangway in good position and well secured?

3. Is an inter ship communication system established?

4. Are emergency signals and shut down signals agreed?

5. Is an engine room watched maintained throughout transfer and is the main engine on standby?

6. Are fire axes in position at fore and aft mooring stations?

7. Is a bridge watch and/or an anchor watch established?

8. Is a deck watch established to pay particular attention to moorings, fenders, hoses, manifold observation and cargo pump controls?

9. Is the initial cargo transfer rate agreed with other ships?

10. Is the maximum cargo transfer rate agreed with other ships?

11. Is the topping-off rate agreed with other ships?

12. Are the loading arms tested (after connection)?

13. Are the loading arms well connected and within operable limits?

14. Are tools required for rapid disconnection located at the cargo manifold?



Name:

Rank:

Signature: Date:


Appendix

Ship to Ship (STS) Transfer Check List 5: Before Unmooring Discharging Ship’s Name:


Date of Transfer:



Remarks

1. Are loading arms properly purged prior to hose disconnection?

2. Are loading arms or manifolds blanked?

3. Is the transfer side of the ship clear of obstructions (including any lifting equipment)?

4. Has the method of unberthing and of letting go moorings been agreed with the other ship?

5. Are fenders, including fender pennants, in good order?

6. Is power on winches and windlass?

7. Are rope messengers and rope stoppers at all moorings stations?

8. Are the crew standing by at their mooring stations?

9. Are communications established with other ships?

10. Are communications established with mooring gangs?

11. Has shipping traffic in the vicinity been checked?

12. Are mooring gangs instructed to let go only as requested by the manoeuvring ship?


14. Has the navigational warning been cancelled (when clear of other ship)?


Name:

Rank:

Signature: Date:

Attachment 11 - Personnel CV Forms

Personnel

Form PER -1

Proposed Personnel Bidders should provide the names of suitably qualified personnel to meet the specified requirements. The data on their experience should be supplied using the forms below for each candidate.

1. Title of position*

Name


Name


Name


Name

Form PER-2

Resume of Proposed Personnel

Name of Bidder

Position

Personnel information

Name

Date of birth

Professional qualifications

Present work Name of employer

Type of employment

Address of employer

Telephone

Contact (manager / personnel officer)

Fax

E-mail

Present Job title

Years with present employer

Summarize professional experience over the last 20 years, in reverse chronological order. Indicate particular technical and managerial experience relevant to the project.

From To Company / Project / Position / Relevant technical and management experience

Attachment 12 - Financial Resources Forms

Form FIN-1

Financial Resources

Specify proposed sources of financing, such as liquid assets, unencumbered real assets, lines of credit, and other financial means, net of current commitments, available to meet the total construction cash flow demands of the subject contract or contracts as indicated in Section III, Evaluation and Qualification Criteria

Source of financing Amount (US$ equivalent)

1.

2.

3.

4.

Attachment 13 - Letter from the Caribbean Coast Area Management Foundation (C-CAM)

BOARD OF DIRECTORS Chairperson: Ms. Thera Edwards, Prof. Aggrey Brown Rev. David Yee Sing, Dr. Karl Aiken,

Mrs. Maxine Whittingham – Osbourne, Mr. Krishna Desai, Mr. Earl Patrick, Mr. Merrick Plummer

CARIBBEAN COASTAL AREA MANAGEMENT (C-CAM) FOUNDATION

P.O. Box 33, Lionel Town, Clarendon, JAMAICA Telephone: (876) 986-3344, 986-3327 Fax: (876) 986-3956

[email protected]/[email protected]

August 30, 2011 Mr. Ernie Megginson Jamaican LNG Project | Office of the Cabinet 2a Devon Road Kingston 6 Dear Mr. Megginson Re: About the Caribbean Coastal Area Management Foundation (C-CAM) - "Working together to conserve Portland Bight"

Establishment and mission: C-CAM was established in 1997 with the mission of promoting conservation and sustainable development in the Portland Bight area. We base our work on sound science, and promote co-management and stakeholders’ participation.

Role in the area: The Portland Bight Protected Area (PBPA) was declared in 1999, based on C-CAM’s recommendations, and in 2003 C-CAM was delegated management responsibility on behalf of the Natural Resources Conservation Authority (NRCA). This arrangement ended in 2008, and we are currently negotiating with National Environment and Planning Agency (NEPA) to develop a new Memorandum of Understanding, re-establishing C-CAM’s role in the management of the area. This is expected to be in place by the end of 2011. In 2010 C-CAM entered into a Memorandum of Agreement with the Ministry of Agriculture and Fisheries to manage 3 fish sanctuaries in the PBPA including the Salt Harbour Fish Sanctuary.

Experience: We have unparalleled experience in working on environmental conservation and community development in the area.

· Surveys – We have carried out a wide range of surveys (including socio-economic, birds, coral reefs, and forests) and are currently managing a project that will establish a national base-line survey for fish sanctuaries.

· Participatory management planning and community involvement – we are now in our third cycle of management planning for the PBPA (C-CAM 1999, 2007, 2010 a, b, c, and in prep.). We also have considerable experience in



working with communities e.g. through Portland Bight Fisheries Management Council [1], and in partnership with the Parish Development Committees [2]. The Portland Bight Fisheries Management Council (PBFMC), through which fishers from across the Bight meet every month to discuss fisheries-related issues -the PBFMC has been meeting regularly since 1997. We are in the process of establishing a series of similar councils (e.g. for tourism and forest users).

· Education and awareness – We have considerable experience in education and awareness, including programmes to promote sustainable development, schools programmes and disaster planning.

· Disaster mitigation, planning and awareness – We have experience in disaster planning and have been proposed as one of the first responders to natural disasters in the area.

· Habitat restoration – We have successfully implemented several mangrove replanting exercises and are about to implement another project.

· Tourism – We are seeking to develop community-based tourism in the area and have developed feasibility studies for selected activities.

Related recent projects – We are currently implementing a project called “Participatory planning for management of the Portland Bight Protected Area” funded locally by the Forest Conservation Fund, which is expected to lead to the creation of a biosphere reserve1

o “Portland Bight Climate Change Adaptation Project” (funded by Global Environment Facility GEF) (including a schools programme, community monitoring and mainstreaming climate change into development planning)

. It also includes overall management planning for the whole area, zoning and developing recommendations for the more detailed surveys, and planning contained in this proposal. Some other relevant projects include:

o “Implementing Fish Sanctuaries in Portland Bight through Public Education” (funded by Environmental Foundation of Jamaica),

o “Portland Bight sustainable wetlands project” (funded by GEF) including wildlife assessments and community tourism development.

[1] Portland Bight Fisheries Management Council (established 1995) meets monthly to co-manage fisheries resources in the PBPA.

1 A Biosphere Reserve is a globally recognized area, established with UNESCO in which special efforts are made to ensure that human development proceeds in harmony with the natural environment.

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[2] Parish Development Committees are partnerships between government and the private sector and civil society to promote sustainable development at the local level. LITERATURES CITED: C-CAM 1999 Management Plan for the Portland Bight Protected Area. Prepared for Natural Resource Conservation AuthorityC-CAM 2007. Portland Bight Protected Area Biodiversity Conservation Management Plan, Document prepared for USAID. C-CAM 2010 a, b, c Fish Sanctuary Management Plans for Salt Harbour, Galleon Harbour and Three Bays Fish Sanctuaries. Yours truly, __________________ Ingrid Parchment Executive Director 876-383-2184

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PROFILE OF CARIBBEAN COASTAL AREA MANAGEMENT (C-CAM)

Updated: July, 2011. Caribbean Coastal Area Management Foundation (C-CAM) was established in 1998 to promote coastal conservation in Jamaica. Our mission is to promote sustainable development of the Portland Bight area. C-CAM worked closely with the NRCA to create the Portland Bight Protected Area in 1999. In 2003, the NRCA delegated the environmental management of the Portland Bight Protected Area (PBPA) to C-CAM. Since then financial and institutional constraints and disputes over the delegation instrument have limited C-CAM’s role in management. Unfortunately the NRCA failed to provide any of the financial, legislative or logistical support they had committed themselves to providing to C-CAM under the delegation agreement to enable us to implement any management. Despite this setback C-CAM has continued to build its capacity through training and seeking project funding from a wide variety of sources to implement as many aspects of the PBPA management plan as we could. To this end C-CAM has successfully implemented many projects and developed partnerships with community groups, government agencies, large companies and international agencies to further the sustainable management of the PBPA. It has also established the C-CAM Trust, a trust fund which is hoped will one day provide core funding for C-CAM and the PBPA in the future.

C-CAM has a highly qualified core staff including present Executive Director/Staff Accountant Ingrid Parchment, D. Brandon Hay (Science Officer / Fish Sanctuary Manager), Audrey Fowling (Information Technology Trainer/Librarian) and volunteers such as Raija Atkinson (University Student) and partnering consultant Dr. Ann Sutton (environmental specialist). Despite constant budgetary constraints, C-CAM has not experienced the high turn-over of staff that has characterized the NGO movement in Jamaica and all our core staff have been working for C-CAM (or its predecessor the South Coast Conservation Foundation, SCCF),for more than ten years. C-CAM has maintained high financial accountability and works with Howard Duncan & Associates accounting firm to prepare financial statements and to audit C-CAM’s financials as well as provide necessary information to ensure that C-CAM’s records can be up-to-date. The skills and experience of staff, partners, consultants and volunteers include extensive knowledge of the PBPA combined with management, accounting, community animation, socio-economics, conservation management, protected area planning and enforcement. They possess unequalled knowledge and commitment to the goals of C-CAM in the PBPA. The main office is located in Lionel Town, Clarendon where we also operate a community Cybercentre and environmental library. C-CAM is widely respected in the area and internationally. Project Management Despite its small core staff, C-CAM has demonstrated its ability to expand its capacity to manage a wide range of projects, both small and large. Examples of some of the projects C-CAM has implemented are listed below. • 2001-3: GEF/IDB - US$300,000.00 C-CAM negotiated a grant of US$4m from the Global Environment Facility GEF. This grant was to be a part of a project which was intended to advance a sustainable development agenda for a large part of Jamaica’s south coast. The project was known as the South Coast Sustainable Development Project. The

Jamaican government was to provide part funding through a budgetary allocation coupled with loan from the Inter-American Development Bank IDB. Those funds would have been counted as local counterpart funding to allow C-CAM to receive the GEF funds and we would be responsible to implement the South Coast project in the PBPA. It was agreed that the IDB would provide a loan to the Government of U$14m and our US$4m along with the Government’s contribution of US$2m would provide a total project budget of US$ 20m for the entire south coast sustainable project. C-CAM received an initial amount of US$330,000 as a project development grant to do the preparatory work and hire the necessary consultants to assist with putting together the proposal for how the funds would be used to manage the PBPA for the first five year period. We hired a project manager and a number of consultants to carry out this phase of the project which resulted in our upgrading our website, establishing our GIS capability including software and staff training, launching of the C-CAM Trust and engaging potential contributors locally and abroad. We were also able to develop specific management plans for enforcement, tourism, scientific research and monitoring, fisheries management, public environmental education among other things. Unfortunately the Jamaican government was unable to allocate their US$2m to begin the project and was unable to secure the IDB loan. The loss of the counterpart funding meant that C-CAM could no longer access the US$ 4m to establish the management of the PBPA. This represented a tremendous financial loss to C-CAM and we have continued to struggle to maintain funding for even the most basic operation and management of the area. • 2002: UNESCO – Organization of American States OAS - Socio-economic study We received a grant to do a detailed socioeconomic study of coastal communities in the PBPA. The project would also assist C-CAM to engage with a wider section of the residents of the PBPA and establish Portland Bight Citizens Councils. The data collection and data entry was done by the staff while the analysis and write up was done by the Executive Director at the time. The data is used by various government and academic agencies such as the Social Development Commission and other groups in their work as well as students doing research in the area. • 2004-5: Oxfam/ECHO - Post Ivan Recovery Project- J$5m This project included conducting surveys in nine communities to determine the needs of persons who had damaged or lost their sanitary facilities due to the passage of the hurricane. Based on the results of the survey we were able to build more than nine hundred (900) latrines in the area. We hired a project manager and more than fifteen (15) community persons to assist our staff with the various aspects of the project. We worked along with ODPEM & Red Cross as well as other agencies to offer public health/disaster planning information to community members. • 2005: USAID - Post Ivan- Fishers Recovery project After Hurricane Ivan we received a small grant from USAID which allowed us to purchase and distribute mesh wire to affected fishers on several beaches in the area to assist them to rebuild their stock of fish traps. C-CAM used the opportunity to purchase mesh wire with larger holes than was commonly in use to determine how this reduction of the fishing pressure on juvenile fish would affect the fishery. Unfortunately C-CAM was unable to fund a scientific assessment of the changes however there were strong anecdotal reports that the pots had to stay out longer but the catch (weight) was bigger. In collaboration with the Caribbean Maritime Institute CMI we offered training for several fishers in several related fields. Those fishers who attended all of the sessions received life jackets, certificates as

well as GPS units to assist them with their fishing. Some of those fishers still use those units when navigating long distances as well as when setting their pots at sea instead of relying only on landmarks. We also received funds to establish a radio system with repeater antennas in Portland Ridge and Port Henderson Hill. We received handheld radios as well as a few base stations and car radios for the system. This system will be an invaluable communication system that will be used by our rangers, community educators and voluntary game wardens.

• 2006/7: USAID - Ja Style - Our Gems - US$5,000.00 parenting project C-CAM has provided administrative assistance for other community organizations in the area. A small community organisation working in the May Pen area of Clarendon wanted to implement a project promoting proper parenting (working with parents and their children. C-CAM administered the project ensuring that the activities were on time and that the USAID funds were properly spent and accounted. • 2002, 2006/7/8: JSDN/UNDP J$5m (2 grants) & US Peace Corps J$350,000 These grants gave us funds to establish and maintain a cyber center which currently has ADSL Internet connection, twelve (12) computers, fax machine, scanners and five (5) printers/copiers. We offer computer classes to community members, students and business persons. Additionally we offer several services including but not limited to printing, photocopying, faxing (receiving & sending), typing and research. The UNDP funded project underwrote the cost to training more than one hundred (100) young persons (17-25 years old) in Information technology, dispute resolution as well as personal, career and small business development. We were also able to assist some persons as Interns as well as short and long term employment at our office as well as other business places/schools in Clarendon. • 2006-7: Cockpit Citizens Association(CCA) – EFJ funded project The Cockpit Citizens Association CCA received a grant from the Environmental Foundation of Jamaica EFJ to do a public education project focusing on the importance of wetlands. This included a series of workshops and field trips to sites in the area, placing appropriate signs as well as an end of project expo. C-CAM staff conducted the workshops and led the field trips and we were also a member of the implementation/project management committee. • 2007-8: Oxfam/ECHO - Post Dean Recovery Project - J$16m This project included conducting surveys in affected communities to determine the needs of persons impacted by the hurricane. Working in collaboration with Oxfam we replaced some five hundred (500) toilets some of which were urine separating toilets, placed communal water tanks in six (6) communities and kept them filled with potable water until the public supply could be restored, provided some residents with rain water harvesting solutions, hired and trained some twenty five (25) community members to assist with data collection and data entry. In addition we hired construction contractors who provided heavy equipment to work along with community members to remove storm created debris from some eleven (11) communities in conjunction with NSWMA & Bouygues Travaux Publics. We also hired and trained twenty (20) community persons to provide proper public health and hygiene practice instruction in schools, churches, business places and house to house in the communities. This project was a jointly managed by C-CAM and Oxfam staff. • 2007-8 on-going: UNDP Global Environment Facility (GEF) small grants – Wetland Sustainable

Management Phase 1 - US$30,000.00

This is an ongoing project in partnership with the Jamalco Bauxite Alumina Company. The objective is to initiate sustainable tourism in the Rocky Point /Salt River area, through wetlands and wildlife management, and assessing the feasibility of a watchable wildlife pond and boat tours. • 2007-8 on-going: NCB Post Dean Recovery - J$10m After Hurricane Dean we were approached by the NCB Foundation and asked to submit a proposal to assist fishers in their recovery process. The first phase included procurement and distribution of mesh wire to fishers on six (6) beaches in the PBPA. Prior to the distributions we relied on our representatives among the fishers to assist with gathering the names of those persons who had suffered damages to their pots as a result of the hurricane. It also included having training workshops focusing on sustainable fisheries. The second phase included developing participatory disaster plans for six (6) communities in the area as well as providing materials and supplies to establish C-CAM as first responders in the area in the event of a disaster. This project also supported the hosting of a Fisheries Symposium during fisherman’s’ week 2008. • 2007-8 on-going: Post card Project – Sterling Asset Management – J$0.8m Sterling Asset Management was encouraged to provide C-CAM with some financial support and they decided to fund the printing of 90,000 post cards with images of the PBPA which could then be sold and the earnings from that be used to produce other similar material or print more cards with different images. The launch of this partnership (publicity) and the earnings are expected to help to jump start C-CAM’s plans for nature and heritage tourism in the area. • 2010 - on-going: PBPA Fish Sanctuaries Management Project – Fisheries Division, Jamaica Government ~ J$7m per year C-CAM has signed an MOU with the Fisheries Division to manage the three Fish Sanctuaries located in the PBPA. The funds will allow C-CAM to hire several Conservation Officers who will conduct extensive public education in the area making persons, especially fishers aware of the new fisheries management regulations. They will also conduct enforcement of the regulations and scientific and socioeconomic monitoring of the sanctuaries. Additional sanctuaries are being considered for the PBPA. • 2010 – on-going: Seacology Foundation Headquarters grant – US$ 30,000. The Seacology foundation provided a grant to C-CAM to assist with the construction of a new field station for the operation of the enforcement and monitoring program for the three new Fish Sanctuaries in the PBPA. The building will be constructed using a modular design using retired steel shipping containers for the main structural component. The building will house a 24hr enforcement presence where Conservation Officers can be deployed to patrol the sanctuaries. CCAM Board 1. Ms. Thera Edwards (consultant): Ms. Edwards is an environmental consultant and chairman of

the C-CAM board 2. Dr. Karl Aiken (fisheries biologist/lecturer): Dr. Aiken is a lecturer the dept. of Life Sciences, UWI. 3. Prof. Aggrey Brown (emeritus): Prof. Brown is the former director at CARIMAC at the UWI. 4. Mr. Merrick Plummer (Investment banker) financial advisor at Pan Caribbean. 5. Mr. Krishna Desai (Lawyer) legal officer Meyers Fletcher.

6. Rev. David Yee-Sing: (shipping analyst) 7. Maxine Whittingham-Osbourne (Marketing and Public relation consultant) 8. Earl Patrick (Executive Director): Tourism Product Development Company CCAM Staff 1. Ingrid Parchment: Executive Director, Financial and Community coordinator. 2. D. Brandon Hay: Scientific Officer, Fish Sanctuary Manager, ecologist. 3. Audrey Fowling: Office Assistant. New Staff

1. Judene Bailey: Education Officer

2. Sharlene Rowe: Education Officer

3. Dujon McKnight: Conservation Officer

4. Boyd Barrett: Conservation Officer

5. Lacey-Ann Thompson: Conservation Officer

6. Dilip Ragoo: Conservation Officer

7. Thyais Thompson: Project Manager Non Staff Affiliate

1. Dr. Ann Sutton (environmental consultant): Partnering consultant

Attachment 14 - National Environment & Planning Agency (NEPA), Permit Roadmap for LNG Project

Environment and Planning Roadmap for LNG Project (31 August 2011)

1

Environmental and Planning Roadmap for the Establishment of a

Liquefied Natural Gas (LNG) Facility in Jamaica

The Liquefied Natural Gas (LNG) Project Technical and Environmental Sub-Committee is one of the sub-committees of the LNG Steering Committee. One of this Committee’s main responsibilities is the development of a Permitting and Licensing Roadmap to help guide the securing of LNG Supply and the development of the infrastructure required for the safe and efficient receiving/storage/regasification of LNG for Jamaica.

This Roadmap seeks to provide relevant environmental and planning technical guidelines pertaining to the Establishment of the LNG Facility in Jamaica including the construction and operation for the Floating Storage and Regasification Terminal (SRT), including floating storage, offshore mooring facilities and onshore gas pipelines, as well as an outline of the permitting and licensing requirement. It sets out preliminary information regarding the preparation of designs and other related aspects of the development that will assist in preparation for project approvals.

Technical Parameters to be Considered

Assuming the location is Port Esquivel, St. Catherine, the following should be noted.

(1) Land Use and Zoning

The Portland Bight has been declared a protected area under the Natural Resources Conservation Authority (1991) Act. Under this act, it is imperative that due diligence is observed in the placing of a mooring station in the area, in order to ensure that minimal short term and long term impacts are not encountered in this venture. The protected area zoning allows for activities as proposed in the area, as long as the environmental characteristics are preserved and protected.

(2) Marine Assessment - Port Esquivel offshore

The marine flora and fauna of the proposed location of the dock as well as the proposed route of the pipeline from the dock to the shore must be assessed. This marine assessment must include but not be limited to:

• Detailed Marine survey of the area expected to be impacted by the dock and the pipeline, including detail flora/fauna assessment


2

• GPS location of the dock as well as the proposed route for pipe laying

• Bathymetry data of the proposed area

• Sediment characteristics of the proposed route for pipe laying

• Details of the Dredge method to be employed for mooring and pipe laying

• Method of disposal of the dredged material and the chemical characteristics of the dredge spoils. If the dredged spoil is not of satisfactory quality, land disposal may be required

• Details of the construction method to be employed for constructing the mooring facilities including the number of pylons to be used, as well as the number of dolphins to be employed

• Size and types of ships expected to be docked

• Details of the method of maintenance of the dock and pylons, as well as maintenance of the pipeline. The maintenance of the pipeline must include the method to be employed for corrosion protection of the pipeline as well as the leak detection system to be employed.

(3) Onshore Pipeline Routing

The proposed pipeline route will be of much importance. The pipeline route will be the subject of much scrutiny considering the novelty of such an infrastructure to the island of Jamaica. The following information will be required to assess the route the pipeline will take:

• GPS mapping and referencing of the proposed pipeline route must be undertaken and submitted.

• Detailed Flora and Fauna assessment of the areas to be impacted by the pipeline route

• Geo-referenced locations of the required governor stations, valve stations and other infrastructures required for the operation and maintenance of the gas delivery network.

• Detailed designs of the pipe laying methodology including method for corrosion protection and leak detection system.


3

• Details of the fire prevention and firefighting systems to be employed.

• If roads will be impacted by the pipeline route, these must be discussed with and approved by the National Works Agency (NWA), including the easement required and the construction and pipe laying methodology to be employed.

• Details on the susceptibility of the selected pipeline routing to damage by earth movement and other natural occurring phenomena, including but not limited to, earthquakes and geological faults.

As mentioned before, the novelty of such a venture may come under much scrutiny from stakeholders in the area of the pipelines, and so a method of public education and awareness may be required. This may be in the form of a public presentation, etc. in order to make the public aware of the project and the risks involved in the operations.

The pipeline route may fall in some protected areas and as mentioned before the necessary due diligence must be taken where applicable.

(4) Waste Management

(a) Waste Streams

The management of all expected waste streams (solid, semi solid, liquid, gaseous) must be submitted in a waste management plan which shall include, but not be limited to the following:

• Expected points of waste generation

• Reuse/recycling of waste streams generated

• Containment and treatment of waste, and

• Method of final disposal of waste.

(b) Sewage Disposal/Treatment

The method of sewage collection, treatment and disposal on and offshore must be outlined. The outline must include but not limited to:

• Engineering report indicating the expected volume of sewage to be generated and the method of containment to be employed, and

• The method of collection, treatment and disposal to be employed.


4

(c) Hazardous Waste Treatment and Disposal

Any hazardous waste generated during the operations of the proposed facility will require an environmental permit for their storage, transportation, treatment and disposal.

Any hazardous waste expected must be described and the method of containment, treatment and disposal must be outlined. Expected volumes of hazardous waste must also be estimated.

(d) Solid Waste Disposal

The type and quantity of waste expected and the method of solid waste disposal should be indicated and this shall be to the satisfaction of the National Solid Waste Management Authority.

(5) Water Supply

Information pertaining to the source and availability of potable water to support the intended development must be provided. A letter from the National Water Commission (NWC) (if they are the source) indicating the ability to provide the required water supply should be submitted as part of the application.

(6) Access & Drainage for onshore operations

With respect to the landward component of the project, ingress and egress to the site and the internal layout of the road network with due consideration to drainage should be designed to the satisfaction of the National Works Agency (NWA). A topographical map, as well as a drainage plan of the area is to be submitted for approval.

The drainage plan should illustrate the following:

a. The effective interception and disposal of storm water and disposal on or off site.

i. The exact location of all existing and proposed hydraulic features and structures.

ii. Detail of all hydraulic features and structures.

b. Detail of final outfall of surface/storm water runoff from the site.


5

c. A hydraulic report including the design notes and calculation summary.

(7) Setbacks

The minimum required setback of any building/structure is as follows:

• The rear and side property boundaries – 1.5m per floor.

• From the centre line of the roadway – not less than 21.0m or otherwise prescribed by the National Works Agency (NWA).

(8) Traffic Impact Assessment

The developer should consult the N W A to ascertain if a Traffic Impact Assessment will be required for the development.

(9) Parking

The parking requirement for industrial buildings used for manufacturing or storage is one parking space for each building up to 1,000 square feet (93m2) and one additional space for each 250 square feet (24m2) of floor area in excess of 5,000square feet (465m2). Also required is one loading/off-loading bay for each building up to 5,000square feet (465m2), plus one additional bay for each 10,000square feet (930m2) of floor area in excess of 5,000 square feet (465m2) to a total of three bays, then one bay for each 50,000 (4650m2) square feet thereafter.

(10) Fire Fighting

A scheme for fire fighting should be prepared to the satisfaction of the Jamaica Fire Brigade. The scheme should include the following.

i. Active protection (such as fire detection systems, sprinkler systems, automatic smoke extraction systems etc.)

ii. Passive protection (the type and nature of construction material used)

iii. Evacuation plan

iv. The means of escape

v. Emergency lighting and warning signs

vi. Dedicated Emergency access ways for the fire fighter


6

(11) Land Ownership

It is a requirement that all applications are accompanied by proof of ownership or a letter of consent from the registered proprietor in the event that the applicant is not the registered owner of the property. The letter should state the following:

• That the owner(s) of the land is aware of the applications at the National Environment and Planning Agency (NEPA) to procure Environmental Permits and Licences for the development on the subject property.

• That “I<name of the owner of the land> consent to the applications being made for the permits/licences for the property to be issued in the name of the Applicant.”

Note that the letter should be signed by the relevant parties and witnessed by a Justice of the Peace and bear their signature and seal.

A letter for permission to use the floor of the sea should be obtained from the Commissioner of Lands.

(12) Statutory Requirement of Other Government Agencies

The requirements of other relevant government Agencies such as Port Authority of Jamaica, Ministry of Health, Water Resources Authority, Mines and Geology Division, National Works Agency, St. Catherine Parish Council, Clarendon Parish Council, Ministry of Agriculture, Fisheries Division, Jamaica Bauxite Institute, Jamaica Fire Brigade and National Water Commission should be incorporated in the overall design.

(13) Consultation

In light of the magnitude and scale of the project, it is advisable that the community (ies) to be impacted is/are sufficiently engaged. In addition, there are a number of other stakeholders who are likely to have varied interest such as prescriptive rights in the specific location and environs namely; Caribbean Coastal Area Management (CCAM), and local fishers.


7

Application Requirements

1. Building and Planning Permission

Port Esquivel, St. Catherine

Any proposed development onshore will be subject to the requirements of the Town and Country Planning Act, 1957, the Town and Country Planning (St. Catherine Coast) Confirmed Development Order, 1964, The Parish Building Act, 1908, Parish Councils Building (St. Catherine) Bylaws, 1952. Consequently, approvals must be sought from the Town and Country Planning Authority and the St. Catherine Parish Council for planning and building permission respectively.

The following information should accompany the application:

1. Two (2) completed copies of the application form, including written details of the proposals.

2. One (1) copy of the subdivision approval, where necessary, showing the location of within the subdivision.

3. One (1) copy of the outline approval, if previously obtained.

4. Six (6) copies of a location plan at a scale of 1:2,500 in urban areas or 1:2,500 for rural areas (scale is linear).

5. Minimum of six (6) copies of the following:

A) A site layout plan at an appropriate scale showing the location of the building(s) on the land together with:

i. Traffic circulation system including ingress/egress

ii. Parking Layout

iii. Size of Land

iv. Planning Information (e.g., habitable rooms, number of units, floor space, ground cover, dimensions and number of parking lots, boundaries of land, setbacks, road reservation and roadway, etc.).

B) Fully detailed drawings illustrating:

a) The external appearance of the building(s)


8

b) Floor Plans

c) Sewage Disposal System

d) Building Lines

e) Drainage

C) Landscaping plans showing the exact location of existing and proposed vegetation. A table with symbols indicating the proposed type (species) of vegetation and quantities should also be included.

D) The following should be submitted with major applications including buildings for use by the public:

a) Parking spaces for the disabled should be clearly demarcated

b) Other facilities such as toilets, grip rails, ramps, etc. for the disabled should be clearly demarcated

c) Method of solid waste disposal

d) Soil test report

2. Environmental Permits and Licenses

The proposed development will be subject to the requirements of the Natural Resources (Prescribed Areas) (Prohibition of Categories of Enterprise, Construction and Development Order, 1997), the Natural Resources Conservation (Permits and Licences) Regulations, 1996 and pursuant to the Natural Resources Conservation Authority Act (1991).

Consequently approvals must be sought for the following permits/licences from the Authority through NEPA under whose jurisdiction the Act currently falls.

Natural Resources Conservation (Permits and Licences) (Amendment) Regulations, 2004, explain whether License or Permit for each of the following is required:

Permits

• Port and Harbour Development (for the receiving station) - J$25,000.00

This application must be accompanied by an Emergency Response and contingency plan for the operation of the regasification/filling station, as well as a Closure Plan.


9

• Pipelines and conveyors, including underground cables, gas lines and other such infrastructure with a diameter or more than 10 cm, for the transport of gas, oil or chemicals - J$25,000.00.

• Petroleum Storage – J$25,000.00

Sizes requiring permits are as follows:

o Underground tanks, 5,000 litres and greater

o Above ground tanks, 4,000 litres or greater

o LPG tanks 3,000 litres and greater

• Concrete Batching Plant (if one will be present onsite) – J$25,000.00

• Hazardous Waste Storage Permit, Transportation, Treatment or Disposal Facility – J$25,000.00

• Land Reclamation and Drainage Projects – J$25,000.00

Licences

Beach Control Act, 1956

Beach license will be required for the use of the foreshore, floor of the sea and water column for:

• Commercial or Industrial Beaches – J$20,000.00

• Pipeline – J$25,000.00 initial and $10,000.00 renewal

• Floating Platform – J$25,000.00 initial, and J$10,000.00 renewal

• Mooring dolphins –

1-5 moorings – J$200.00

6-50 moorings – J$1,000.00;

51-100 moorings - J$5,000.00;

over 100 moorings – J$5,000.00 for every 100 in addition to the first 100

• Pylons – J$5,000.00 per pylon – initial


10

J$5,000.00 per pylon – renewal

• Groynes – J$25,000

• Dredging(capital works) –

for the first 100,000 cubic metres – J$50.00 per cubic metre

for the next 100,000 cubic metres – J$25.00 per cubic metre



for any additional quantity – J$5.00 per cubic metre

• Dredging (maintenance works) –

the first 100,000 cubic metres – J$25.00 per cubic metre

the next 100,000 cubic metres – J$12.50 per cubic metre



any additional quantity – J$2.50 per cubic metre

• Reclamation (Coastline or Wetlands) –

the first 100,000 cubic metres – J$50.00 per cubic metre




any additional quantity – J$5.00 per cubic metre

The Beach license application must be accompanied with all the information specified under the marine assessment.

The relevant applications forms for the permits and licences as well as checklists which are to be to be submitted directly to NEPA are attached. You may also access them at: www.nepa.gov.jm.

http://www.nepa.gov.jm/�


11

NEPA

Applicant submits Application

for Permit /Licence with the

requisite fee to NEPA which

assesses application for

completeness and circulates

to other Agencies e.g. NWA,

WRA, EHU

Applicant submits Application

for Permit /Licence with the

requisite fee to NEPA which

assesses application for

completeness and circulates

to other Agencies e.g. NWA,

WRA, EHU

NEPA screens

application and

conducts site visit

(if necessary)

determines if an

EIA is required.

NEPA screens

application and

conducts site visit

(if necessary)

determines if an

EIA is required.

Application is reviewed by

NEPA’s Internal & Technical

Review Committees.

Application is reviewed by

NEPA’s Internal & Technical

Review Committees.

NEPA modifies Generic ToR to

include any other significant

issues and the need for public

presentation.

NEPA advises applicant that EIA

is required; sends ToR to

applicant and relevant

stakeholders for inclusion of any

other significant issues.

NEPA modifies Generic ToR to

include any other significant

issues and the need for public

presentation.

NEPA advises applicant that EIA

is required; sends ToR to

applicant and relevant

stakeholders for inclusion of any

other significant issues.

Applicant reviews

ToR & indicates to

NEPA whether or

not they have

added any

significant issues to

the ToR.

Applicant reviews

ToR & indicates to

NEPA whether or

not they have

added any

significant issues to

the ToR.

NEPA, relevant

Agencies and

stakeholders review

EIA.

NEPA, relevant

Agencies and

stakeholders review

EIA.

Permit/Licence

Denied by NRCA.

Permit/Licence

Denied by NRCA.

Permit/Licence

Granted by NRCA

Permit/Licence

Granted by NRCA

Optional Appeal

to Minister.

Optional Appeal

to Minister.

NEPA informs

applicant of

adequacy of EIA

NEPA informs

applicant of

adequacy of EIA

Based on approved

ToR, applicant

prepares & submits

EIA report (12 hard

copies + digital copy)

and publishes second

public notice.

Based on approved

ToR, applicant

prepares & submits

EIA report (12 hard



public notice.

Applicant defines project and may seek conference

with NEPA

Applicant defines project and may seek conference

with NEPA

Permitee/Licencee

implements project

according to terms &

conditions of approval.

Permitee/Licencee

implements project

according to terms &

conditions of approval.

• NEPA – National Environment & Planning Agency

EIA - Environmental Impact Assessment

• ToR - Terms of Reference

• NRCA - Natural Resources Conservation Authority

• NEPA – National Environment & Planning Agency

EIA - Environmental Impact Assessment

• ToR - Terms of Reference

• NRCA - Natural Resources Conservation Authority

National Environment and Planning Agency (NEPA) October 2010

Technical Review

Committee’s

recommendations are

presented to NRCA.

Technical Review

Committee’s

recommendations are

presented to NRCA.

NEPA returns

incomplete application

to applicant.

NEPA returns


to applicant.

IF NO EIA IS REQUIRED

NEPA advises

applicant:

• of stakeholders

comments, if any

• to proceed with the

EIA study

• to publish first

standard public

notice.

NEPA advises

applicant:

• of stakeholders

comments, if any


EIA study


standard public

notice.

IF NOT ADEQUATE

Applicant Appeals

condition (s)

Applicant

Appeals

Decision

NEPA’s Environmental Permit & Licence

Applications Process

NEPANEPA’’ss Environmental Environmental Permit & Licence Permit & Licence

Applications ProcessApplications Process

LEGEND

Applicant

pays

Permit/

Licence

Fee

Applicant

pays

Permit/

Licence

FeeNEPA monitors

Compliance.

NEPA monitors

Compliance.


12

Applicant submits Beach Licence Application

with the requisite fee to NEPA, posts Form B Notice and informs immediate neighbours via

registered mail of his/her proposed project.

NEPA assesses application for completeness.

Applicant submits Beach Licence Application

with the requisite fee to NEPA, posts Form B Notice and informs immediate neighbours via

registered mail of his/her proposed project.

NEPA assesses application for completeness.

NEPA screens

application and

conducts site visit,

verify posting of the

notice and

determines if an

EIA is required.

NEPA screens

application and

conducts site visit,

verify posting of the

notice and

determines if an

EIA is required.

Application is

reviewed by NEPA’s

Internal & Technical

Review Committees.

Application is

reviewed by NEPA’s

Internal & Technical

Review Committees.

NEPA modifies Generic

ToR to include any other

significant issues and the

need for public

presentation.

NEPA advises applicant

that EIA is required; sends

ToR to applicant and

relevant stakeholders for

inclusion of any other

significant issues.

NEPA modifies Generic

ToR to include any other

significant issues and the

need for public

presentation.

NEPA advises applicant

that EIA is required; sends

ToR to applicant and

relevant stakeholders for

inclusion of any other

significant issues.

Applicant reviews

ToR & indicates to

NEPA whether or

not they have

added any

significant issues

to the ToR.

Applicant reviews

ToR & indicates to

NEPA whether or

not they have

added any

significant issues

to the ToR.

NEPA, relevant

Agencies and

stakeholders

review EIA.

NEPA, relevant

Agencies and

stakeholders

review EIA.

Licence Denied

by NRCA.

Licence Denied

by NRCA.

Licence

Granted by

NRCA.

Licence

Granted by

NRCA.

Optional Appeal

to Minister.

Optional Appeal

to Minister.

NEPA informs

applicant of

adequacy of EIA

NEPA informs

applicant of

adequacy of EIA

Based on approved

ToR, applicant

prepares & submits

EIA report ( 12 hard



public notice.

Based on approved

ToR, applicant

prepares & submits

EIA report ( 12 hard



public notice.

Applicant defines

project and may

seek conference

with NEPA

Applicant defines

project and may

seek conference

with NEPA

Applicant signs

Deed of

Indemnity and

pays Licence

Fee.

Applicant signs

Deed of

Indemnity and

pays Licence

Fee.

National Environment and Planning Agency (NEPA) October 2010

NEPA

monitors

Compliance.

NEPA

monitors

Compliance.

Technical Review

Committee’s

recommendations are

presented to NRCA’s

Board.

Technical Review

Committee’s

recommendations are

presented to NRCA’s

Board.

NEPA returns


to applicant.

NEPA returns


to applicant.

IF NO EIA IS REQUIRED

NEPA advises

applicant:

• of stakeholders

comments, if any


EIA study


standard public

notice.

NEPA advises

applicant:

• of stakeholders

comments, if any


EIA study


standard public

notice.

IF NOT ADEQUATE

Applicant

Appeals

condition/s

Applicant

Appeals

Decision

NEPA’s Beach Licence Application Process

NEPANEPA’’ss Beach Licence Beach Licence Application ProcessApplication Process

•NEPA - National Environment & Planning Agency

•EIA - Environmental Impact Assessment

•ToR - Terms of Reference

•NRCA - Natural Resources Conservation Authority

•NEPA - National Environment & Planning Agency

•EIA - Environmental Impact Assessment

•ToR - Terms of Reference

•NRCA - Natural Resources Conservation Authority

LEGEND

Licensee

implements

project

according to

terms &

conditions of

approval

Licensee

implements

project

according to

terms &

conditions of

approval


13