dnvgl-si-0166 verification for compliance with norwegian...

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DNV GL AS

STATUTORY INTERPRETATIONS

DNVGL-SI-0166 Edition July 2018

Verification for compliance with Norwegianshelf regulations

FOREWORD

DNV GL statutory interpretations contain the Society's own interpretations of statutoryregulations. These are valid when not instructed otherwise by the flag or coastal stateadministration, and when no interpretations exist from IACS or regulatory bodies. The publicationcovers only selected relevant topics and shall under no circumstances be taken as the Society'scomplete interpretations of such regulations.

© DNV GL AS July 2018

Any comments may be sent by e-mail to [email protected]

If any person suffers loss or damage which is proved to have been caused by any negligent act or omission of DNV GL, then DNV GL shallpay compensation to such person for his proved direct loss or damage. However, the compensation shall not exceed an amount equal to tentimes the fee charged for the service in question, provided that the maximum compensation shall never exceed USD 2 million.

In this provision "DNV GL" shall mean DNV GL AS, its direct and indirect owners as well as all its affiliates, subsidiaries, directors, officers,employees, agents and any other acting on behalf of DNV GL.

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Statutory interpretations, DNVGL-SI-0166. Edition July 2018 Verification for compliance with Norwegian shelf regulations

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CHANGES – CURRENT

This document supersedes the July 2017 edition of DNVGL-SI-0166.Changes in this document are highlighted in red colour. However, if the changes involve a whole chapter,section or subsection, normally only the title will be in red colour.

Changes July 2018, entering into force 1 January 2019Topic Reference Description

Ch.1 Sec.1 Table 3Ch.1 Sec.1 Table 4Ch.1 Sec.1 Table 5

References updated.

Ch.2 Sec.2 [2.2.3]Ch.2 Sec.2Ch.2 Sec.2 [2.2.4]

Ch.2 Sec.2 [2.2.5]Ch.2 Sec.2 [2.2.6]

Guidance notes and clarifications added to the PSA additionaltechnical requirements.

Ch.2 Sec.2 [2.3.1] A new limitation has been added listing the sections of the PSAFacilities Regulations which are not included in the notation.The limitations regarding drilling plant, cranes and liftingappliances have been moved to Ch.2 Sec.2 Table 1 footnote.

Ch.2 Sec.2 Table 1Ch.2 Sec.3 Table 1Ch.2 Sec.4 Table 1Ch.2 Sec.5 Table 1Ch.2 Sec.6 Table 1Ch.2 Sec.7 Table 1Ch.2 Sec.8 Table 1Ch.2 Sec.9 Table 1

The SFI numbers have been removed from the table andfootnotes. The table has been completely restructuredaccording to the section numbering of the PSA FacilitiesRegulations. The verification references and notes/commentscolumns have been updated based upon the current PSAFacilities Regulations including Guidelines and the AoCHandbook Rev.5.

Ch.2 Sec.3 [2.2.3]Ch.2 Sec.3 [2.2.4]Ch.2 Sec.3 [2.2.5]Ch.2 Sec.2 [2.2.6]Ch.2 Sec.2 [2.3.7]Ch.2 Sec.4 [2.2.3]Ch.2 Sec.4 [2.2.4]Ch.2 Sec.4 [2.2.5]Ch.2 Sec.4 [2.3.6]Ch.2 Sec.6 [2.2.3]Ch.2 Sec.6 [2.2.4]Ch.2 Sec.6 [2.2.5]Ch.2 Sec.6 [2.2.6]

Guidance notes and clarifications added to the PSA additionaltechnical requirements.

Update of DNVGL-SI-0166containing the offshore (N)-notation

Ch.2 Sec.3 [2.4.1] A new limitation has been added listing the sections of the PSAFacilities Regulations which are not included in the notation.The limitations regarding production plant, cranes and liftingappliances have been revised and moved to Ch.2 Sec.3 Table 1footnote.

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Topic Reference Description

Ch.2 Sec.4 [2.4.1] A new limitation has been added listing the sections of the PSAFacilities Regulations which are not included in the notation.The limitation regarding cranes and lifting appliances has beenrevised and moved to Ch.2 Sec.4 Table 1 footnote.

Ch.2 Sec.5 [2.2.2] Clarifications added and deletion of non-applicable subsections.



Ch.1 Sec.2 [2.2.3] andCh.2 Sec.7 [1]

Added new notation Modular drilling system(N).

Ch.1 Sec.2 [2.2.3] andCh.2 Sec.9 [1]

Added new notation Modular well system(N).

Ch.2 Sec.10 [2.3] Limitations added.

Ch.3 Sec.1 [1] References to fleet in service rules updated.

Ch.3 Sec.2 References to fleet in service rules updated. New subsectionCh.3 Sec.2 [3] added to align with Ch.2 and DNVGL-RU-OU-0300.

Editorial corrections

In addition to the above stated changes, editorial corrections may have been made.

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CONTENTS

Changes – current............................................................3

Chapter 1 Principles and procedures................................ 8Section 1 Introduction.........................................................................................................8

1 General.................................................................................................................8

2 Definitions............................................................................................................9

3 References......................................................................................................... 11

4 Abbreviations..................................................................................................... 14

Section 2 Verification principles and class notations.........................................................16

1 Verification principles........................................................................................ 16

2 Class notations...................................................................................................18

3 Classification principles, procedure and legal provisions................................... 18

Chapter 2 Design and construction provisions................ 20Section 1 Introduction....................................................................................................... 20

1 General...............................................................................................................20

Section 2 Drilling unit(N).................................................................................................21

1 Introduction....................................................................................................... 21

2 Technical requirements......................................................................................21

3 Procedures for verification.................................................................................27

Section 3 Oil production(Unit)(N) or Oil production(Installation)(N)...............................28

1 Introduction....................................................................................................... 28



Section 4 Oil storage(Unit)(N) or Oil storage(Installation)(N)........................................ 37

1 Introduction....................................................................................................... 37



Section 5 Well intervention unit(N)................................................................................. 45

1 Introduction....................................................................................................... 45



Section 6 Accommodation unit(N)................................................................................... 51

1 Introduction....................................................................................................... 51



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Section 7 Drill(N)............................................................................................................. 58

1 Introduction....................................................................................................... 58

2 PSA Compliance................................................................................................. 58

3 Additional design requirements......................................................................... 60

4 Additional manufacturing and installation requirements....................................65


Section 8 PROD(N)...........................................................................................................69

1 Introduction....................................................................................................... 69



Section 9 WELL(N)........................................................................................................... 72

1 Introduction....................................................................................................... 72

2 PSA Compliance................................................................................................. 72

3 Additional design requirements......................................................................... 75

4 Additional manufacturing and installation requirements....................................75


Section 10 HELDK(S, H, N)/HELDK(S, H, F, N).................................................................76

1 Introduction....................................................................................................... 76


Section 11 Crane-offshore(N)............................................................................................77

1 Introduction....................................................................................................... 77


3 Design verification and certification of materials and components.................... 80

4 Survey during construction, installation and commissioning..............................81

Section 12 COMF-MOU(N)..................................................................................................82

1 Introduction....................................................................................................... 82


Chapter 3 Classification in operation.............................. 83Section 1 General provisions for periodical surveys.......................................................... 83

1 General...............................................................................................................83

2 Class renewal for (N)-notation.......................................................................... 83

Section 2 Periodic survey extent for (N)-notations........................................................... 84

1 Drilling unit(N).................................................................................................84

2 Oil production(Unit)(N) or Oil production(Installation)(N)...............................84

3 Oil storage(Unit)(N) or Oil storage(Installation)(N).........................................84

4 Well intervention unit(N)................................................................................. 84

5 Accommodation unit(N)................................................................................... 84

6 DRILL(N).......................................................................................................... 85

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7 PROD(N)...........................................................................................................85

8 WELL(N)........................................................................................................... 85

9 Crane-offshore(N).............................................................................................. 86

10 COMF-MOU(N)................................................................................................ 87

Appendix A Special considerations for ageing offshoreunits (informative)...................................................... 88

1 General..................................................................................................88

Appendix B DNV GL enterprise of competence (EOC) forlifting equipment......................................................... 90

1 General..................................................................................................902 Supplementary survey for enterprise of competence............................ 903 Execution by DNV GL............................................................................ 904 Control of lifting equipment performed by enterprise of competence.... 90

Changes - Historic.......................................................... 93

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CHAPTER 1 PRINCIPLES AND PROCEDURES

SECTION 1 INTRODUCTION

1 General

1.1 IntroductionDNV GL offshore classification aims to assure safety and reliability of offshore units and installations withregard to design, construction and operation. Wherever possible DNV GL offers additional, integrated servicesto assist clients towards fulfilling coastal state legislation, giving credit for classification activities.

1.2 ObjectiveThis publication, presents standardised DNV GL verification services building on class, which may be used todocument partial compliance with verification obligations related to operation on the Norwegian continentalshelf (NCS).

1.3 ScopeThis document is divided into three main chapters:

— This chapter: General information about classification services related to operation on the Norwegiancontinental shelf (NCS)

— Ch.2: Design and construction requirements for the newbuilding phase— Ch.3: Requirements for maintenance of NCS related class notations in the operational phase.

1.4 ApplicationThis document covers NCS related class services for offshore objects of the following types:

— drilling units— production units— storage units— well intervention units— accommodation units

and the following types of installed facilities:

— drilling plants— production plants— well Intervention plants— helicopter decks— cranes.

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2 Definitions

2.1 Verbal forms

Table 1 Verbal forms

Term Definition

shall verbal form used to indicate requirements strictly to be followed in order to conform to the document

shouldverbal form used to indicate that among several possibilities one is recommended as particularly suitable,without mentioning or excluding others, or that a certain course of action is preferred but not necessarilyrequired

may verbal form used to indicate a course of action permissible within the limits of the document.

2.2 Definitions

Table 2 Definitions (continued)

Term Definition

acknowledgement ofcompliance (AOC)

a statement from the Petroleum Safety Authority Norway (PSA) that expresses theauthorities' confidence that petroleum activities can be carried out using the facility withinthe framework of the regulations

Guidance note:

The decision is based on information provided in the AOC application relating to the facility'stechnical condition and the applicant's organisation and management system, as well as theauthorities' verifications and other processing. The party that will handle the daily operation ofsuch a facility, shall have an AOC when such a facility participates in petroleum activities subjectto Norwegian shelf jurisdiction. (See guidelines to Sec.25 of PSA Framework regulations).

---e-n-d---o-f---g-u-i-d-a-n-c-e---n-o-t-e---

approval or approved denotes acceptance by DNV GL of documentation showing design solutions, arrangementsand/or equipment to comply with the rules.

assigning class

originally signified designation of one of several classes to a ship based on its condition,ranging from good to badToday only the highest class is assigned, comprising the main class, 1A, and an obligatoryadditional class notation, e.g. Drilling unit, where applicable.

Optional additional class notations may also be assigned covering special service, equipmentor systems, e.g. DRILL denoting a classed drilling plant.

CE-mark CE denotes Communauté Européenne and confirms that equipment complies relevantEuropean Union Directives

classificationcomprises those services rendered by DNV GL in accordance with the rulesClassification of offshore units is conducted in accordance with the requirements of the rulesand any standards referred to by the rules.

classification certificateissued upon assignment or renewal of classIts validity is five years subject to successful completion of annual and intermediate surveys.

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Term Definition

client

the party having requested classification or having assumed ownership of a classed offshoreunit or installationIn cases where owners have authorised another party to operate the unit or installation ontheir behalf, such party is regarded as the client.

contract

the specific agreement between DNV GL and the clientIt defines the extent of services requested by the client, and is concerned with:

— the classification of offshore units or installations, both newbuildings and in operation— statutory work carried out on behalf of national maritime authorities— equipment and materials.

DNV GL

DNV GL undertakes classification and certification and ensures the quality of ships, offshoreunits and installations, facilities and systems, and carries out research in connection withthese functionsDNV GL operates a world wide network of survey stations and is authorised by more than120 national administrations to carry out surveys and, in most cases, issue certificates ontheir behalf.

guidance noteadvice which is not mandatory for assignment of class, but with which DNV GL, in light ofgeneral experience, advises complianceThe client may decide whether to apply the guidance note or not.

mobile offshore unit(MOU)

a buoyant construction engaged in offshore operations including drilling, production, storageor support functions, not intended for service at one particular offshore site and which canbe relocated without major dismantling or modification

notified bodyindependent organisations appointed by EEA national authorities to undertake conformityassessment before a product is CE-marked according to a EU directiveDNV GL is notified body for many EU directives

offshore installation a collective term to cover any construction, buoyant or non-buoyant, designed and built forinstallation at a particular offshore location

owner in the context of this service specification, the owner is defined as the party responsible forthe offshore unit or installation including its operation and safety

recognised classificationsociety a classification society which is a full or associate member of IACS

statutory certificates IMO convention certificates issued on behalf of, or by, national authorities

supplier or manufacturersupplies materials, components, equipment and systems to newbuildings to be classed, orto classed units in operation, whose production is subject to design approval, surveys andtesting in accordance with the rules

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3 References

3.1 Normative references

3.1.1 This service specification includes references to other DNV GL documents and regulations, codes andstandards which shall be used in conjunction with the requirements given herein, for assignment of (N)-notation.Latest issue of the references shall be used unless otherwise agreed.

3.1.2 DNV GL documents referred to are given in Table 3 and Table 4.

Table 3 DNV GL rules for classification: Offshore units

Document code Title

DNVGL-RU-OU-0101 Offshore drilling and support units

DNVGL-RU-OU-0102 Floating production, storage and loading units

DNVGL-RU-OU-0294 Modular systems for drilling and well

DNVGL-RU-OU-0300 Fleet in service

Table 4 Normative DNV GL references

Document code Title

DNVGL-OS-A101 Safety principles and arrangements

DNVGL-OS-A201 Winterization for cold climate operations

DNVGL-OS-A301 Human comfort

DNVGL-OS-D201 Electrical installations

DNVGL-OS-E101 Drilling plant

DNVGL-OS-E201 Oil and gas processing systems

DNVGL-OS-E401 Helicopter decks

3.1.3 Non-DNV GL standards and other verification references as referred to herein are given in Table 5.Only parts referred to in Ch.2 are applicable for the verification activity. Latest edition of Petroleum SafetyAuthority Norway (PSA) and Norwegian Maritime Authority (NMA) regulations shall be used unless otherwiseagreed. Below are the valid NMA regulations at time of printing listed.

Table 5 Other references

Document code Title

API Spec 8C Drilling and Production Hoisting Equipment

API Standard 520 Sizing, Selection, and Installation of Pressure-relieving Devices

API Standard 521 Pressure-relieving and Depressuring Systems

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Document code Title

DSB No. 1450 of 2001-12-04 DSB regulations relating to maritime electrical installations

EEMUA Publication 191 Alarm systems - a guide to design, management and procurement

EN 280 Mobile elevating work platforms

EN 1127-1 Explosion prevention and protection - Part 1

EN ISO 4126 series Safety devices for protection against excessive pressure

EN 12644 Cranes – Information for use and testing

EN 13135 Cranes-Safety- Design-Requirements for equipment

EN 13586 Cranes - Access

EN ISO 13849-1 Safety of machinery – Safety-related parts of control systems Part 1

EN 13852-1 Cranes – Offshore cranes- Part 1

EN 62682 Management of alarms system for the process industries

IEC 60092 Electrical installations in ships

IEC 60204-32 Safety of machinery - Electrical equipment of machines -- Part 32

IEC 61508 series Functional safety of electrical/electronic/programmable electronic safety-relatedsystems

IEC 61892 series Fixed and mobile offshore units - Electrical Installations

IMO Resolution A.754 (18) Recommendation on fire resistance tests for ", "B" and "F" class divisions

ISO 834

ISO 3008 Fire-Resistance Tests

ISO 3009 Fire-Resistance Tests - Elements of building construction - Glazed Elements

ISO 9001 Quality management systems - Requirements

ISO 12100 Safety of machinery - General principles for design - Risk assessment and riskreduction

ISO 10418 Petroleum and natural gas industries - Offshore production installations - Basicsurface process safety systems

ISO 12482 Cranes - Monitoring for crane design working period

ISO 13702 Petroleum and natural gas industries. Control and mitigation of fires and explosionson offshore production installations. Requirements and guidelines

ISO 14121-2 Safety of machinery - Risk assessment - Part 2: Practical guidance and examples ofmethods

ISO 15138 Petroleum and natural gas industries - Offshore production installations - Heating,ventilation and air-conditioning

ISO 22899-1 Determination of the resistance to jet fires of passive fire protection materials - Part 1

NMA No. 67 of 2016-01-27 Regulations on ballast systems on mobile offshore units (Ballast Regulations)

NMA No. 72 of 2008-01-15 Regulations concerning helicopter decks on mobile offshore units

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Document code Title

NMA No. 90 of 2016-02-02 Regulations concerning evacuation and lifesaving appliances on mobile offshore units

NMA No. 123 of 1994-02-10 Regulations for mobile offshore units with production plants and equipment

NMA No. 227 of 1984-01-31 Regulations concerning precautionary measures against fire and explosion on mobileoffshore units

NMA No. 480 of 2003-11-04 Regulations concerning welding equipment, etc. for the welding gases acetylene andoxygen in mobile offshore units

NMA No. 488 of 2012-02-30 Regulations on environmental safety for ships and mobile offshore units

NMA No. 856 of 1987-09-04 Regulations concerning construction of mobile offshore units

NMA No. 859 of 1987-09-04 Regulations concerning protective, environmental, and safety measures on mobileoffshore units

NMA No. 878 of 1991-12-20 Regulations concerning stability, watertight subdivision and watertight/weathertightclosing means on mobile offshore units

NMA No. 955 of 2014-07-01 Regulations on radio communication equipment for Norwegian ships and mobileoffshore units

NMA No. 998 of 2009-07-10 Regulations concerning positioning and anchoring systems on mobile offshore units(Anchoring Regulations 09)

NMA No. 1239 of 1993-12-22 Regulations concerning risk analyses for mobile offshore units

NMA No. 1406 of 2015-12-04 Regulations on potable water and potable water systems on mobile offshore units

NMA No. 2318 of 1986-12-17 Regulations concerning the construction and equipment of living quarters on mobileoffshore units

NOROG/ NSA Handbook for Acknowledgement of Compliance (AoC)

NOG Guideline 070 070 - Norwegian Oil and Gas' Guidelines for the application of IEC 61508 and IEC61511 in the Norwegian petroleum industry

NORSOK C-001 Living quarters area

NORSOK C-002 Architectural components and equipment

NORSOK D-001 Drilling facilities

NORSOK D-002 Well intervention equipment

NORSOK H-003 Heating, ventilation and air conditioning (HVAC) and sanitary systems

NORSOK L-001 Piping and valves

NORSOK L-002 Piping system layout, design and structural analysis

NORSOK M-001 Materials selection

NORSOK M-101 Structural steel fabrication

NORSOK M-601 Welding and inspection of piping

NORSOK N-001 Integrity of offshore structures revision

NORSOK N-003 Actions and action effects

NORSOK N-004 Design of steel structures

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Document code Title

NORSOK P-002 Process system design

NORSOK R-001 Mechanical Equipment

NORSOK R-002 Lifting equipment

NORSOK R-003 Safe use of lifting equipment

NORSOK R-004 Piping and equipment insulation

NORSOK S-001 Technical safety

NORSOK Z-013 Risk and emergency preparedness assessment

NORSOK Z-DP-002 Coding System

NS 6033 Sea engineering - Signs - with fixed text

NT Fire 021 Insulation of Steel Structures: Fire protection

PSA – Activities Regulations relating to conduct of activities in the petroleum activities (the ActivitiesRegulations)

PSA – Facilities Regulations relating to design and outfitting of facilities etc. in the petroleumactivities (the Facilities Regulations), including guidelines and interpretations

PSA – Framework HSE Regulations relating to health, safety and the environment in the petroleum activitiesand at certain onshore facilities (the Framework Regulations)

PSA – Management Regulations relating to Management and the duty to provide information in thePetroleum Activities and at certain onshore land facilities

4 AbbreviationsThe abbreviations given in Table 6 are used in this document.

Table 6 Abbreviations

Abbreviation Title

AOC acknowledgement of compliance

DSB Norwegian Directorate for Civil Protection

EEA European Economic Area

EoC enterprise of competence (sakkyndig virksomhet)

EOS Emergency operating system

EU European Union

FPSO floating production and storage unit

FSO floating storage unit

IACS International Association of Classification Societies

IMO International Maritime Organisation

NEA Norwegian Environment Agency (previously KLIF and SFT)

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Abbreviation Title

MOU mobile offshore unit

NBH Norwegian Board of Health

NCS Norwegian continental shelf

NMA Norwegian Maritime Authority

NOROG Norwegian Oil and Gas Association (previously OLF)

NSA (NR) Norwegian Shipowners' Association (Norges Rederiforbund)

OEM original equipment manufacturer

PSA (PTIL) Petroleum Safety Authority (Petroleumstilsynet)

RBI risk based inspection

SDLA spesial design lifting accessories

SFI Norwegian Ship Technical Research Institute

SIL safety integrity level

SOC statement of compliance

WLL working load limit

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SECTION 2 VERIFICATION PRINCIPLES AND CLASS NOTATIONS

1 Verification principles

1.1 General

1.1.1 According to the Norwegian Petroleum Act, the owner is fully responsible for verification activitiesensuring that the unit/installation and related operations are in compliance with the applicable regulatoryrequirements.

1.1.2 The owner may utilise internal as well as external verification activities to demonstrate partial or fullcompliance with his verification obligations. Documentation may include:

— maritime certificates issued by flag state administrations and associated rules and regulations to which thecertificates are issued

— classification certificates— work performed by consultants/technical specialists for the owner/operator resulting typically in

verification reports or statements of compliance (SOCs).

1.1.3 The (N)-notation is issued based on statutory reference regulations and standards valid at the date ofcontract between Yard and Owner.

Guidance note:

Offshore units will normally be required to document compliance with the latest edition of the PSA regulations and associatedreference regulations and standards when applying for AOC from the Norwegian PSA.


1.2 Regulatory basisThe regulatory body on the NCS is the Petroleum Safety Authority (PSA). Requirements for petroleumactivities on the NCS are stipulated by PSA together with Norwegian Environment Agency (NEA) and TheNorwegian Board of Health (NBH). The services described in this document are interpreted from or containreference to the PSA/NEA/NBH joint regulations given in Table 1.

Table 1 PSA Regulations referred to and used under this service specification

Formal regulation title Abbreviation

Regulations relating to Health, Safety and the Environment in the PetroleumActivities and at certain onshore facilities The Framework Regulations

Regulations relating to Management and the duty to provide information in thePetroleum Activities and at certain onshore land facilities The Management Regulations

Regulations relating to Design and Outfitting of Facilities etc. in the PetroleumActivities The Facilities Regulations

Regulations relating to Conducting of Petroleum Activities The Activities Regulations

Guidance note:

The latest revision of the applicable standards may be found at http://www.psa.no


http://www.psa.no

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1.3 Regulatory considerations for floating units

1.3.1 PSA regulations make a distinction between mobile facilities and other offshore installations withrespect to the verification basis which may be applied, (see Sec.3 of PSA Framework Regulations).

1.3.2 Mobile facilities are in this context understood as units registered in a national register of shipping, andwhich follow a maritime operational concept.Typical examples of such units are:

— drilling units— well intervention units— accommodation units— multi-purpose units— production and/or storage units following a maritime operational concept.

Guidance note:

In some cases it may be a matter of judgement if the object can be categorised as a maritime practice offshore unit according toPSA regulations. It is recommended that the PSA is contacted at an early stage in such projects for principal clarifications.


1.4 Acknowledgement of compliance and verification basis

1.4.1 PSA operates approval compliance scheme for mobile facilities named acknowledgement of compliance(AOC). The AOC scheme is mandatory for all types of mobile facilities except floating storage units (FSO).

1.4.2 DNV GL services described in this document may be used by owners to document partial compliancewith PSA requirements for an AOC application.

1.4.3 Details on the AOC scheme are given in Handbook for Application for Acknowledgement of Compliance(AOC), issued by Norwegian Oil and Gas Association (NOROG), and Norwegian Shipowners' Association(NSA).

Guidance note:

The latest revision of the handbook may be found at http://www.norskoljeoggass.no


1.4.4 The maritime regulations and corresponding class rules that may be applied are to have a safety levelminimum corresponding to the latest edition of the NMA Regulations for Mobile offshore units (NMA redbook)and supplementary DNV GL rules for classification: Offshore units (RU-OU).

1.4.5 Petroleum related aspects (e.g. drilling and production plants) shall comply directly with the provisionsof the PSA Facilities Regulations, as shall working environment issues.

1.4.6 The approach described in [1.4] has been used as basis for the services described in this document.

http://www.norskoljeoggass.no

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2 Class notations

2.1 GeneralCh.2 and Ch.3 of this document describe DNV GL services building on standard class notations which can beused to document partial compliance with verification obligations of the owner as described in [1].

Guidance note:

DNV GL’s results and conclusions related to services described in this document are based on DNV GL’s understanding andinterpretation of the PSA’s regulations, but do not represent any formal approval on behalf of PSA.

Formal compliance with PSA requirements can only be confirmed by the PSA itself. No other authorities or organisations havedelegated authority to act on behalf of PSA.


2.2 Class notations

2.2.1 Classed units/installations complying with the additional requirements of the relevant sections of thisdocument will, after completion of prescribed design verifications and surveys, be assigned the notation (N).

2.2.2 Verification basis applied for the (N)-notation will be stated in the appendix to class certificate.

2.2.3 The following (N)-notations are currently available:

— Drilling unit(N)— Oil production(Unit)(N) or Oil production(Installation)(N)— Oil storage(Unit)(N) or Oil storage(Installation)(N)— Well intervention unit(N)— Accommodation unit(N)— DRILL(N)— PROD(N)— WELL(N)— HELDK(S, H, N)/HELDK(S, H, F, N)— Crane-offshore(N)— COMF-MOU(N)— Modular drilling system(N)— Modular well system(N).

3 Classification principles, procedure and legal provisions

3.1 General

3.1.1 The (N)-notations will be issued and maintained based on the following main activities:

— design verification— certification of materials and components— survey during construction and installation— survey during commissioning and start-up— periodical survey during operation.

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3.1.2 General principles, procedures and legal provisions for classification applicable for this document arestated in Chapter 1 of the following DNV GL rules for classification: Offshore units:

— Rules for drilling and support units for Drilling unit(N), Well intervention unit(N), Accommodationunit(N), DRILL(N), WELL(N) and HELDK(S, H, F, N)/HELDK(S, H, N), (see DNVGL-RU-OU-0101).

— Rules for floating production, storage and loading units for Oil production(Unit)(N) or Oilproduction(Installation)(N), Oil storage(Unit)(N) or Oil storage(Installation)(N) and PROD(N),(see DNVGL-RU-OU-0102).

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CHAPTER 2 DESIGN AND CONSTRUCTION PROVISIONS

SECTION 1 INTRODUCTION

1 General

1.1 General

1.1.1 Unless otherwise stated the design and construction requirements given in this chapter aresupplementary to the latest edition of relevant DNV GL class requirements. For units built to earlier editionsof DNV GL rules for classification or to class rules from another IACS Society, an additional verification ofcompliance with the DNV GL rules for classification in force at the time when the (N)-notation is sought, shallbe carried out in addition to the verification activities described in this chapter, (see Ch.1 Sec.2 [1.1.3]).

1.1.2 Activities related to issuing the (N)-notation shall normally be carried out as an integral part of theactivities related to the corresponding class notations to which the (N) symbol will be attached.

1.1.3 Unless otherwise stated class procedures, documentation requirements, extent of certification ofmaterials and components, extent of surveys etc. shall as a minimum be as required for the correspondingclass notations to which the (N) symbol will be attached. Generally the documentation requirements andextent of survey will be based on the additional verification basis as listed herein.

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SECTION 2 DRILLING UNIT(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to mobile offshore drilling unitssatisfying the following criteria:

— The unit is being classed with DNV GL with minimum service notation Drilling unit and enhanced systemnotation, ES.

— The unit is registered with a national maritime administration.

1.2 Class notationsClassed units/installations complying with the relevant requirements of this section may, after completion ofdesign reviews and surveys be assigned the class notation Drilling unit(N).

2 Technical requirements

2.1 Supplementary verification basis for Drilling unit(N)The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation.

Table 1 Verification basis for Drilling unit(N)

PSAFacilities

Regulationreference

Area Verificationbasis

Verification references foradditional requirements Notes/comments

Section 5 Design offacilities Maritime

NMA Construction

NMA Living Quarter

NMA Fire

Section 7 Main safetyfunctions Maritime

NMA Construction

NMA Living Quarter

NMA Fire

Section 8 Safetyfunctions Maritime

NMA Ballast

NMA Stability

NMA Fire

NMA Risk analysis, Sec. 22

Section 10Installations,systems andequipment

Maritime

NMA Construction*

NMA Anchoring*

NMA Ballast*

NMA Stability*

NMA Welding equipment

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tion

2


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PSAFacilities

Regulationreference



Section 10a Ignition sourcecontrol* Maritime

NMA Fire Sec. 24-26

DNVGL-OS-D201

Ignition source control mappingto comply with PSA FacilitiesRegulation 10a.

Refer to acknowledgement fromPSA stating acceptance of use ofDNVGL-OS-D201 in lieu of NMAregarding electrical installations.

Section 11

Loads/actions,load/actioneffects andresistance

Maritime

NMA Construction, Sec. 6, Sec. 7and Sec. 10, implications of

NMA Stability, Sec. 22 and Sec. 30

NMA Fire Sec. 4*

DNVGL-OTG-13, DNVGL-OTG-14*

DNVGL-OTG-13, DNVGL-OTG-14applicable for semi-submersibleunits. Refer to PSA circular dated30.09.2016.

Section 12 Materials Maritime See note

Covered by class with addition ofrequirement from PSA regardingimpact toughness properties forspecial and primary steel, see Sec.2.2.2.

Section 13

Materialshandling andtransportroutes, accessand evacuationroutes

Maritime

NMA Construction

NMA Living Quarter

NMA Fire

Verification scope is limited torequirements relating to escaperoutes.

Section 14 Ventilation andindoor climate Maritime

NMA Fire

NMA Living Quarters Sec. 9.1*

Verification scope is limited torequirements relating to fire andexplosion protection.

Section 18

Systemsfor internaland externalcommunication*

Maritime

NMA Fire, Sec. 22, 23, 25

NMA Radio equipment

NMA Anchoring, Sec. 12

Except for universal audio andvisual alarms which shall followNORSOK S-001 Chapter 17.4.2.

Section 19 Communicationsequipment Maritime

NMA Radio equipment

NMA Lifesaving appliances sec. 16,28*

Section 28 Safety signs Maritime NMA Protective, environmental

Section 29 Passive fireprotection* Maritime

NMA Living quarter, Sec. 6

NMA Fire

Section 30 Fire divisions* MaritimeNMA Living quarter, Sec. 6

NMA Fire

Section 31 Fire divisions inliving quarters* Maritime


NMA Fire

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tion

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DNV GL AS

PSAFacilities

Regulationreference



Section 32Fire and gasdetectionsystem

Maritime NMA Fire, Sec. 22-25

Section 33Emergencyshutdownsystem

Maritime NMA Fire, Sec. 26

Section 34aControl andmonitoringsystem

Maritime

NMA Ballast

NMA Stability

NMA Fire


Section 36 Firewatersupply Maritime

NMA Fire, Sec. 6-9*

NMA Helicopter decks, Sec. 38.4,38.8*

NMA Helicopter deck regardingrequirements firewater pumpcapacity and supply arrangement.

Section 37Fixed fire-fightingsystems

MaritimeNMA Fire, Sec. 6-11

NMA Helicopter decks, Sec. 38.4,38.8

NMA Helicopter deck regardingrequirements to fixed fire fightingsystems.

Section 38

Emergencypower andemergencylighting*

Maritime

NMA Construction, Sec. 7, 11-13,21, Appendix III

NMA Fire, Sec. 6, 23, 25,26

NMA Ballast, Sec. 7

NMA Helicopter deck, Sec. 27, 38

NMA Stability, Sec. 39, 40

Section 39 Ballast system Maritime NMA Ballast Not applicable for self-elevatingunits.

Section 40 Open drainagesystems* Maritime See note Covered by class.

Section 46

Manual fire-fighting andfirefighters’equipment


Section 47 Electricalinstallations* Maritime DNVGL-OS-D201

See acknowledgement from PSAstating acceptance of use ofDNVGL-OS-D201 in lieu of NMAregarding electrical installations.

Section 56

Load-bearingstructuresand maritimesystems

Maritime


NMA Stability, Sec. 22 and Sec. 30DNVGL-OTG-13, DNVGL-OTG-14 *

DNVGL-OTG-13, DNVGL-OTG-14applicable for semi-submersibleunits. See PSA circular dated30.09.2016.

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PSAFacilities

Regulationreference



Section 58 Living quarters Maritime

NMA Construction, Sec. 6, 6a, 7, 8,12, 13, 14, 15, 17, 18

NMA Living Quarter, Sec. 6-15,17-18

NMA Fire, Sec. 19

PSA specify the following additionalrequirement:

— Bunk beds should be replacedby beds on the floor.

Section 59 Healthdepartment Maritime NMA Living Quarter, Sec. 16

Additional PSA requirement thatthe health department should belocated with the least possibleexposure to noise and vibrations,and such that stretcher transportto the health department ofsick or injured personnel can beaccomplished in a prudent manner.

Verification scope is limited torequirements to layout, locationand access.

Section 60 Emergencysickbay

PSA –Facilities

PSA Facilities Regulations Sec.60incl. Guidelines

NORSOK C-001 Ch. 7.21


Section 61Supply of foodand drinkingwater

Maritime NMA Potable Water

Section 62 Stability Maritime NMA Stability, Sec. 8-51 Not applicable for self-elevatingunits.

Section 63Anchoring,mooring andpositioning

Maritime NMA Anchoring Not applicable for self-elevatingunits.

Section 68 Exhaust ducts* Maritime NMA Helicopter deck, Sec. 6.1

Section 71 Marking offacilities * Maritime NMA Construction, Sec. 13

PSAManagementRegulationsSection 17

Risk analysesand emergencypreparednessassessments

PSA -Management

PSA Management Regulations, Sec.17 incl. Guideline

NORSOK Z-013

NMA Risk Analysis

Verification scope is limited toreview of methodology applied andimplementation of results.

NMA Risk analysis applicableregarding maritime systems andstability.

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tion

2


DNV GL AS

PSAFacilities

Regulationreference



* Where an asterix is used this denominates a deviation from the AOC handbook revision 5Notes:

— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.— The references in this table apply in addition to the class requirements for the class notation Drilling unit.— All references to NMA relates to the technical requirements in these regulations to satisfy PSA requirements, and not

a full compliance for achieving Norwegian flag.

The following items covered by AOC are not included in this (N)-notation:

— dynamic positioning systems— drilling plant (can be covered through DRILL(N)-notation, see Sec.7)— machine tools, cutting and welding equipment— lifting and transport equipment for machinery components— life saving equipment— medical and dental equipment, medicines and first aid equipment— furniture, inventory and entertainment equipment— galley and pantry equipment, arrangement for provisions, ironing/drying equipment— personnel lifts, escalators— deck cranes (offshore cranes can be covered through CRANE-OFFSHORE(N)-notation, see Sec.11)— helicopter decks (can be covered through HELDK(S, H, N)/HELDK (S, H, F, N)-notation, see Sec.10)— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner’s management systems.

2.2 Additional technical requirements stipulated by Norwegian Petroleum Safety Authority

2.2.1 The technical requirements given in [2.2] have been stipulated by PSA in letter to classificationsocieties with (N)-notation, dated 2012-06-26, as applicable for mobile facilities following the FrameworkRegulations Sec.3. These requirements are to be considered as part of the scope of N-notation.

2.2.2 Special and primary steel for structural applications (as categorised in the relevant offshore standards)shall have documented impact toughness properties. This applies to both new and existing structures. Testsshall be made for each batch of materials.The test scope may be reduced for existing structures provided:

— The unit has a documented good service record from similar conditions as the NCS.— The quality system at the steel supplier is certified by the classification society and can demonstrate a

historic record of satisfactory results from their Charpy-testing of similar steels produced.

2.2.3 Offshore structures shall be designed with a fatigue life of minimum 20 years.Guidance note:

The 20 year requirement relates to newbuildings. For conversions a minimum fatigue life of 10 years should in general be used.Alternatively, special evaluations based on risk based inspection (RBI) may be used to demonstrate acceptable safety level w.r.t.fatigue on a case by case basis.


Cha

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DNV GL AS

2.2.4 A control shall be made in the accidental limit state (ALS) with environmental and accidental loads withan annual probability of exceedence of 10-4.

Guidance note:

The ALS control is a check against catastrophic accidents like sinking or capsizing with personnel onboard. The hull and lifeboatplatforms should remain intact for a period of time sufficient to allow evacuation of the unit.


2.2.5 For self-elevating units intended for continuous offshore operation for more than 5 years, the actioncoefficient for slender members shall be minimum 1.3.

Guidance note:

The requirement is limited to cord and brace members, and not relevant for secondary slender members being part of a primarybearing structure element (e.g. stiffeners on an integrated plate field).


2.2.6 Units shall resist collision energies of at least 35 MJ.Guidance note:

A lower collision energy may be justified based on site specific probability assessments or use of compensating measures. Collisionsurvivability is related to the unit's total structural integrity and damage stability capability, meaning that the unit should remainintact for a period of time sufficient to allow evacuation.


2.2.7 Other possible causes of damage than those indicated in NMA Stability Regulations and DNV GL rulesshall also be taken into account.An analysis of possible damage cases shall be made. The likelihood and consequences shall be reduced. (Ref.PSA Management Regulation section 17 on risk analyses and emergency preparedness assessments).

2.2.8 Units should be designed with as few openings to sea as possible under the waterline.

2.2.9 Maximum flow of fire water from fire water pumps (internal or external) shall not lead to weight orstability problems for the unit.

2.3 Limitations

2.3.1 The following aspects subject to PSA requirements are not included in th Drilling unit(N)-notation inaddition to the limitations from the AOC handbook as given in Table 1:

— PSA Facilities Regulations Sections 1-4, 6, 9, 15-17, 20-27, 34, 35, 41-45, 48-55, 57, 64-67, 69, 70,72-82.

— emergency preparedness— owner’s management system for activities onboard as well as ashore— development of risk analyses— prevention of harmful effects of tobacco— worker protection and working environment issues (including noise, room acoustics, vibration, lighting,

indoor climate, radiation, chemical exposure, ergonomic aspects)— protection against pollution— radioactive sources— potable water (regarding water quality)— operational requirements

Cha

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DNV GL AS

— regularity and reliability issues.Guidance note:

NCS regulatory items not included in the (N)-notations as listed in [2.3.1] may be covered through separate verification servicesby DNV GL. A statement of compliance will be issued following completion of such services.

DNV GL is Notified Body for all relevant EU-directives, and may offer CE-marking services on a world-wide basis.


2.3.2 The verification is limited to safety aspects of the applicable standards, rules and regulations.

3 Procedures for verification

3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to DNVGL-RU-OU-0101 Offshore drilling and support units and referred offshore standards for the specific disciplines.

3.2 Verification during construction, installation and commissioningVerification during construction, installation and commissioning shall be carried out according to DNVGL-RU-OU-0101 Offshore drilling and support units and referred offshore standards for the specific disciplines.

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DNV GL AS

SECTION 3 OIL PRODUCTION(UNIT)(N) OR OILPRODUCTION(INSTALLATION)(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to mobile offshore units satisfying thefollowing criteria:

— The unit is being classed with DNV GL with minimum service notation Oil production(Unit) or Oilproduction(Installation).

— The unit is registered with a national maritime administration.

1.2 Class notationsClassed units/installations complying with the relevant requirements of this section may, after completion ofdesign reviews and surveys be assigned class notations:

— Oil production(Unit)(N) or Oil production(Installation)(N).


2.1 Supplementary verification basis for Oil production(Unit)(N) or Oilproduction(Installation)(N).The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation:

Table 1 Verification basis for Oil production(Unit)(N) Oil production(Installation)(N)

PSAFacilities

Regulationreference



Section 5 Design offacilities

PSA –Facilities

PSA Facilities Regulations Sec.5 incl.Guidelines

ISO 13702

NORSOK S-001

IEC 61892-7

Section 7 Main safetyfunctions

PSA –Facilities


ISO 13702

NORSOK S-001

Section 8 Safetyfunctions

PSA –Facilities


ISO 13702

NORSOK S-001

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3


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PSAFacilities

Regulationreference




Maritime

NMA Construction*

NMA Anchoring*

NMA Ballast*

NMA Stability*

NMA Production, Sec. 11, 28


Verification scope and referencescover provisions relating to mattersof a maritime character thatare not directly related to thepetroleum function the facility isintended to carry out.

Section 10a Ignitionsource control

PSA –Facilities

PSA Facilities Regulations Sec.10aincl. Guidelines

ISO 13702

NORSOK S-001

EN 1127-1

Section 11

Loads/actions,load/actioneffects andresistance*

PSA –Facilities


NORSOK S-001

NMA Construction, Sec. 6, 7 and 10,implications of

NMA Stability, Sec. 22 and 30

DNVGL-OTG-13, DNVGL-OTG-14

DNVGL-OTG-13 and DNVGL-OTG-14 applicable for semi-submersible units. Refer to PSAcircular dated 30.09.2016.



Section 13

Materialshandling andtransportroutes,access andevacuationroutes

PSA –Facilities

PSA Facilities Regulations Sec. 13incl. GuidelinesNORSOK S-001, Ch.5,6 and 21


Section 14Ventilationand indoorclimate

PSA –Facilities

PSA Facilities Regulations Sec. 14incl. Guidelines

ISO 15138

NORSOK H-003

NORSOK S-001 Ch.16.4


Section 18


Maritime


NMA Radio equipment




NMA Radio equipment

NMA Lifesaving appliances sec. 16,28

Cha

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tion

3


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PSAFacilities

Regulationreference



Section 28 Safety signs PSA –Facilities


NORSOK C-002

NS 6033

Section 29 Passive fireprotection

PSA –Facilities


NORSOK S-001 Ch.19

ISO 834

ISO 3008

ISO 3009

NT Fire 021 (fire resistance tests)

ISO 22899-1 (jet fires)

Section 30 Fire divisions PSA –Facilities


NORSOK S-001 Ch.19

ISO 834

ISO 3008 for doors

ISO 3009 for windows

IMO Resolution A.754 (18) for othertypes of penetrations such as ducts,pipes and cable penetrations

Section 31Fire divisionsin livingquarters

PSA –Facilities


NORSOK S-001 Ch. 19.4.6


PSA –Facilities


ISO 13702 with Appendix B.6

NORSOK S-001 Ch.12 and 13


PSA –Facilities


ISO 13702

NORSOK S-001


PSA –Facilities

PSA Facilities Regulations Sec. 34aincl. Guidelines

EN 62682

EEMUA Publication 191

Verification scope is limited toalarm design. Requirements toprotection against ICT-relatedhazards are not included.

Section 36 Firewatersupply

PSA –Facilities


NORSOK S-001 Ch.20

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tion

3


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PSAFacilities

Regulationreference




PSA –Facilities


ISO 13702 Ch.12 and App. B.8

NORSOK S-001 Ch.20

Section 38

Emergencypower andemergencylighting

Maritime

NMA Construction, Sec. 7, 11-13, 21,Appendix III

NMA Fire, Sec. 6, 23, 25,26

NMA Ballast, Sec. 7




Section 40Opendrainagesystems

PSA –Facilities


ISO 13702 Ch.9 and Appendix B.4

NORSOK S-001, Ch. 8 and 23

Section 46


PSA –Facilities


ISO 13702 Appendix B.8.12

NORSOK S-001 Ch.20.4.7 and 8

NORSOK S-001 Ch.22.4.2.6

Section 47 Electricalinstallations

PSA –Facilities

PSA Facility Regulations Sec.47including Guidelines

IEC 61892 series

IEC 60092 series (relevant parts)

Section 56


Maritime

NMA Construction, Sec. 6, 7 and Sec.10, implications of

NMA Stability, Sec. 22 and 30

DNVGL-OTG-13, DNVGL-OTG-14

DNVGL-OTG-13 and DNVGL-OTG-14 applicable for semi-submersible units. See PSA circulardated 30.09.2016.

Section 58 Livingquarters

Maritime (seenote)


NMA Living Quarter, Sec. 6-15,17-18

NORSOK S-001

NMA applicable for construction ofliving quarters, however fire safetyto follow requirement for the unit(PSA - Facilities).PSA specify the following additionalrequirement:


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PSAFacilities

Regulationreference







PSA -Facilities






Section 62 Stability MaritimeNMA Stability, Sec. 8-51

NMA Production Plant Sec.17.2-3Not applicable for self-elevatingunits.



Section 64 Turrets Maritime NMA Production, Sec.15.1-4

Use of maritime approach iscovering turret structure andcomponents. Requirements tolayout, systems, piping andequipment in the turret area shallfollow as described for the unit asa whole.

Section 66Loading andoffloadingsystems

PSA –Facilities

PSA Facilities Regulations, Sec. 66incl. guideline

DNVGL-OS-E201 Ch.2 Sec.12

NMA Production, Sec. 35

Section 68 Exhaustducts* Maritime

NMA Helicopter deck, Sec. 6.1

NMA Production, Sec. 13, Sec. 33

Section 71 Marking offacilities* Maritime NMA Construction, Sec. 13


Riskanalyses andemergencypreparednessassessments

PSA -Management


NORSOK Z-013

NMA Risk Analysis


NMA Risk Analysis applicableregarding maritime systems andstability.

Cha

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2 Sec

tion

3


DNV GL AS

PSAFacilities

Regulationreference



* Where an asterix is used this denominates a deviation from the AOC handbook Rev. 5.Notes:

— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D, andthe PSA Facility Regulations Guidelines with respect to defining limitations to the extent of application of maritimeregulations for mobile facilities that are production facilities.

— The verification references in this table apply in addition to the class requirements for the class notation Oilproduction(Unit) or Oil production(Installation).

— All references to NMA relates to the technical requirements in these regulations to satisfy PSA requirements, and nota full compliance for achieving Norwegian flag.


— dynamic positioning systems— production plant (can be covered through PROD(N), Sec. 8)— machine tools, cutting and welding equipment— lifting and transport equipment for machinery components— life saving equipment— medical and dental equipment, medicines and first aid equipment— furniture, inventory and entertainment equipment— galley and pantry equipment, arrangement for provisions, ironing/drying equipment— personnel lifts, escalators— cranes and lifting appliances (offshore cranes can be covered through CRANE-OFFSHORE(N)-notation, see Sec.11)— helicopter decks (can be covered through HELDK(S, H, N)/HELDK(S, H, F, N)-notation, Sec.10)— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner's management systems.

2.2 Additional technical requirements stipulated by PSA

2.2.1 The technical requirements given in [2.2] and recommendations given in [2.3] have been stipulated byPSA in letter to classification societies with (N)-notation, dated 2012-06-26, as applicable for mobile facilitiesfollowing the Framework Regulations Sec.3. These requirements and recommendations are to be consideredas part of the scope of (N)-notation.


— The unit has a documented good service record from similar conditions as the NCS.— The quality system at the steel supplier is certified by the classification society and can demonstrate a


2.2.3 Offshore structures shall be designed with a fatigue life of minimum 20 years.

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Guidance note:




Guidance note:




Guidance note:



2.2.6 Units shall resist collision energies of at least 35 MJ. FPSOs using tandem loading shall resist collisionenergies of at least 60 MJ in the stern.

Guidance note:



2.2.7 Other possible causes of damage than those indicated in NMA Stability Regulations and DNV GL rulesshall also be taken into account.An analysis of possible damage cases shall be made. The likelihood and consequences shall be reduced. (SeePSA Management Regulation section 17 on risk analyses and emergency preparedness assessments).



2.2.10 FPSOs shall have a double hull arrangement as specified in MARPOL, covering the entire storage tanklength including fuel tanks.

2.2.11 The distance between oil tight boundaries and external boundaries (e.g. side shell and bottom shell)of an FPSO shall be larger than two meter, to facilitate acceptable conditions for inspection and repair andprotection against collision.

2.2.12 Provisions should be made such that the ballast system is not contaminated in case of a leakagebetween a ballast tank and an oil storage tank.

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2.3 Recommendations for tandem offloading area and equipment on floating productionand storage units stipulated by Norwegian Petroleum Safety Authority

2.3.1 The shape of the stern of FPSOs should be rounded or partly rounded to minimize consequences incase of collision between the unit and shuttle tankers.

2.3.2 The flare tower should be located in the centerline of the FPSO with a necessary distance from thestern to prevent contact between the flare tower and a worst case colliding shuttle tanker.

2.3.3 Only equipment to be used for offloading operation should be located at the stern. No lifeboats shall belocated at the stern.

2.3.4 The hawser, hawser winch and fairlead should be located in the centerline of the unit.

2.3.5 The speed of the hawser winch should be adjustable up to 50 m/min.

2.3.6 The offloading hose should be stored on a drum, not in a chute. The storage drum shall be located nextto the hawser winch.

2.3.7 Only void space or ballast tanks should be inside the stern of the hull. If ballast tanks are chosen, thewater filling volume should be maximum 75% of the total tank volume to avoid damage propagation in acollision scenario.

2.3.8 All antennas for position reference systems should be placed in the correct height at the aft of the flaretower. Signal obstructions should be avoided.

2.3.9 Gutter bar(s) should be located around the offloading area. The height of the gutter bars shall besufficient to prevent overboard spillage of oil when the vessel is rolling and not less than 400 mm.

2.3.10 Rupture disks included return pipe to cargo tank, should be arranged from the offloading pipe toprevent damages due to surge pressure.

2.3.11 The control stations should be a safe working place giving the necessary protection for the operatorfrom a snatch broken rope or wire. The operator should have free view to all involved equipment and theshuttle tanker.

2.3.12 Adequate capacity of nitrogen or inert gas should be available to displace the offloading hose inmaximum 15 minutes.

2.4 Limitations

2.4.1 The following aspects subject to PSA requirements are not included in the (N)-notation in addition tothe limitations to the AOC handbook as given in Table 1:

— PSA Facilities Regulations Sections 1-4, 6, 9, 15-17, 20-27,34,35, 41-45, 48-54, 55, 57, 65-67, 69, 70,72-82.

— emergency preparedness— owner’s management system for activities onboard as well as ashore— development of risk analyses

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DNV GL AS

— prevention of harmful effects of tobacco— worker protection and working environment issues (including noise, room acoustics, vibration, lighting,

indoor climate, radiation, chemical exposure, ergonomic aspects)— protection against pollution— radioactive sources— potable water (regarding water quality)— operational requirements— regularity and reliability issues.

Guidance note:


— DNV GL is Notified Body for all relevant EU-directives, and may offer CE-marking services on a world-wide basis.

— Functional safety certification of safety systems (SIL evaluation) according to Norwegian Oil and Gas guideline NOG-GL-070can be offered concurrent with design review activites.




3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to DNV GL rules forfloating production, storage and loading units and referred offshore standards for the specific disciplines.

3.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to rules for floatingproduction, storage and loading units and referred offshore standards for the specific disciplines.

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SECTION 4 OIL STORAGE(UNIT)(N) OR OILSTORAGE(INSTALLATION)(N)

1 Introduction

1.1 Application

1.1.1 The verification methodology described in this section may be applied to mobile offshore unitssatisfying the following criteria:

— The unit is being classed with DNV GL with minimum service notation Oil storage(Unit) or Oilstorage(Installation).

— The unit is registered with a national maritime administration.— The unit does not have a production facility.

1.1.2 For units provided with both a production facility and a storage facility, the verification basis for Oilstorage(Unit)(N) or Oil storage(Installation)(N) shall be as described in Sec.3.

1.2 Class notationsClassed units/installations complying with the relevant requirements of this section may, after completion ofdesign reviews and surveys be assigned class notation Oil storage(Unit)(N) or Oil storage(Installation)(N).


2.1 Supplementary verification basis for Oil storage(Unit)(N) or Oilstorage(Installation)(N)The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation:

Table 1 Verification basis for Oil storage(Unit)(N) or Oil storage(Installation)(N)

PSAFacilities

Regulationreference


Verification reference foradditional requirements Notes/Comments


NMA Construction

NMA Living Quarter

NMA Fire

NMA Production, Sec.11, Sec.27*


NMA Construction

NMA Living Quarter

NMA Fire


NMA Ballast

NMA Stability

NMA Fire


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tion

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PSAFacilities

Regulationreference




Maritime

NMA Construction*

NMA Anchoring*

NMA Ballast*

NMA Stability*



Maritime approach coversprovisions relating to matters ofa maritime character that are notdirectly related to the petroleumfunction the facility is intended tocarry out.

Guidance note:

Cargo piping locateddownstream of the crude oilriser emergency shutdownvalve may normally followmaritime standards. Thecrude oil riser emergencyshutdown valve and any pipingand between the valve andconnection to the riser shallnormally follow PSA FacR.


Section 10a Ignitionsource control Maritime

NMA Fire Sec. 24-26

NMA Production, sec. 13, 14*

DSB Regulations concerning maritimeelectrical installations

Section 11

Loads/actions,load/actioneffects andresistance*

Maritime

NMA Construction, Sec. 6, Sec. 7 andSec. 10, implications of


NMA Fire, Sec. 4*



Section 13


Maritime

NMA Construction

NMA Living Quarter

NMA Fire



Maritime

NMA Fire

NMA Living Quarters Sec. 9.1



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tion

4


DNV GL AS

PSAFacilities

Regulationreference



Section 18


Maritime


NMA Radio equipment

NMA Anchoring, Sec.12



NMA Radio equipment





NMA Fire

Section 30 Fire divisions* MaritimeNMA Living quarter, Sec. 6

NMA Fire

Section 31Fire divisionsin livingquarters*

MaritimeNMA Living quarter, Sec. 6

NMA Fire






Maritime

NMA Ballast

NMA Stability

NMA Fire



NMA Fire, Sec. 6-9




Maritime

NMA Fire, Sec. 6-11




Section 38

Emergencypower andemergencylighting

Maritime


NMA Fire, Sec. 6, 23, 25,26

NMA Ballast, Sec. 7



NMA Production

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tion

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PSAFacilities

Regulationreference



Section 39 Ballastsystem Maritime NMA Ballast Not applicable for self-elevating

units.

Section 40Opendrainagesystems

Maritime See note Covered by class.

Section 46



Section 47 Electricalinstallations Maritime

NMA Construction

DSB Regulations concerning maritimeelectrical installations

Section 56


MaritimeNMA Construction, Sec. 6, Sec. 7 andSec. 10, implications of


Section 58 Livingquarters Maritime


NMA Living Quarter, Sec. 6-15, 17-18

NMA Fire, Sec. 19







PSA -Facilities






Section 62 Stability MaritimeNMA Stability, Sec. 8-51

NMA Production Plant Sec.17.2-3Not applicable for self-elevatingunits.



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PSAFacilities

Regulationreference



Section 64 Turrets Maritime NMA Production, Sec.15.1-4

Covering turret structure andmachinery. Requirements to layoutand safety systems shall be asspecified for the unit as a whole asdescribed elsewhere in this table.

Section 66Loading andoffloadingsystems

PSA -Facilities

PSA Facilities Regulations, Sec. 66incl. guideline

DNVGL-OS-E201 Ch.2 Sec.12


Section 68 Exhaustducts* Maritime

NMA Helicopter deck, Sec. 6.1

NMA Production, Sec. 13, Sec. 33




PSA -Management


NORSOK Z-013

NMA Risk Analysis




— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D— The verification references in this table apply in addition to the class requirements for the class notations Oil

storage(Unit) or Oil storage(Installation).— All references to NMA relates to the technical requirements in these regulations to satisfy PSA requirements, and not



— dynamic positioning systems— machine tools, cutting and welding equipment— lifting and transport equipment for machinery components— life saving equipment— medical and dental equipment, medicines and first aid equipment— furniture, inventory and entertainment equipment— galley and pantry equipment, arrangement for provisions, ironing/drying equipment— personnel lifts, escalators— cranes and lifting appliances (offshore cranes can be covered through CRANE-OFFSHORE (N)-notation, see Sec.11)— helicopter decks (can be covered through HELDK(S, H, N)/HELDK(S,H,F, N)-notation, Sec.10)— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner's management systems.

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2.2.1 The technical requirements given in [2.2] and recommendations given in [2.3] have been stipulated byPSA in letter to classification societies with (N)-notation, dated 2012-06-26, as applicable for mobile facilitiesfollowing the Framework Regulations Sec.3. These requirements and recommendations are to be consideredas part of the scope of (N)-notation.


— The unit has a documented good service record from similar conditions as the NCS— The quality system at the steel supplier is certified by the classification society and can demonstrate a






Guidance note:




Guidance note:



2.2.6 Units shall resist collision energies of at least 35 MJ. FSOs using tandem loading shall resist collisionenergies of at least 60 MJ in the stern.

Guidance note:



2.2.7 Other possible causes of damage than those indicated in NMA Stability Regulations and DNV GL rulesshall also be taken into account.An analysis of possible damage cases shall be made. The likelihood and consequences shall be reduced. (SeePSA Management Regulation section 17 on risk analyses and emergency preparedness assessments).

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2.2.10 FSOs shall have a double hull arrangement as specified in MARPOL, covering the entire storage tanklength including fuel tanks.

2.2.11 The distance between oil tight boundaries and external boundaries (e.g. side shell and bottom shell)of an FSO shall be larger than two meters, to facilitate acceptable conditions for inspection and repair andprotection against collision.

2.2.12 Provisions should be made such that the ballast system is not contaminated in case of a leakagebetween a ballast tank and an oil storage tank.

2.3 Recommendations for tandem offloading area and equipment on floating storageunits stipulated by Norwegian Petroleum Safety Authority

2.3.1 The shape of the stern of FSOs should be rounded or partly rounded to minimize consequences in caseof collision between the unit and shuttle tankers.

2.3.2 Only equipment to be used for offloading operation should be located at the stern. No lifeboats shall belocated at the stern.

2.3.3 The hawser, hawser winch and fairlead should be located in the centerline of the unit.

2.3.4 The speed of the hawser winch should be adjustable up to 50 m/min.

2.3.5 The offloading hose should be stored on a drum, not in a chute. The storage drum shall be located nextto the hawser winch.

2.3.6 Only void space or ballast tanks should be inside the stern of the hull. If ballast tanks are chosen, thewater filling volume should be maximum 75% of the total tank volume to avoid damage propagation in acollision scenario.

2.3.7 All antennas for position reference systems should be placed in the correct height. Signal obstructionsshould be avoided.

2.3.8 Gutter bar(s) should be located around the offloading area. The height of the gutter bars shall besufficient to prevent overboard spillage of oil when the vessel is rolling and not less than 400 mm.

2.3.9 Rupture disks included return pipe to cargo tank, should be arranged from the offloading pipe toprevent damages due to surge pressure.

2.3.10 The control stations should be a safe working place giving the necessary protection for the operatorfrom a snatch broken rope or wire. The operator should have free view to all involved equipment and theshuttle tanker.

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2.3.11 Adequate capacity of nitrogen or inert gas should be available to displace the offloading hose inmaximum 15 minutes.

2.4 Limitations


— PSA Facilities Regulations Sections 1-4, 6, 9, 15-17, 20-27,34,35, 41-45, 48-55, 57, 65-67, 69, 70, 72-82— emergency preparedness— owner’s management system for activities onboard as well as ashore— development of risk analyses— prevention of harmful effects of tobacco— worker protection and working environment issues (including noise, room acoustics, vibration, lighting,

indoor climate, radiation, chemical exposure, ergonomic aspects)— protection against pollution— radioactive sources— potable water (regarding water quality)— operational requirements— regularity and reliability issues.

Guidance note:






3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to rules for floatingproduction, storage and offloading units and referred offshore standards for the specific disciplines.

3.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to rules for floatingproduction, storage and offloading units and referred offshore standards for the specific disciplines.

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SECTION 5 WELL INTERVENTION UNIT(N)

1 Introduction


— The unit is being classed with DNV GL with service notation Well intervention unit and enhancedsystem notation ES.

— The unit is registered with a national maritime administration (flagged).

1.2 Class notationsClassed units/installations complying with the relevant requirements of this section may, after completion ofdesign reviews and surveys be assigned the class notation Well intervention unit(N).


2.1 Supplementary verification basis for Well intervention unit(N)The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation.

Table 1 Verification basis for Well intervention unit(N)

PSA FacilitiesRegulationreference




NMA Construction

NMA Living Quarter

NMA Fire


NMA Construction

NMA Living Quarter

NMA Fire


NMA Ballast

NMA Stability

NMA Fire

NMA Risk analysis, Se. 22


Maritime

NMA Construction*

NMA Anchoring*

NMA Ballast*

NMA Stability*


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Section 10aIgnitionsourcecontrol*

MaritimeNMA Fire Sec. 24-26

DNVGL-OS-D201


Refer to acknowledgement fromPSA stating acceptance of use ofDNVGL-OS-D201 in lieu of NMAregarding electrical installations.

Section 11


Maritime



NMA Fire Sec. 4*





Section 13


Maritime

NMA Construction

NMA Living Quarter

NMA Fire



MaritimeNMA Fire



Section 18


Maritime


NMA Radio equipment




NMA Radio equipment





NMA Fire

Section 30 Firedivisions* Maritime


NMA Fire

Section 31Fire divisionsin livingquarters*

MaritimeNMA Living quarter, Sec. 6

NMA Fire

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Maritime

NMA Ballast

NMA Stability

NMA Fire



NMA Fire, Sec. 6-9







Section 38


Maritime


NMA Fire, Sec. 6, 23, 25,26

NMA Ballast, Sec. 7



Section 39 Ballastsystem Maritime NMA Ballast Not applicable for self-elevating

units.

Section 40Opendrainagesystems*

Maritime See note Covered by class.

Section 46




Seeacknowledgement from PSAstating acceptance of use ofDNVGL-OS-D201 in lieu of NMAregarding electrical installations.

Section 56


Maritime



DNVGL-OTG-13, DNVGL-OTG-14 *


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Section 58 Livingquarters Maritime


NMA Living Quarter, Sec. 6-15, 17-18

NMA Fire, Sec. 19




Additional PSA requirement thatthe the health department shouldbe located with the least possibleexposure to noise and vibrations,and such that stretcher transportto the health department ofsick or injured personnel can beaccomplished in a prudent manner.



PSA -Facilities




Section 61

Supply offood anddrinkingwater





Section 68 Exhaustducts* Maritime NMA Helicopter deck, Sec. 6.1




PSA -Management


NORSOK Z-013

NMA Risk Analysis



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— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.— The verification references in this table apply in addition to the class requirements for the class notation Well

intervention unit.— All references to NMA relates to the technical requirements in these regulations to satisfy PSA requirements, and not



— dynamic positioning systems— well intervention plant (can be covered through WELL(N)-notation, see Sec.9)— machine tools, cutting and welding equipment— lifting and transport equipment for machinery components— life saving equipment— medical and dental equipment, medicines and first aid equipment— furniture, inventory and entertainment equipment— galley and pantry equipment, arrangement for provisions, ironing/drying equipment— personnel lifts, escalators— deck cranes (offshore cranes can be covered through CRANE-OFFSHORE(N)-notation, see Sec.11)— helicopter decks (can be covered through HELDK(S, H, N)/HELDK(S,H,F, N)-notation, see Sec,10)— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner’s management systems.


2.2.1 The technical requirements given in [2.2] have been stipulated by PSA in letter to classificationsocieties with N-notation, dated 2012-06-26, as applicable for mobile facilities following the FrameworkRegulations Sec.3. These requirements are to be considered as part of the scope of N-notation.




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2.3 Limitations

2.3.1 The following aspects subject to PSA requirements are not included in the Well interventionunit(N)-notation in addition to the limitations to the AOC handbook as given in Table 1:

— PSA Facilities Regulations Sections 1-4, 6, 9, 15-17, 20-27, 34, 35, 41-45, 48-55, 57, 64-67, 69, 70,72-82.


indoor climate, radiation, chemical exposure, ergonomic aspects)— protection against pollution— cranes and lifting appliances— radioactive sources— potable water (regarding water quality)— operational requirements— regularity and reliability issues.

Guidance note:


DNV GL is notified body for all relevant EU-directives, and may offer CE-marking services on a world-wide basis.




3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to rules for drillingand support units and referred offshore standards for the specific disciplines.

3.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to rules for drillingand support units and referred offshore standards for the specific disciplines.

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SECTION 6 ACCOMMODATION UNIT(N)

1 Introduction


— The unit is being classed with DNV GL with service notation Accommodation unit.— The unit is registered with a national maritime administration (flagged).

1.2 Class notationsClassed units/installations complying with the relevant requirements of this section may, after completion ofdesign reviews and surveys be assigned the class notation Accommodation unit(N).


2.1 Supplementary verification basis for Accommodation unit(N)The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation.

Table 1 Verification basis for Accommodation unit(N)

PSAFacilities

Regulationreference




NMA Construction

NMA Living Quarter

NMA Fire


NMA Construction

NMA Living Quarter

NMA Fire


NMA Ballast

NMA Stability

NMA Fire



Maritime

NMA Construction*

NMA Anchoring*

NMA Ballast*

NMA Stability*


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Regulationreference



Section 10a Ignition sourcecontrol* Maritime

NMA Fire Sec. 24-25

DNVGL-OS-D201*



Section 11


Maritime



NMA Fire Sec. 4*





Section 13

Materialshandling andtransportroutes, accessand evacuationroutes

Maritime

NMA Construction

NMA Living Quarter

NMA Fire


Section 14 Ventilation andindoor climate Maritime

NMA Fire



Section 18


Maritime


NMA Radio equipment




NMA Radio equipment




NMA Living quarter, Sec. 6NMA Fire

Section 30 Fire divisions* MaritimeNMA Living quarter, Sec. 6NMA Fire

Section 31 Fire divisions inliving quarters* Maritime

NMA Living quarter, Sec. 6NMA Fire

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Regulationreference








Maritime

NMA Ballast

NMA Stability

NMA Fire



NMA Fire, Sec. 6-9







Section 38


Maritime

NMA Construction, Sec. 7, 11-13,21, Appendix III

NMA Fire, Sec. 6, 23, 25,26

NMA Ballast, Sec. 7




Section 40 Open drainagesystems* Maritime See note Covered by class.

Section 46





Section 56


Maritime



DNVGL-OTG-13, DNVGL-OTG-14 *


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Regulationreference



Section 58 Living quarters Maritime

NMA Construction, Sec. 6, 6a, 7, 8,12, 13, 14, 15, 17, 18NMA Living Quarter, Sec. 6-15,17-18

NMA Fire, Sec. 19





Additional PSA requirement thatthe the health department shouldbe located with the least possibleexposure to noise and vibrations,and such that stretcher transportto the health department ofsick or injured personnel can beaccomplished in a prudent manner.


PSA -Facilities

PSA Facilities Regulations Sec.60incl. GuidelinesNORSOK C-001 Ch. 7.21







Section 68 Exhaust ducts* Maritime NMA Helicopter Deck, Sec. 6.1



Risk analysesand emergencypreparednessassessments

PSA -Management

PSA Management Regulations, Sec.17 incl. GuidelineNORSOK Z-013

NMA Risk Analysis


NMA Risk analysis regardingmaritime systems and stability.

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PSAFacilities

Regulationreference



* Where an asterix is used this denominates a deviation from the AOC handbook revision 5.Notes:

— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.— The verification references in this table apply in addition to the class requirements for the class notation

Accommodation unit.— All references to NMA relates to the technical requirements in these regulations to satisfy PSA requirements, and not



— dynamic positioning plant (SFI 408)— machine tools, cutting and welding equipment (SFI 441 to 447)— lifting and transport equipment for machinery components (SFI 45)— life saving equipment (SFI 422, 501 to 503)— medical and dental equipment, medicines and first aid equipment (SFI 504)— furniture, inventory and entertainment equipment (SFI 54)— galley and pantry equipment, arrangement for provisions, ironing/drying equipment (SFI 55)— personnel lifts, escalators (SFI 561)— deck cranes (offshore cranes can be covered through CRANE-OFFSHORE(N)-notation, see Sec.11)— helicopter decks (can be covered through HELDK(S, H, N)/HELDK(S,H,F, N)-notation, see Sec.10)— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner's management systems.


2.2.1 The technical requirements given in [2.2] have been stipulated by PSA in letter to classificationsocieties with (N)-notation, dated 2012-06-26, as applicable for mobile facilities following the FrameworkRegulations Sec.3. These requirements are to be considered as part of the scope of (N)-notation.







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Guidance note:




Guidance note:



2.2.6 Units shall resist collision energies of at least 35 MJ.Guidance note:






2.3 Limitations


— PSA Facilities Regulations Sections 1-4, 6, 9, 15-17, 20-27, 34, 35, 41-45, 48-55, 57, 64-67, 69, 70,72-82


indoor climate, radiation, chemical exposure, ergonomic aspects)— protection against pollution— cranes and lifting appliances— radioactive sources— potable water (regarding water quality)

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— operational requirements— regularity and reliability issues.

Guidance note:






3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to rules for drillingand support units and referred offshore standards for the specific disciplines.

3.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to rules for drillingand support units and referred offshore standards for the specific disciplines.

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SECTION 7 DRILL(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to drilling plants on mobile offshoreunits being classed with DNV GL with minimum class notations Drilling unit and DRILL, and to modulardrilling systems being classed with DNV GL with minimum class notation Modular drilling system.

Guidance note:

DNV GL recommends that the unit has Drilling unit(N)-notation in order to minimize challenges on interfaces between drillingplant and unit.


1.2 Class notations

1.2.1 Units equipped with drilling plants which have been designed, constructed and installed in accordancewith the requirements of this section under the supervision of DNV GL will be entitled to the class notationDRILL(N).

1.2.2 Modular drilling plants which have been designed, constructed and installed in accordance with therequirements of this section and DNVGL-RU-OU-0294 under the supervision of DNV GL will be entitled to theclass notation Modular drilling system(N).

1.2.3 DNV GL may accept decisions by PSA as basis for assigning class notation DRILL(N).

2 PSA Compliance

2.1 General

2.1.1 Drilling systems and equipment for use on the Norwegian continental shelf shall comply with theprovisions given in the PSA regulations and referred standards in the corresponding PSA guidelines.

2.1.2 DNVGL-OS-E101 (the technical basis for class notation DRILL) is listed in PSA regulations as anacceptable reference standard for drilling plants on mobile facilities registered in a national ship register.

2.1.3 The class notation DRILL(N) documents compliance with relevant provisions given in PSA regulationsand referred standards in the corresponding PSA guidelines, documents compliance with DNV GL'sinterpretation of relevant, including Norsok D-001, R-002, N-001, N-003 and N-004 as per Table 1.

2.2 Verification basis for DRILL(N)The verification references given in Table 1 provides an overview of the additional requirements forDRILL(N). DNVGL-OS-E101 and Table 1 shall be complied with for DRILL(N)-notation:

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Table 1 Verification basis for DRILL(N)

PSAFacilities

Regulationreference

Area Verification basis for additional requirements Technical equivalence/Comments


PSA Facilities Regulations Sec.10 incl. GuidelinesDNVGL-OS-E101 is consideredequivalent to requirements inSec.10.

Section 11Loads/actions,load/action effectsand resistance

PSA Facilities Regulations Sec.11 incl. Guidelines

DNVGL-OS-E101 is consideredequivalent to requirements inSec.11 incl. NORSOK N-001, N-003and N-004.

Section 12 Materials PSA Facilities Regulations Sec.12 incl. Guidelines Covered by class.

Section 27Personneltransportequipment

PSA Facilities Regulations Sec.27 incl. GuidelinesAdditional requirements fromSec.27 (NORSOK R-002) are givenin [3] and [4].

Section 48 Well barriers PSA Facilities Regulations Sec.48, incl.guidelines

DNVGL-OS-E101 is consideredequivalent to requirements inSec.48.

Verification scope relating to wellbarriers is limited to wellheadconnector and above, but notwellhead or elements located belowthe wellhead.

Section 49 Well controlequipment

PSA Facilities Regulations Sec.49, incl.guidelines


Section 50Compensator anddisconnectionsystems



Section 51 Drilling fluidsystems



Section 52 Cementing Units PSA Facilities Regulations Sec.52, incl.guidelines


Section 53Equipment forcompletion andwell flow



Section 56Load-bearingstructures andmaritime systems

PSA Facilities Regulations Sec.56 incl. guidelinesDNVGL-OS-E101 is consideredequivalent to requirements inSec.56.

Section 69 Lifting appliancesand lifting gear

PSA Facilities Regulations Sec.69, incl.guidelinesNORSOK R-002

Additional requirements fromSec.69 (NORSOK R-002) are givenin [3] and [4].

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PSAFacilities

Regulationreference

Area Verification basis for additional requirements Technical equivalence/Comments

PSAActivitiesregulations,Section 89

Remote operationof pipes and workstrings

PSA Activities Regulations Sec.89, incl.guidelines

Additional requirements fromSec.89 (Guideline-081) are given in[3].

Notes:

— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.

2.3 Limitations

2.3.1 The following aspects subject to PSA requirements are not included in the DRILL(N):

1) regularity and reliability issues2) operational requirements3) protection against pollution4) worker protection and working environment issues5) winterization and arctic operations6) compliance with EU directives and European law.

Guidance note:

NCS regulatory items not included in the (N)-notations may be covered through separate verification services by DNV GL. Astatement of compliance will be issued following completion of such services.

— Att 4): Worker protection and working environment issues, including noise, vibration, radiation, ergonomic aspects as per NorsokS-001 and Norsok S-002. A special verification scheme is available for the drill area to capture HSE issues concurrent with designreview activites.

— Att. 5): Winterisation and arctic operation issues as per DNVGL-OS-A201. Evaluation against owners winterization philosophycan be performed concurrent with design review activites.

— Att. 6): DNV GL is notified body for all relevant EU-directives, and may offer CE-marking services for all systems in the drilling area.

— Enterprise of competence (EOC/Sakkyndig Virksomhet) as per Norsok R-003. Initial, and periodic control can be performedconcurrent with the class related surveys.

— Functional safety certification of BOP control system (SIL evaluation) according to Norwegian Oil and Gas guideline NOG-Guideline-070 can be performed concurrent with design review activites.



3 Additional design requirements

3.1 GeneralIn addition to DNVGL-OS-E101, the design requirements in [3.2] to [3.7] apply for DRILL(N).

3.2 PSA Activities Regulation Sec.89All pipe handling that can be remotely operated shall be handled in this manner as long as this improvesthe overall safety level. If manual handling is chosen, regardless of possible remote handling solutions, adocumented risk assessment shall be established. Remote operations shall be performed from a safe position

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away from exposed area. (See Norwegian oil and gas recommended guidelines for remote pipe handlingoperations - no.81).

3.3 Norsok R-002 - Ch.4

3.3.1 Norsok R-002 Ch.4.11.1 Risk assessment - GeneralA risk assessment shall be carried out in accordance with ISO 12100. The risk assessment shall as aminimum include the following phases:

— design— construction— FAT/commissioning— operation.

The risk assessment shall as a minimum contain the elements listed in ISO 12100 Sec.7.Guidance note:

See ISO 14121-2 Annex A.3.2-4 for example.


3.3.2 Norsok R-002 Ch.4.11.3 Risk assessment - Identification of hazardsAll hazards, hazardous situations and events shall be systematically identified. Lifting appliances defined ascomplex shall include component level hazards by use of FMECA.

Guidance note 1:

See ISO 14121-2 Annex A.4 for example.


Guidance note 2:

Complex lifting appliances are defined as power driven lifting appliances with high capacity and or high risks. Complex liftingappliances in drilling area are defined as BOP/X-mas cranes, main hoist, drawworks and manriding equipment.


3.3.3 Norsok R-002 Ch.4.11.4-5 and 4.12 Risk assessments – Estimation, evaluation and reductionof risksRisks shall be systematically estimated by combining the probability of occurrence and the severity of harmsand evaluated to determine if risk reduction is required. Identified risks shall be reduced in the followingorder:

1) Inherently safe design measures; meaning that the design should be altered to eliminate the identifiedrisk.

2) Safeguarding and possible complementary protective measures; meaning that protection, encapsulationand barriers should be implemented to eliminate the remaining risk.

3) Information for use covering residual risk; meaning that remaining risks not possible to remove in steps1 and 2 are to be clearly addressed in the user manual. Identified risks cannot be addressed in the usermanual without documenting attempts to reduce the risks according to steps 1 and 2.

Guidance note:

See ISO 14121-2 Annex A.5 for examples.


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3.4 Norsok R-002 - Ch.5

3.4.1 Norsok R-002 Ch.5.1.1 SuitabilityDesign documentation shall contain specification of foundation reaction forces acting at the interface betweenthe foundation and the lifting appliance. The foundation reaction forces shall include the load effects from themost severe load combinations applicable to the foundation interface, including dynamic factors and effectsfrom environmental conditions and motions of the installation. Any partial safety factors, risk coefficients orconsequence factors included in the given foundation reaction forces shall be clearly stated.

3.4.2 Norsok R-002 Ch.5.1.3 Mechanical InterferenceWarning signals and anti-collision systems shall be provided on lifting appliances where mechanicalInterference with other machinery or equipment represents an unacceptable risk.

3.4.3 Norsok R-002 Ch.5.7.6 BrakesBrakes shall automatically be activated without undue delay when the motion control lever is returned to theneutral position, at power failure, control failure or at emergency stop.

3.4.4 Norsok R-002 Ch.5.11 Limiting and Indication SystemsIndoor electrical equipment shall have minimum IP rating of IP44.

3.4.5 Norsok R-002 Ch.5.14 Limiting and Indication SystemsLifting appliances are to be provided with motion limiting devices. Lifting appliances with SWL>1 000kg shallbe fitted with capacity indicators and associated alarms.

3.4.6 Norsok R-002 Ch.5.15.1 Emergency StopLifting appliances are to be provided with emergency stops. A separate emergency stop system is to beprovided for the emergency operation system (EOS) .

3.4.7 Norsok R-002 Ch.5.15.3 Emergency Operation System (EOS)Lifting appliances for lifting of persons are to be provided with EOS. The EOS shall be capable of movingthe load in any direction. The EOS is to be provided with a separate emergency stop. Minimum hoisting andlowering speeds are to be no lower than 10% of minimum operational speed for normal conditions.

3.5 Lifting accessories and lifting components (Appendix C)

3.5.1 Norsok R-002 App.C.5 General - DesignMinimum design temperature for SDLA is -20 °C unless otherwise agreed.

3.5.2 Norsok R-002 App.C.17.3.1 SDLA - DesignIf it is possible to use the SDLA for picking up tubulars or other loads from a horizontal position, the workingload limit (WLL) for the SDLA shall be specified for the most unfavorable direction. Alternatively, differentWLLs may be specified for horizontal and vertical positions. To calculate WLL according to Norsok R-002, theload rating from API Spec 8C should be divided by a dynamic coefficient of 1,33.

3.5.3 Norsok R-002 App.C.17.3.2.1 Elevators – General

— Elevators shall be designed to withstand design load(s) according to API Spec 8C in the most unfavorableorientation (i.e. load horizontally with the opening sector facing downwards).

— All pinned and bolted connections shall be secured against unintended loosening.— Elevator suspension points shall be designed with means to prevent the elevator links to disconnect from

the suspension points.

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— Elevators with inserts shall be designed in a way, to easily verify that the correct inserts for the actualpipe dimension are used. Elevators with inserts shall have means to prevent inserts from falling out of theelevator.

3.5.4 Norsok R-002 App.C.17.3.2.2 Elevators – Locking, securing and indication

— Elevators shall be fitted with a locking mechanism, a securing device and an indication device. Thesedevices shall be protected from external influences such as impact etc.

— The locking mechanism shall be designed according to the self-closing principle so that it is not possible toopen the mechanism when loaded.

— The securing device shall be designed to prevent the locking mechanism to be opened unintentionally, e.g.by external impacts. It shall not be possible to disengage the securing device when the elevator is loaded.

— The indication device shall be designed to give a positive visual indication that the elevator is lockedand secured. It shall not be possible for the indication device to indicate "locked and secured" whenthe securing device is not in secured position. The indication device shall not be manually operated.The securing device and the indication device may be combined. Whenever the elevator is unlocked orunsecured the indication device shall clearly indicate that the elevator is unlocked and unsecured.

3.5.5 Norsok R-002 App.C.17.3.2.3 Elevators – Manually operated

— The locking mechanism should preferably be engaged by a positive mechanical action from the closingmovement of the elevator door(s). If the locking mechanism depends on springs, the risks are to beevaluated in a formal risk assessment. Design documentation for the springs is to be submitted forreview.

— It shall not be possible to close the elevator doors completely (min. 20mm opening) if the lockingmechanism is in the locked position prior to closing.

— The securing device shall engage automatically to the “secured” position when the locking mechanismis engaged. It shall not be possible to engage the securing function unless the locking function has beenperformed.

— Release of the load from the elevator shall require at least two separate manual actions by the operator,e.g. one action for disengaging the securing device and one action for opening the locking mechanism.

3.5.6 Norsok R-002 App.C.17.3.2.4 Elevators – Powered (remote operated)

— Powered (remote operated) elevators shall be fully automatic and have a pre-defined sequence for allmovements.

— The control system for powered elevators shall be integrated with the control system for the drillinghoisting machine and operation shall be as a result of one operator signal triggering all necessarymotions.

— The sequence of operations shall not be influenced by the operator.— Hoisting movements shall be prevented until the secured indication signal is given.— In the case of power loss in locked and secured position the elevator shall remain locked and secured.

Means shall be provided to unsecure and unlock the elevator manually when unloaded, only.— Signals shall be provided to the control system for the hoisting machinery when the elevator is in the

closed, locked and secured condition.

3.5.7 Norsok R-002 App.C.17.3.3 SDLA - Lifting subs, caps, nipples and tools

— SDLAs shall be secured with double barriers to avoid any part of the tool to disconnect (e.g. unscrew)from the load or the lifting appliance. NOTE: For screwed connections, a verified torque in accordance withthe manufacturer’s instructions, may be regarded as the second barrier.

— Means shall be provided for the operator to verify that SDLAs with non-threaded connections are correctlyconnected to the load and the lifting appliance.

— For SDLAs where the load holding elements interfacing with the profiles of the load are not visible fromthe outside of the SDLA, indicating devices visible from the outside shall be provided. Indicating devices

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shall be visible from all sides of the SDLA. The indicating devices shall give a clear and unambiguousindication that the load holding elements are in correct (locked) position and secured. The indicatingdevices must be designed to prevent indication of locked and secured if the SDLA is not locked andsecured.

— All SDLAs shall be provided means for connection of standardized lifting accessories for safe handling theSDLA without load.

3.6 Norsok R-002 – Lifting equipment in drilling area (Appendix D)

3.6.1 Norsok R-002 App.D.6 MouseholeA dynamic factor of 2,0 is to be applied to calculation of mouse hole bottom. A reduced dynamic factor maybe used if verified by the design, e.g. installed shock absorbers.

3.6.2 Norsok R-002 App.D.7 Horizontal to Vertical Pipe HandlingTubular feeding machine shall be designed based on a dynamic factor of minimum 1,8. This applies for theTFM when at standstill in a loading operation.

3.6.3 Norsok R-002 App.D.8 BOP/XMAS lifting equipment

— X-mas tree/BOP handling systems shall have a rated capacity indicator (pressure gauge with colour codingis acceptable).

— A guiding system to control possible horizontal movements shall be installed.— Additional requirements from Appendix G apply.

3.7 Norsok R-002 – Cranes (Appendix G)

3.7.1 Norsok R-002 App.G.3.2 Operating limitsMinimum design temperature for lifting appliances is -20 °C unless otherwise agreed.

3.7.2 Norsok R-002 App.G.13.1 Power driven winchesPower driven winches shall be equipped with a visual indication of the actual load during lifting operation. Ifthe winch operator is unable to see the winch from the operator position a drum motion indicator shall bearranged at the operator position.

3.7.3 Norsok R-002 App.G.13.3 Manrider winches

— Man riding winches shall have 2 independent systems to limit motion outside of safe operating limits (forboth lowering and hoisting).

— The EOS shall be operational within 1 min from standstill.— An over-speed protection device shall be implemented to prevent free fall or excessive lowering speed

without exposing persons or equipment to unacceptable accelerations.— When operating in areas where there may be relative motions between the surroundings and the person

being lifted, the winch shall have an automatic overload protection device to protect the person lifted frombeing exposed to pull forces exceeding 2.25 kN.Guidance note:

A mode switch where the brakes are lifted off during operation close to moving platforms will be accepted.


3.7.4 Norsok R-002 App.G.17 Mobile elevating work platforms (Scissor lifts)Mobile elevating work platforms shall be designed in accordance with EN 280.

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3.8 Norsok R002 Foundations and suspensions (Appendix H)Foundation loads from lifting appliances to be multiplied with 1.25 to account for the consequence factor. Thisis only applicable if the lifting appliance can be subjected to external loads. This is normally not the case forlifting appliances in the drilling area.

4 Additional manufacturing and installation requirements

4.1 GeneralIn addition to DNVGL-OS-E101, the manufacturing and installation requirements in [4.2] and [4.3] apply forDRILL(N).

4.2 Norsok R-002 - Ch.4 and Ch.5

4.2.1 Norsok R-002 – GeneralInformation for use (user manual, signs, signals, symbols etc.) shall be provided. Information for useshall include the complimentary safety measures needed to reduce risks identified in the risk analysis. Theinstruction for use is to be according to EN 12644. Instruction for use shall include foundation reaction forcesacting at the interface between the foundation and the lifting appliance.

4.2.2 Norsok R-002 Ch.4.9 MaintenanceA maintenance program shall be provided for all lifting appliances. The maintenance program shall includeall important maintenance tasks highlighted and recommended in the risk assessment. Complex liftingappliances shall have a maintenance program developed on component level (e.g. FMECA).

4.2.3 Norsok R-002 Ch.4.10 Quality management systemThe manufacturer shall be able to document a quality management system in accordance with ISO 9001 orequivalent.

4.2.4 Norsok R-002 Ch.5.4.3 Escape and AccessSee NMA No. 856/87 §14, Stairs and Ladders - Location:

1) Stairs shall be placed in routes where the difference in level is more than 450 mm.2) In principle the ladders shall be inclined. However, vertical ladders in a height up to 18 metres may be

arranged where it is impractical to arrange inclined ladders.3) Should it for practical reasons be impossible to arrange fixed ladders/stairs, removable ladders/stairs

may be permitted provided they can be securely fastened.4) Fixed ladders shall be placed at all points where it is necessary to climb more than 1.5 meters to carry

out inspections.

See NMA No. 856/87 §14, Stairs and Ladders - Construction

1) Stairs shall have railing on both sides and the inclination shall not exceed 50°. The steps shall be atleast 150 x 600 mm and shall be slip-proof in all directions. Steps in outside stairs and steps which maybe exposed to oil spills, mud, etc., may be required made of self-draining grating. Railings shall have avertical height above steps of at least 1000 mm and shall be furnished with at least one middle railing.The projection of the steps shall overlap one another.

2) Fixed, vertical ladders shall have a breadth of minimum 350 mm, but of maximum 500 mm, between thebearers, a depth of minimum 150 mm behind the steps and the vertical distance between the steps shallbe at least 250 mm, but not more than 350 mm. Between each rest platform and in the entire ladder, allthe steps shall be evenly spaced and be in alignment.

3) Fixed, inclining ladders shall have a breadth of minimum 400 mm between the bearers and a minimumdepth of 150 mm behind the steps. The vertical distance between the steps shall be at least 200 mm,

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but not more than 250 mm. Between each rest platform and in the entire ladder, the steps shall beevenly spaced. The inclination of the ladder shall not exceed 70°.

4) The steps shall be made of minimum 22 mm square steel bar and so mounted that one of the squarebar corners will point upwards. There shall be single rungs in the vertical ladders and double rungs ininclined ladders.

5) Single steps mounted direct on hatch coamings, bulkheads or similar, shall be of 22 mm square steel baror equivalent, and have the same depth behind the steps, distance between and breadth as mentionedin item 2.) above. The steps shall be of a design which effectively stops the foot from slipping sidewaysand shall be aligned with the ladders below and above. There shall also be a satisfactory handhold. Ifnecessary a separate handhold shall be arranged.

6) The maximum allowed continuous height of a ladder is 9 meters. If the climbing height exceeds this, restplatforms with railing shall be arranged at intervals of maximum 6 meters.

7) If the climbing height for vertical ladders is more than 6 meters, and for especially exposed ladders,safety hoops shall be arranged from a height of 2.5 meters and upwards. Wherever possible, safetyhoops shall be carried 1 meter above the upper level and have a breadth/depth of at least 600 x 600mm.

8) Platforms and gangways shall be made of slip-proof open grating or the like, be at least 600 mm wideand have a railing at least 1 meter high. If there is a passage or work area underneath, the openings ofthe grating shall be so small that a ball of 15 mm diameter will not fall through. Alternatively a special,fine grating may be arranged underneath the platforms/gangways.

9) When dimensioning ladders and stairs, fastenings, rest platforms and safety hoops, environmentalconditions (sea, weather, and wind etc.) shall be taken into consideration and also possible strainwherever the ladders/stairs are in an exposed position due to the handling of cargo. Platforms andgangways shall be dimensioned for 400 kp/m2. The allowed bending of the gangways shall be maximum1/250 between the point of support.

10) It is not allowed to discontinue the bearers of vertical ladders. The bearers shall be continuous to give asafe handhold.

11) Inclined ladders shall have an effective handrail on each side.12) In exposed places, such as masts, deckhouse, cranes, etc. where maintenance work is necessary,

effective railing or safety hoops for footing shall be arranged.13) The steps shall be carried through the bearers and have continuous welding on both sides. Other

constructions which are just as effective may also be allowed.14) All joints in stairs and ladders and the mounting of same shall have continuous welding of at least 5 mm

weld thickness. If, for special reasons, it is necessary to bolt the stair/ladder to fasten it, the bolts shallbe effectively secured.

15) Single steps shall be fastened so securely that they will be deformed before they loosen.

See NMA No. 856/87 §14, Railings:

1) Decks, passageways, scaffolding, and platforms which are 800 mm or more above the level below, shallbe furnished with fixed strong railing with toeboards along the outer edge. Where it is impractical toarrange a fixed railing, alternative arrangements providing an equivalent safety level may be used.

2) The height of railings, handropes, etc. shall be at least 1 meter from deck to upper rail. There shall betwo intermediate rails with a distance of maximum 380 mm. The opening below the lower rail in therailing shall not exceed 230 mm at the open part of the deck. The distance between stanchions shall bemaximum 1.5 meters.

Guidance note:

EN 13586 is considered equivalent to the NMA requirements in [4.2.4].


4.2.5 Norsok R-002 Ch.5.4.4 MarkingAll lifting appliances are to be marked with SWL. Lifting accessories are to be marked with WLL. If APIcompliance is required, Load Rating shall also be marked on the appliance/accessory.

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4.2.6 Norsok R-002 Ch.5.4.8 Falling objectsBolts used in lifting equipment shall normally be secured. Exceptions are bolts which represent no hazard.The following methods/products are considered to be properly secured:

— controlled documented pretension to 70 % of yield, used for bolts where the clamping length is at least 3times the diameter

— nut with split-pin through the bolt— through metal nuts— locking plates.

4.2.7 Norsok R-002 Ch.5.15.3 Emergency operation system (EOS)Minimum EOS hoisting and lowering speeds are to be no lower than 10% of minimum operational speed fornormal conditions.

4.2.8 Norsok R-002 Ch.5.16 CommunicationsPermanently fixed telephone, UHF/VHF radio and loudspeaker/alarm horn to be fitted in lifting applianceswith enclosed control cabins.

4.2.9 Norsok R-002 Ch.5.22-23 Fabrication, installation and assemblyFabrication, material selection, welding inspection and testing is to be performed according to DNVGL-ST-0377 and DNVGL-ST-0378 unless otherwise specified in the annexes of Norsok R-002.

4.2.10 Norsok R-002 Ch.5.25 Technical construction fileThe technical construction file shall as a minimum contain:

— Unique identification details of the lifting equipment.— Design specification including design parameters.— Risk assessments including resulting risk reduction measures and residual risk level.— Applicable requirements for the lifting appliance.— Standards and codes used.— Technical information, such as GA drawings, detailed drawings with dimensions and cross sections relevant

for strength analysis, material specifications, welding details, diagrams of power and control circuits,calculations, test reports etc.

— Fabrication documentation, e.g. material certificates, fabrication procedures, welding documentation etc.— Verification reports.— Formal statements, declarations and certificates, Instructions for use, including inspection and

maintenance instructions, including wear and tear tolerances, non-destructive examination (NDE) programif applicable, and NDE program for examination after load tests performed during construction andinstallation.

4.3 Norsok R-002 – Lifting accessories and lifting components (Appendix C)

4.3.1 Norsok R-002 App.C.17.3.4 SDLA – TestingSDLAs shall be proof load tested in accordance with API Spec 8C. For SDLA with WLL specified for differentdirections, the load test is to be performed in all directions.

4.3.2 Norsok R-002 App.C.17.3.6 SDLA – Manufacturer’s certificateManufacturer’s SoC shall include reference to Norsok R-002 and state the working load limit (WLL)corresponding to the load rating.

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4.3.3 Norsok R-002 App.C.17.3.7 SDLA – MarkingAll SDLAs shall be marked with their WLL. For SDLAs with one -1- WLL, the marking shall indicate the WLLfor the most unfavorable direction for which the load is possible to be applied. For SDLAs with more thanone WLL for different directions, the WLL for each direction shall be marked with a clear indication for whichdirection the different WLLs apply. SDLA solely intended for being lifted by the derrick drilling machine (DDM)may be marked with load rating only, in accordance with API Spec. 8C.


5.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to rules forOffshore drilling and support units (DNVGL-RU-OU-0101) and referred offshore standards for the specificdisciplines. This in addition to requirements found in Table 1.

5.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to rules forOffshore drilling and support units (DNVGL-RU-OU-0101) and referred offshore standards for the specificdisciplines.

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SECTION 8 PROD(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to production plants on mobile offshoreunits being classed with DNV GL with service notation Oil production(Unit).

Guidance note:

DNV GL recommend that the unit is assigned Oil production(Unit)(N)-notation in order to minimize challenges on interfacesbetween production plant and unit.


1.2 Class notations

1.2.1 Units equipped with production plants complying with the requirements of this section may, aftercompletion of design reviews and surveys be assigned the class notation PROD(N).

1.2.2 DNV GL may accept decisions by PSA as basis for assigning class notation (N).


2.1 GeneralProduction systems and equipment for use on the Norwegian continental shelf shall comply directly with theprovisions given in the PSA regulations and referred standards in the corresponding PSA guidelines.

2.2 Supplementary verification for PROD(N)The following areas will be subject to additional design verification and survey as basis for assignment of the(N)-notation.

Table 1 Verification basis for PROD(N)

PSAFacilities

Regulationreference

Area Verification reference for additional requirements Notes/Comments

Section 5 Design of facilities


ISO 13702

NORSOK S-001

IEC 61892-7

Section 8 Safety functions


ISO 13702

NORSOK S-001



NORSOK: L-001, L-002, P-002, R-001, Z-DP-002

IEC 61892

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PSAFacilities

Regulationreference


Section 11Loads/actions,load/action effectsand resistance


NORSOK L-002, N-001, N-003, N-004, M-101, S-001, Z-013App B

ISO 13702

Section 12 MaterialsPSA Facilities Regulations Sec.12 incl. Guidelines

NORSOK M-001, M101, M-601, R-004

Verification scoperelating to R-004 islimited to insulation forpersonnel protectionand passive fireprotection.

Section 15 Chemicals andchemical exposure


NORSOK P-002

Section 33 Emergencyshutdown system


ISO 13702

NORSOK S-001

Section 34 Process safetysystem


ISO 10418

NORSOK: P-002

API Standard 520/ EN ISO 4126

API Standard 521

Section 34a Control andmonitoring system

PSA Facilities Regulations Sec. 34a incl. Guidelines

EN 62682

EEMUA Publication 191

Verification scopeis limited to alarmdesign. Requirementsto protection againstICT-related hazards arenot included.

Section 35 Gas releasesystem


ISO 13702 Ch. 7 and App. B.2

API Standard 521

NORSOK S-001 Ch.11

NORSOK P-002 Ch.21

Section 40 Open drainagesystem


ISO 13702 Ch. 9 and App. B.4

NORSOK S-001 Ch.8

NORSOK P-002 Ch. 28

Section 55 Production plantsPSA Facilities Regulations Sec.55 incl. Guidelines

NORSOK P-002, L-001, L-002

Section 56Load-bearingstructures andmaritime systems


NORSOK N-001

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PSAFacilities

Regulationreference


Notes:

— The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.

The following items covered by AOC are not included in (N)-notation:

— winterisation and arctic operation issues— working environment issues— compliance with EU-directives and European law— owner’s management systems.

2.3 Limitations


— regularity and reliability issues— development of risk analyses— worker protection and working environment issues (including noise, vibration, radiation, chemical

exposure, ergonomic aspects)— protection against pollution— operational requirements.

Guidance note:


— DNV GL is notified body for all relevant EU-directives, and may offer CE-marking services on a world-wide basis.

— Functional safety certification of safety systems (SIL evaluation) according to Norwegian Oil and Gas guideline NOG-Guideline-070 can be offered concurrent with design review activites.




3.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to DNVGL-OS-E201.

3.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to DNVGL-OS-E201.

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SECTION 9 WELL(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to well intervention equipment onmobile offshore units being classed with DNV GL with service notation Well intervention and WELL, and toand modular well systems being classed with DNV GL with minimum class notation Modular well system.

Guidance note:

DNV GL recommend that the unit is assigned Well intervention(N)-notation in order to minimize challenges on interfacesbetween well intervention equipment and unit.


1.2 Class notations

1.2.1 Units equipped with well intervention equipment complying with the requirements of this section may,after completion of design reviews and surveys be assigned the class notation WELL(N).

1.2.2 Modular well systems which have been designed, constructed and installed in accordance with therequirements of this section and DNVGL-RU-OU-0294 under the supervision of DNV GL will be entitled to theclass notation Modular well system(N)

1.2.3 DNV GL may accept decisions by PSA as basis for assigning (N)-notation.

2 PSA Compliance

2.1 General

2.1.1 Well intervention equipment and systems for use on the Norwegian continental shelf shall comply withthe provisions given in the PSA regulations and referred standards in the corresponding PSA guidelines.

2.1.2 DNVGL-OS-E101 (the technical basis for class notation DRILL and WELL) is listed in PSA regulationsas an acceptable reference standard for drilling and well intervention plants on mobile facilities registered in anational ship register.

2.1.3 The class notation WELL(N)documents compliance with relevant provisions given in PSA regulationsand referred standards in the corresponding PSA guidelines, documents compliance with DNV GL'sinterpretation of relevant, including Norsok D-002, R-002, N-001, N-003 and N-004 as per Table 1.

2.2 Verification basis for WELL(N)The verification references given in Table 1 provides an overview of the additional requirements forWELL(N). DNVGL-OS-E101 and Table 1shall be complied with for WELL(N)-notation:

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Table 1 Verification basis for WELL(N)


Area/System Verification basis foradditional requirements Technical equivalence/Comments



DNVGL-OS-E101is considered equivalentto requirements in Sec.10.

Section 11



DNVGL-OS-E101 is considered equivalentto requirements in Sec.11 incl. NORSOKN-001, N-003 and N-004.

Section 12 Materials PSA Facilities Regulations Sec.12 incl.Guidelines Covered by class.

Section 27Personneltransportequipment


Additional requirements from Sec.27(NORSOK R-002) are given in [3]and [4].

Section 48 Well barriers PSA Facilities Regulations Sec.48, incl.guidelines

DNVGL-OS-E101 is considered equivalentto requirements in Sec.48.

Verification scope relating to well barriersis limited to wellhead connector andabove, but not wellhead or elementslocated below the wellhead.

Section 49 Well controlequipment



Section 50

Compensatoranddisconnectionsystems



Section 51 Drilling fluidsystems



Section 53Equipment forcompletion andwell flow



Section 56


PSA Facilities Regulations Sec.56 incl.guidelines


Section 69Liftingappliances andlifting gear

PSA Facilities Regulations Sec.69, incl.guidelinesNORSOK R-002

Additional requirements from Sec.69(NORSOK R-002) are given in [3] and[4].

PSA Activitiesregulations,Section 89

Remoteoperation ofpipes and workstrings

PSA Activities Regulations Sec.89, incl.guidelines

Additional requirements from Sec.89(Guideline-081) are given in [3].

Notes:The table is based on the Handbook for Application for Acknowledgement of Compliance (AOC), enclosure D.

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2.2.1 Typically, the following equipment shall be subject to verification as applicable.

— wireline unit including power pack— subsea wireline lubricator assembly— BOP wireline shear-ram— grease injection skid for braided line and stuffing box for slick line— line pressure control head— wireline winch— skids/carriers for handling of equipment— umbilicals for subsea controls— subsea coiled tubing lubricator— BOP coiled tubing shear-ram— coiled tubing reel— lifting equipment— high pressure pumping facilities (cement, well stimulation fluids, nitrogen)— emergency disconnect package (EDP)— lower riser package (LRP)— umbilicals for subsea controls.

2.3 Limitations

2.3.1 The following aspects subject to PSA requirements are not included in the WELL(N):

1) regularity and reliability issues2) operational requirements3) protection against pollution4) worker protection and working environment issues5) winterization and arctic operations6) compliance with EU directives and European law.

Guidance note:

NCS regulatory items not included in the (N)-notations may be covered through separate verification services by DNV GL. Astatement of compliance will be issued following completion of such services.

— Att. 4): Worker protection and working environment issues, including noise, vibration, radiation, ergonomic aspects as per NorsokS-001 and Norsok S-002. A special verification scheme is available for the drill area to capture HSE issues concurrent with designreview activites.

— Att. 5): Winterisation and arctic operation issues as per DNVGL-OS-A201. Evaluation against owners winterization philosophycan be performed concurrent with design review activites.

— Att. 6): DNV GL is Notified Body for all relevant EU-directives, and may offer CE-marking services for all systems in the drillingarea.

— enterprise of competence (EOC/Sakkyndig Virksomhet) as per Norsok R-003. Initial, and periodic control can be performedconcurrent with the class related surveys.

— Functional safety certification of BOP control system (SIL evaluation) according to Norwegian Oil and Gas guideline NOG-Guideline-070 can be performed concurrent with design review activites.



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3 Additional design requirements

3.1 GeneralIn addition to DNVGL-OS-E101, the additional design requirements in Sec.7 [3] apply for WELL(N).

4 Additional manufacturing and installation requirements

4.1 GeneralIn addition to DNVGL-OS-E101, the additional manufacturing and installation requirements in Sec.7 [4] applyfor WELL(N).


5.1 Design verification and certification of materials and componentsExtent of documentation and certification of materials and components shall be according to DNVGL-RU-OU-0101 Offshore drilling and support units and referred offshore standards for the specific disciplines. Thisin addition to requirements found in Table 1.

5.2 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to DNVGL-RU-OU-0101 Offshore drilling and support units and referred offshore standards for the specific disciplines.

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SECTION 10 HELDK(S, H, N)/HELDK(S, H, F, N)

1 Introduction

1.1 ApplicationThe requirements in this section may be applied to helicopter decks on mobile offshore units classed withDNV GL to a minimum of HELDK(S, H), respectively HELDK(S, H, F).

1.2 Class notationsMobile offshore units with helicopter decks which have been designed, constructed and installed inaccordance with the requirements of this section may be given the class notation HELDK(S, H, N),respectively HELDK(S, H, F, N).


2.1 GeneralHelicopter decks on mobile offshore units on the Norwegian continental shelf shall comply with the provisionsgiven in NMA No. 72 of 2008-01-15.

2.2 Supplementary verification for (N)In addition to DNVGL-OS-E401 Ch.2 Sec.1 to Sec.6 (for units with HELDK(S, H)) and DNVGL-OS-E401 Sec.1 to Sec. 7 (for units with HELDK(S, H, F)), the Helicopter deck regulations of NMA No.72 of2008-01-15 shall be complied with.

Guidance note:

It is noted that the regulations of Norwegian Civil Aviation Authorities, in CAA-N BSL D 5-1, Regulation 26 October, no.1181governing commercial air traffic to and from helicopter decks on units operating on the Norwegian continental shelf, is covered bythe above regulations.


2.3 Limitations

2.3.1 The following aspects subject to PSA requirements are not included in HELDK(S, H, N) or HELDK(S,H, F, N):

— regularity and reliability issues— development of risk analyses— worker protection and working environment issues (including noise, room acoustics, vibration, lighting,

indoor climate ,radiation, chemical exposure, ergonomic aspects)— protection against pollution— operational requirements

Guidance note:


DNV GL is notified body for all relevant EU-directives, and may offer CE-marking services on a world-wide basis.



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SECTION 11 CRANE-OFFSHORE(N)

1 Introduction

1.1 ApplicationThe verification methodology described in this section may be applied to cranes on mobile offshore unitsbeing classed with DNV GL with class notation Crane-offshore.

1.2 Class notationsUnits equipped with cranes complying with the requirements of this section may, after completion of designreviews and surveys be assigned the class notation Crane-offshore(N).In order to obtain this notation at least one of the cranes onboard must have been verified in accordancewith this section.


2.1 GeneralCranes for use on the Norwegian continental shelf shall comply with the provisions given in the PSAregulations and referred standards in the corresponding PSA guidelines.

Guidance note:

Pedestal and connection to deck shall be cheeked according to EN 13852-1.


2.2 Supplementary requirements for Crane-offshore(N)In addition to complying with DNVGL-ST-0378, Standard for offshore and platform lifting appliances, thefollowing regulations and standards shall be complied with for Crane-offshore(N) notation:

— PSA Facility Regulations with Guidelines Sec.69 Lifting appliances and lifting gear— NORSOK-R002 Lifting Equipment— EN 13852-1 Cranes – Offshore cranes- Part 1: General – purpose offshore cranes.— EN 13135 Cranes-Safety- Design-Requirements for equipment— EN ISO13849-1 Safety of machinery – Safety-related parts of control systems Part 1: General principles

for design.— IEC 60204-32 Safety of machines Part 32: Requirements for hoisting machines.

For the application of these, see Ch.1 Sec.1 [3.1.3].Guidance note:

Alternatively, upon owners request, Crane-offshore(N) may be issued based on maritime regulations from the NorwegianMaritime Authority (NMA) accordant to PSA framework regulations, section 3 Application of maritime regulations in the offshorepetroleum activities. It is recommended that such approach is specifically agreed with PSA by the owner.


2.3 Overview of technical areasThe areas as listed in Table 1 and Table 2 will be subject to additional design verification and survey as basisfor assignment of the class notation Crane-offshore(N).

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Table 1 Areas to be verified and surveyed with reference to NORSOK R-002 and EN 13135 asmarked

Number Area Verification Reference Notes/Comments

1) Principle of safety integration Part 4.4 NORSOK R-002

2) Safeguarding and complementary protectivemeasurement Part 4.6 NORSOK R-002

3) Information for use Part 4.7 NORSOK R-002

4) Strength proportion Part 4.8 NORSOK R-002

5) Maintenance Part 4.9 NORSOK R-002

6) Quality management system Part 4.10 NORSOK R-002

7) Risk assessment Part 4.11 all NORSOK R-002

8) Risks reduction Part 4.12 NORSOK R-002

9) Documentation of risk assessment Part 4.13 NORSOK R-002

10) Electro technical equipment Part 5.11 NORSOK R-002

11) Non-electro technical equipment Part 5.12 NORSOK R-002

12) Controls, control stations and control systems Part 5.13 NORSOK R-002

13) Cranes with emergency operation system (EOS) Annex G4 NORSOK R-002

14) Size and capacity Annex G11.1 NORSOK R-002

15) Access Annex G11.3 NORSOK R-002

16) View from the control station Annex G11.4 NORSOK R-002

17) Control station outfitting Annex G11.5 NORSOK R-002

18) Data recorder Annex G11.7 NORSOK R-002

19) Data remote access Annex G11.8 NORSOK R-002

20) Hook and block protection device Annex G11.11 NORSOK R-002

21) Rigging detection system Annex G11.12 NORSOK R-002

22) Location of emergency stop Annex G11.13 NORSOK R-002

23) Location of MOPs manual control Annex G11.14 NORSOK R-002

24) AOPS simulation and testing Annex G11.15 NORSOK R-002

25) Hook Velocities Annex G11.16NORSOK R-002The velocity shall be consideredfor load chart derating.

26) Rescue boat lifting operations Annex G11.19

NORSOK R-002Shall only be consideredif accepted by the flagadministration.

27) Emergency operation system (EOS) Annex G11.21 NORSOK R-002

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28) Service brakes Part 5.3.3.2 EN 13135

29) Brakes for vertical movements Part 5.3.3.3 EN 13135

30) Rope sheaves Part 5.3.6.4 EN 13135

31) Motors and Brakes Part 5.5.4.3.2 EN 13135

Notes:See Table 2.

Table 2 Areas to be verified and surveyed with reference to EN-13852-1; 2013


1) Out of service loads Part. 5.2.3 Annex C.2.1b) and C.2.2

2) Failure mode analysis Part. 5.2.4 Annex D

3) Non electrical equipment Part 5.3.2 Number 27, 28, 29 and 30 inTable 1

4) Power requirements Part 5.3.3

5) Slewing drives Part. 5.3.4 Paragraph 2

Mode and rigging selector Part 5.3.14

7) Control station, machinery house etc. Part 5.5

8) Noise reduction Part 5.6

9) Access, guards etc. Part 5.7

10) Controls Part. 5.8.2 Response time

11) Indicators General Part 5.8.3.1 Annex F

12) Slack rope indicator Part 5.8.3.3

13) Drum motion Indicator Part 5.8.3.4

14) Indicator for failures in the power system Part 5.8.3.5 Annex F

15) Wind speed indicator Part. 5.8.3.6

16) Crane inclometer Part 5.8.3.7

17) Slewing torque indicator Part. 5.8.3.8

18) Data recorder Part 5.8.3.10

19) Slack wire rope preventer Part 5.8.4.3

20) Slewing limiter Part 5.8.4.4

21) Emergency operation system Part 5.9.2

22) Secondary motion limiters Part 5.10.6

23) Documentation Part. 7.1

24) Operation Part. 7.2

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25) Maintenance Part. 7.3

26) Incoming supply conductor terminations anddevices for disconnecting and switching off Part 5 IEC 60204-32

27) Equipotential bonding Part 8 IEC 60204-32

28) Control limitation Part 9.2.7.2 IEC 60204-32

29) Determination of factors Annex B

30) Environmental influences Annex C.1 Minimum wave height

31) Boom stalling Annex C.2.2

32) Floating units Annex C.3

33) Ice Annex C.5

34) Control station Instrumentation Annex F

35) Required performance levels Annex K EN ISO13849-1

36) Noise test Annex N

Notes:

— The verification references in these tables apply in addition to the class requirements for the class notation Crane-offshore.

The following items covered by AoC are not included in (N)-notation:

— working environment issues are not fully covered— compliance with EU-directives and European law— owner’s management system.

2.4 Limitations

2.4.1 In addition to the limitations stated in Table 2, the following aspects subject to PSA requirements arenot included in the (N)-notation:

— NORSOK R-002 Annex B, Material handling principles— worker protection and working environment issues (including noise, room acoustics, vibration, lighting,

indoor climate, radiation, chemical exposure, ergonomic aspects.Guidance note:

NCS regulatory items not included in the (N)-notations as listed in [2.4.1] may be covered through separate verification servicesby DNV GL. A statement of compliance will be issued following completion of such services. DNV GL is notified body for all relevantEU-directives, and may offer CE-marking services on a world-wide basis.


2.4.2 The verification will only be related to safety aspects of the applicable standards, rules and regulations.

3 Design verification and certification of materials and componentsThe extent of documentation and certification of materials and components shall be in compliance with theDNVGL-ST-0378 Standard for offshore and platform lifting appliances.

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4 Survey during construction, installation and commissioningSurvey during construction, installation and commissioning shall be carried out according to DNVGL-ST-0378Standard for offshore and platform lifting appliances.In addition, initial control by an enterprise of competence (EoC), see App.B [4.2] shall be carried out.

Guidance note:

For a clarification of the enterprise of competence role is referred to Ch.3 Sec.2 [8]. A complete overview of the activities underEoC is listed in App.B.


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SECTION 12 COMF-MOU(N)

1 Introduction

1.1 ApplicationThe requirements in this section may be applied to mobile offshore units classed with DNV GL.

1.2 Class notationMobile offshore units that comply with the requirements of this section may be given the class notationCOMF-MOU(N).

1.2.1 The notation documents partial compliance with NORSOK S-002 Working environment.


2.1 GeneralMobile offshore units operating on the Norwegian continental shelf shall comply to the NORSOK S-002Working Environment, which among other things cover noise, vibration, illumination and indoor climate.

2.2 Supplementary verificationUnits with the qualifier (N) shall comply of the crn level 1 and additional requirements related to NORSOKS-002 as described in DNVGL-OS-A301 Ch.2.

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CHAPTER 3 CLASSIFICATION IN OPERATION

SECTION 1 GENERAL PROVISIONS FOR PERIODICAL SURVEYS

1 General

1.1 Principles and proceduresPeriodical surveys for (N)-notations shall follow systematics applied for offshore class surveys in general. Fordetails on principles, procedures, survey intervals etc. see DNVGL-RU-OU-0300.

2 Class renewal for (N)-notation

2.1 General

2.1.1 At certificate renewals (5-yearly intervals) it shall be demonstrated that the owner/manager hascontrol over the effect of the changes between original and latest edition of the applicable technicalreferences. This may be verified by a gap-analysis. Any deviations identified shall be closed out by the ownerin order for the (N)-notation to be renewed.

Guidance note:

The AOC Handbook Sec.6.4 provides guidance on evaluation of possible consequences for the unit resulting from changes to therules and regulations. Such evaluations are a required part of the verification systematics for maintaining AOC.


2.1.2 All changes in technical references identified in [2.1.1] shall be included in the basis for the periodicsurvey related to the (N)-notation.

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SECTION 2 PERIODIC SURVEY EXTENT FOR (N)-NOTATIONS

1 Drilling unit(N)

1.1 Annual and complete periodical surveys

1.1.1 Extent of annual survey shall be as given for class notation Drilling in DNVGL-RU-OU-0300 Ch.3 Sec.3[2].

1.1.2 Extent of complete periodical survey shall be as given for class notation Drilling in DNVGL-RU-OU-0300 Ch.3 Sec.3 [2], supplemented by items given in Ch.2 Sec.2 Table 1 and Ch.3 Sec.1 [2].

2 Oil production(Unit)(N) or Oil production(Installation)(N)


2.1.1 Extent of annual survey shall be as given for class notation Oil production in DNVGL-RU-OU-0300Ch.3 Sec.3 [8].

2.1.2 Extent of complete periodical survey shall be as given for class notation Oil production in DNVGL-RU-OU-0300 Ch.3 Sec.3 [8], supplemented by items given in Ch.2 Sec.3 Table 1 and Ch.3 Sec.1 [2].

3 Oil storage(Unit)(N) or Oil storage(Installation)(N)


3.1.1 Extent of annual survey shall be as given for class notation Oil storage in DNVGL-RU-OU-0300 Ch.3Sec.3 [9].

3.1.2 Extent of complete periodical survey shall be as given for class notation Oil storage in DNVGL-RU-OU-0300 Ch.3 Sec.3 [9], supplemented by items given in Ch.2 Sec.4 Table 1 and Ch.3 Sec.1 [2].

4 Well intervention unit(N)


4.1.1 Extent of annual survey shall be as given for class notation Well intervention unit in DNVGL-RU-OU-0300 Ch.3 Sec.3 [3].

4.1.2 Extent of complete periodical survey shall be as given for class notation Well intervention in DNVGL-RU-OU-0300 Ch.3 Sec.3 [3], supplemented by Ch.2 Sec.5 Table 1 and Ch.3 Sec.1 [2].

5 Accommodation unit(N)


5.1.1 Extent of annual survey shall be as given for class notation Accommodation unit in DNVGL-RU-OU-0300 Ch.3 Sec.3 [4].

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5.1.2 Extent of complete periodical survey shall be as given for class notation Accommodation unit inDNVGL-RU-OU-0300 Ch.3 Sec.3 [4], supplemented by items given in Ch.2 Sec.6 Table 1 and Ch.3 Sec.1 [2].

6 DRILL(N)


6.1.1 Extent of surveys shall be as given for class notation DRILL in DNVGL-RU-OU-0300 Ch.3 Sec.4 [6],supplemented by items given in Ch.2 Sec.7 Table 1 and Ch.3 Sec.1 [2].

Guidance note:

Note there are instances where the performance standard required in Norway is higher than generally specified in the internationalcodes, e.g BOP control system accumulator capacity. When tests are carried out on a unit with DRILL(N) then the Norwegianperformance standards are to be used.


6.1.2 Survey, testing and overhaul of the blow out preventer (BOP) with associated valves and otherpressure control equipment (well control equipment) at complete periodical survey shall be performedaccording the requirements for DRILL which is in line with the principles given in DNVGL-RP-E101.

7 PROD(N)


7.1.1 Extent of annual survey shall be as given for class notation PROD in DNVGL-RU-OU-0300 Ch.3 Sec.4[26].

7.1.2 Extent of complete periodical survey shall be as given for class notation PROD in DNVGL-RU-OU-0300Ch.3 Sec.4 [26], supplemented by items given in Ch.2 Sec.8 Table 1 and Ch.3 Sec.1 [2].

8 WELL(N)

8.1 ApplicationThe requirements in this subsection apply for units with class notation: WELL(N).


8.2.1 Extent of annual survey shall be as given for class notation WELL in DNVGL-RU-OU-0300 Ch.3 Sec.4[15].

8.2.2 Extent of complete periodical survey shall be as given for class notation WELL in DNVGL-RU-OU-0300Ch.3 Sec.4 [15], supplemented by items given in Ch.2 Sec.9 Table 1 and in Ch.3 Sec.1 [2].

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9 Crane-offshore(N)

9.1 Introduction

9.1.1 The periodical survey for Crane-offshore(N) covers both the assurance requirements for class andthe requirements for enterprise of competence inspection from PSA.

Guidance note:

Enterprise of competence is an entity in the operator companies’ organization, or in other companies or institutions, that togetherhave sufficient theoretical knowledge and practical experience to understand calculations for lifting equipment, its design andfunction, and to carry out necessary examinations and tests in order to issue certificates

Enterprise of competence services is performed in accordance with NORSOK Standard R-003 as a means of complying with PSARegulations relating to conduct of activities in the petroleum activities (the Activities Regulations), Sections 16 and 47.


9.1.2 The normative reference documents given in Table 1 have been used as basis for the servicesdescribed in this chapter.

Table 1 References other than DNV GL given in this service specification

Reference Title Notes/Comments

NORSOK R-003 Annex H Safe use of lifting equipment. Enterprise of competence


9.2.1 AnnualExtent of annual survey shall be as given for class notation Crane-offshore(N) in DNVGL-RU-OU-0300 Ch.3Sec.4 [10] supplemented by the enterprise of competence (EoC) elements as described in App.B.

9.2.2 CompleteExtent of complete periodical survey shall be as given for class notation Crane-offshore(N) in DNVGL-RU-OU-0300 Ch.3 Sec.4 [10] supplemented by the enterprise of competence (EoC) elements as described inApp.B.

Guidance note:

DNV GL follows NORSOK R-003 Table H.1 Grading of faults and defects for the survey reporting of the Crane-offshore(N)services.


9.3 Safety assessments and extraordinary control

9.3.1 Safety assessmentA safety assessment shall be executed in case of increasing frequency of failure, causing serious incidents,danger for risk fatigue or where there is other reasonable doubt about safety through continued operation.The interval of safety assessments shall exceed 10 years if it was new, or at least when there are more than10 years since the previous safety assessment, (see also App.B [4.4]).A safety assessment shall include a lifetime analysis (ISO 12482), gap analysis, classification andestablishment of barriers, operational risk analysis, consideration of change of operation (e.g. person lift),working study etc., see NORSOK R-003.

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9.3.2 Extraordinary controlAn extraordinary control shall be executed in case the crane operation has encountered an unexpected eventor situation and after modifications to the crane.(See NORSOK R-003)

Guidance note:

It is the owner’s responsibility to initiate the safety assessment and extraordinary controls. The assessment may be performed byDNV GL.


10 COMF-MOU(N)

10.1 ApplicationThe requirements in this subsection apply for units with class notation COMF-MOU(N).

10.2 Complete periodical surveysExtent of complete periodical survey shall be as given for class notation COMF-MOU in DNVGL-RU-OU-0300Ch.3 Sec.4 [17].

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APPENDIX A SPECIAL CONSIDERATIONS FOR AGEING OFFSHOREUNITS (INFORMATIVE)

1 General

1.1 Introduction

1.1.1 This appendix is not part of the scope for (N)-notation and is provided for information purposes only.

1.1.2 PSA requires owners of facilities aged 19 years or more since first certificate issue, in operation orintended for operation on the Norwegian shelf, to provide special documentation of subjects as listed below.

1.2 Special documentation requirements for units aged 19 years or more

1.2.1 Fatigue life shall be calculated according to current rules and regulations and corrected for changes inassumed weights and weight distribution caused by modifications or changes in assumed usage, such as useof derrick, ballasting and loading and unloading operations. The fatigue calculations should take into accountthe actual environmental exposure the unit has been exposed to, in form of relevant environmental scatterdiagrams for respective locations or actual environmental measurements if available.

1.2.2 Redundancy in the event of substantial damage to hull, braces or jacking system, and substantialinternal damage to hull shall be calculated:

— check for overload in connection with environmental loads with return period of one year,— fatigue life.

1.2.3 An updated verification of physical match between the facility and as-built documentation shall bedone, so that

— later modifications or changed usage are taken into account in analyses and calculations,— local weld-ons or scallops do not change the integrity.

1.2.4 The rig owner shall evaluate of the needs for further requirements with respect to inspection andmaintenance as a result of extended life such as

— watertight and weatherproof closing appliances,— ballasting and stability, included seawater intake,— jacking equipment with related machinery, gears and brakes— and for related safety systems which depend on emergency power or hydraulics. The rig owner shall verify

that the manufacturers' specifications for maintenance of marine systems are complied with.

1.2.5 Rig owners shall evaluate the needs for further requirements with respect to inspection and a result ofextended life for

— load-carrying structures with respect to fatigue, corrosion, erosion and thickness measurement,— critical areas, in addition to those required by the classification societies.

1.2.6 Review information about past performance and relevant equipment usage, including results fromsimilar facilities – and a systematic review of the relevancy of major accidents/incidents worldwide the lastdecade.

1.2.7 Make plans for replacement and need for repairs offload carrying structures and marine systems.

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1.2.8 Identify possible chain of events related to maritime and structural systems, identification of barriersin these chains of events, review of the robustness, availability and reliability of these barriers. Identificationof criteria for how long these barriers are to be considered satisfactory and identification of special criteriain case several barriers are impaired at the same time. Furthermore, consider preventive measures that arepossible to do using the ALARP principles.

1.2.9 Assess the assumed future service life in terms of safe operation of the facility. Identify circumstancesthat will limit the service life and specify criteria for safe operation to the extent ¡t is possible to do so (e.g.permissible lengths of cracks, maximum permissible corrosion or remaining thickness, remaining anodes,degrading of paint protection).

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APPENDIX B DNV GL ENTERPRISE OF COMPETENCE (EOC) FORLIFTING EQUIPMENT

1 GeneralThis appendix describes the control carried out by an enterprise of competence in order to verify that liftingequipment satisfies relevant requirements and is designed, embedded, installed, set up, tested, documentedand maintained in such a way that use of the lifting equipment is fully justified.

2 Supplementary survey for enterprise of competence.Lifting equipment on offshore units operating on the NCS shall be controlled by an enterprise of competence(EoC) according to NORSOK R-003 as a means of complying with the Norwegian Petroleum Safety Authority(PSA) Regulations relating to conduct of activities in the petroleum activities (the Activities Regulations),Sections 16 and 47.

3 Execution by DNV GLThe initial and periodical controls on offshore units' lifting equipment by EoC is performed by DNV GL as partof commissioning, annual and complete classification surveys.The required safety assessment and extraordinary controls can be performed by DNV GL upon request fromthe owner.

Guidance note:

DNV GL as classification society assumes the role as EoC in accordance with NORSOK R-003, Annex H, clause H1:

“On mobile installations, requirements in the Norwegian Maritime Directorate’s regulations can be followed if the technicalspecification of the equipment was based on these requirements. Reference is made to relevant Petroleum Safety AuthorityNorway regulations that describe when maritime regulations can form the basis. In such circumstances, a competent personauthorized by the Norwegian Maritime Directorate shall be used.

Classification societies that are recognized by the Norwegian Maritime Directorate and that inspect lifting equipment as part of theclass notation “DRILL N” and “Crane” on an installation can carry out control as enterprise of competence, provided that the controlis implemented and reported in accordance with requirements in this NORSOK standard.”

After publication of the 2004 edition of NORSOK R-003, the Norwegian Maritime Directorate (NMD) has changed name toNorwegian Maritime Authority, hereafter referred to as NMA.


4 Control of lifting equipment performed by enterprise ofcompetence

4.1 IntroductionDNV GL performs three types of competent control of lifting equipment in the role as EoC:

— Initial control in the form of certification when installed— Periodic control (annual or complete (5-yearly) survey)— Safety assessment and extraordinary control.

4.2 Initial controlInitial control is normally done when the lifting equipment is placed on its final location and the extent ofapproval/verification and inspections are followed according to different notations for cranes. Upon initialinspection, DNV GL issues certificate CG2 or product certificate OLA101 and cargo gear book CG1 or similaras defined in DNVGL-ST-0378.

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4.3 Periodical control

4.3.1 GeneralPeriodical control shall follow internal procedures for EoC on DNV GL units with notation Crane-offshore orCrane-offshore(N) for annual and complete (5-yearly) survey.The control is an independent risk-based condition monitoring according to DNV GL internal governingdocumentation for such control. The aim is to verify the technical safety of the lifting equipment in relationto the requirements applied during initial control, enabling the owner and user to decide on the furtheroperation of the lifting equipment, and if necessary, implement monitoring, compensating measures orrepairs.DNV GL assumes that the lifting equipment has been designed and built for the operation and theenvironment it is exposed to, and has been, and continues to be used and maintained according to themanufacturer's requirements and the requirements owner and user given in authorities regulations, as wellas the conditions for initial control is fulfilled.Test procedures shall be available from the owner and accepted by DNV GL including examination of allrelevant parts.

4.3.2 Elements includedThe periodical control consists of the following elements:

1) Control of existing certificate (CG2), cargo gear book (CG1), maintenance and operation procedure.2) Review of previous reports from Enterprise of Competence, as well as records of maintenance and crane

use history from last control period.3) Survey of lifting equipment as determined by well-established inspection programmes4) Witness of testing of the control- and safety functions for all movements and limits.

It is the owner and user which are responsible for the implementation of function testing. In caseswhere the function testing involves an increased safety risk, DNV GL will recommend that measures areimplemented to increase the safety of the test. This can i.e. involve "safe job analysis", restrict/close offwork and warning.

5) Signing of cargo gear book, issuance of certificate if applicable.6) For lifting gear without unique marking, the periodical control shall be documented with the years color.

Periodic inspection of work equipment does not include:

1) A general operating permit for the lifting equipment. Owner and operator are responsible at any time toconsider technical and operational safety and if necessary suspend the operation of the lifting equipment,partially or completely.

2) Verification of organizational or operational requirements towards the user are met, such asrequirements for the implementation of risk analysis, training, use of protective equipment, etc.

3) Assessment of any deviations approved by the authorities.4) Establishing specific inspection/test programme.

4.4 Extraordinary controlAn extraordinary control shall be executed in case the lifting equipment operation has encountered anunexpected event or situation. Such an event indicates that the manufacturer preconditions for safeoperation and maintenance as specified in the user manual may no longer be valid.In addition the control shall be done after modifications to the lifting equipment. The modifications may affectthe validity of the certificate and/or may include a change of responsibilities from manufacturer to otherparties.The extraordinary control evaluates the safety of lifting equipment without reference to declarations ofconformity, etc. from the equipment manufacturer with the following conditions:

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— The owner and user of the crane always has a responsibility that lifting equipment is suitable and can beused safely, even after changes, rebuilds and repairs. Owner and user must ensure access to all relevantinformation need to assess the safety of lifting equipment.

— Liability is limited in accordance with the assignment of work scope.— Assessment of lifting equipment condition after extraordinary control does not always present a

complementary equipment status and must be read in conjunction with the report of the last periodicinspection.

It is assumed that the client facilitates a scope of work that is proportionate to what is the reason forextraordinary control. As a minimum, extraordinary control should include the following activities performedin the given order.

1) review of the documentation for the equipment2) review of the documentation for the reason for extraordinary control, including verification of

documentation for the work performed3) inspection4) function testing5) testing with overload if deemed necessary.

Guidance note:

For a recommended procedure for establishing a control scope reference is made to DNV-OSS-308 Verification of Lifting Appliancesfor the Oil and Gas Industry.


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CHANGES - HISTORIC

July 2017 edition

Main change July 2017

• GeneralRequirements are updated to be in compliance with NORSOK R-002.

• Ch.2 Sec.7 DRILL(N)— Ch.2 Sec.7 Table 1: Updated with clarifying text and compliance reference.— Ch.2 Sec.7 [2]: Update heading and include new clause [2.1.3].— Ch.2 Sec.7 [2.3]: Updated sub-section including risk analysis included in scope and specification of

additional services.— Ch.2 Sec.7 [3]: Design requirements from NORSOK R-002 are listed in addition to DNVGL-OS-E101.— Ch.2 Sec.7 [3.8]: Added Norsok R-002 - Foundations and Suspensions (Appendix H).— Ch.2 Sec.7 [4]: Manufacturing requirements from NORSOK R-002 are listed in addition to DNVGL-OS-

E101.— Ch.2 Sec.7 [5.1]: Updated clauses.— Ch.2 Sec.7 [5.2]: Updated clauses.

• Ch.2 Sec.9 WELL(N)— Ch.2 Sec.9 Table 1: Updated with clarifying text and compliance reference.— Ch.2 Sec.9 [2.3]: Risk analysis included in scope and additional services are specified.— Ch.2 Sec.9 [3]: Design requirements from NORSOK R-002 are listen in addition to DNVGL-OS-E101.— Ch.2 Sec.9 [4]: Manufacturing requirements from NORSOK R-002 are listed in addition to DNVGL-OS-

E101.— Ch.2 Sec.9 [5.1]: Updated clauses.— Ch.2 Sec.9 [5.2]: Updated clauses.

April 2016 edition

Main changes April 2016

• GeneralUpdates in line with the updates of other DNV GL service documents, that is:

— Description of requirements related to offshore cranes completed and replacing reference to the oldcertification standard DNV SfC 2.22 by DNVGL-ST-0378 under definition of a new notation name Crane-offshore .

— Further completion of Crane-offshore(N) service delivery, including in operation survey requirements— Inclusion of Enterprise of Competence as described in NORSOK-R003 in Crane-offshore(N) service.— Definition of COMF-MOU(N) class notation

• Ch.1 Sec.1 Introduction— Table 5: NORSOK R-002 and R-003 added

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— Table 6: EoC and OEM added.

• Ch.1 Sec.2 Introduction— [2.2] Updated listings of applicable class notations

• Ch.2 Sec.11 Crane-offshore(N)— Descriptions related to offshore cranes completely revised under update notation naming Crane-

offshore(N).

• Ch.2 Sec.12 COMF-MOU(N)— New section covering requirements for the class notation COMF-MOU(N) as relevant for newbuilding

projects.

• Ch.3 Sec.2 Periodic survey for (N)-notations— [8]: Survey requirements for Crane-offshore(N) added— [9]: Survey requirements for COMF-MOU(N) added.

• App.B DNV GL Enterprise of Competence (EoC) for lifting equipment— New appendix including description of EoC.

July 2015 edition

Main changes July 2015

• General structureThe revision of this document is part of the DNV GL merger, updating the previous DNV recommendedpractice into a DNV GL format including updated nomenclature and document reference numbering, e.g.:

— DNV replaced by DNV GL— DNV-OSS-201 to DNVGL-SI-0166 etc.

A complete listing with updated reference numbers can be found on DNV GL's homepage on internet.To complete your understanding, observe that the entire DNV GL update process will be implementedsequentially. Hence, for some of the references, still the legacy DNV documents apply and are explicitlyindicated as such, e.g.: Rules for Ships has become DNV Rules for Ships.

About DNV GLDNV GL is a global quality assurance and risk management company. Driven by our purpose ofsafeguarding life, property and the environment, we enable our customers to advance the safetyand sustainability of their business. We provide classification, technical assurance, software andindependent expert advisory services to the maritime, oil & gas, power and renewables industries.We also provide certification, supply chain and data management services to customers across awide range of industries. Operating in more than 100 countries, our experts are dedicated to helpingcustomers make the world safer, smarter and greener.

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