ro ep fe in phl 001 01 e philosophy control instrumentation packaged units

OMV Petrom S.A. Regulation

OMV Petrom S.A. Philosophy - RO-EP-FE-IN-PHL-001-01-E

Valid from: 15 December 2010 Philosophy for Control and

Instrumentation in packaged units Page 2 of 36

Edition: 1

TABLE OF CONTENTS

1. Introduction....................................................................................................................................................3 1.1. Preface ........................................................................................................................................................3 1.2. Purpose.......................................................................................................................................................3

2. Regulatory content ........................................................................................................................................3 2.1. Codes and standards ................................................................................................................................3 2.2. General requirements for field instruments...........................................................................................8 2.2.1. General ...................................................................................................................................................8 2.2.2. Environmental conditions ..................................................................................................................10 2.2.3. Electrical terminal strips ....................................................................................................................10 2.2.4. Pneumatic and hydraulic connections..............................................................................................10 2.2.5. Markings and tags ..............................................................................................................................11

2.3. Specific requirements for field instruments ........................................................................................11 2.3.1. Requirements common for all types of instruments ......................................................................11 2.3.2. Pressure and differential pressure instruments ..............................................................................12 2.3.3. Flow instruments ................................................................................................................................15 2.3.4. Temperature instruments ..................................................................................................................17 2.3.5. Level instruments ...............................................................................................................................20 2.3.6. Process stream analysers...................................................................................................................22 2.3.7. Corrosion monitoring .........................................................................................................................23 2.3.8. Control valves......................................................................................................................................23 2.3.9. Self-contained regulators...................................................................................................................24 2.3.10. ESD/PSD & BDV valves..................................................................................................................24 2.3.11. Motor operated valves ...................................................................................................................26 2.3.12. Pressure safety valves....................................................................................................................26

2.4. Requirements for Unit Control Systems for packaged units .............................................................27 2.5. Technical requirements for instruments utilities supplies, cabling systems and cabinets ............28 2.5.1. Electrical power ..................................................................................................................................28 2.5.2. Air supply .............................................................................................................................................28 2.5.3. Cable routing .......................................................................................................................................29 2.5.4. Cables...................................................................................................................................................29

2.6. Technical requirements for instrumentation testing ..........................................................................31 2.6.1. Manufacturers internal test ..............................................................................................................31 2.6.2. Final tests.............................................................................................................................................31

2.7. Maintenance in design............................................................................................................................31 2.8. Documentation requirements................................................................................................................31 2.9. Certifying authority review requirements ............................................................................................32 2.10. Spare parts...............................................................................................................................................32

3. Responsibilities............................................................................................................................................33 4. Terms and abbreviations ............................................................................................................................33 5. Obsolete regulations ...................................................................................................................................35 6. Supporting documentation ........................................................................................................................35 7. Distribution list ............................................................................................................................................36 8. Amendments from previous edition..........................................................................................................36 9. Annexes ........................................................................................................................................................36





Edition: 1

1. Introduction

1.1. Preface

1.1.1. This Philosophy defines the Petrom Exploration & Production SA corporate policy on the

design of control and instrumentation included in vendor packaged units for onshore hydrocarbon production and processing facilities. The document specifies basic

requirements and criteria, defines the appropriate codes and standards, and assists in the

standardisation of facilities design across all onshore operations.

1.1.2. The design process needs to consider project specific factors such as the location,

production composition, production rates and pressures, the process selected and the size

of the plant. This philosophy aims to address a wide range of the above variables, however it is recognised that not all circumstances can be covered. In situations where project

specific considerations may justify deviation from this philosophy, a document supporting

the request for deviation shall be submitted to Petrom E&P for approval.

1.1.3. No OMV document regarding the same subject exists at this date.

1.2. Purpose

1.2.1. This Philosophy together with specific Project Technical Specification and Data Sheets covers the minimum requirements for the design of control and instrumentation system in

packaged units.

1.2.2. This document shall be used as a reference during the Front End Engineering Design and

Detailed Design whenever a new facility is to be built or an existing facility has to be

revamped. 2. Regulatory content

2.1. Codes and standards

2.1.1. The applicable reference standards for design, manufacture, inspection, testing and

installation of the control and instrumentation in packaged units system shall be the latest

edition, including the amendments.

2.1.2. In case discrepancies occur between the provisions of different standards referring the

same subject, these shall be brought to Petrom knowledge for a decision.

Directive 2006/42/EC Council Directive on the approximation of the laws of

the Member States relating to machinery





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the Member States relating to equipment and

protective systems intended for use in potentially explosive atmospheres - ATEX

Directive 97/23/EC Council Directive on the approximation of the laws of the Member States relating to pressure equipment -

PED

Directive 2004/108/EC Council Directive on the approximation of the laws of the Member States relating to electromagnetic

compatibility EMC


the Member States relating to common provisions for

both measuring instruments and methods of

metrological control

Directive 2004/22/EC Council Directive on measuring instruments

BRML Order Concerning the official list of measuring instruments under legal metrological control LO-2010

EN 837 Pressure gauges. Bourdon tube pressure gauges

EN 1092-1 Flanges and their joints - Circular flanges for pipes,

valves, fittings and accessories, PN designated - Part 1:

Steel flanges

EN ISO 4126 Safety devices for protection against excessive

pressure

EN ISO 5167 Measurement of fluids by means of orifice plates and

venturi tubes inserted in circular cross section conduits

running full

EN ISO 6817 Measurement of conductive liquid flow in closed

conduits. Method using electromagnetic flowmeters

EN ISO 10497 Testing of valves Fire type-testing requirements

EN 13190 Dial thermometers





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EN 13463 Non-electrical equipment for use in potentially

explosive atmospheres

EN 13480 Metallic Industrial Piping

EN ISO 15156 / NACE MR-0175 Petroleum and natural gas industriesMaterials for use in H2S-containing environments in oil and gas

production

EN ISO 23251 Petroleum, petrochemical and natural gas industries -- Pressure-relieving and depressuring systems

EN ISO 28300 / API Std 2000 Petroleum, petrochemical and natural gas industries -- Venting of Atmospheric and Low-Pressure Storage

Tanks

EN 50288 Multi-element metallic cables used in analogue and digital communication and control

EN 50290 Communication cables

EN 60079 Electrical Apparatus for Explosive Gas Atmospheres

EN 60092 Electrical installations in ships

EN 60331 Tests for Electric Cables under Fire Conditions - Circuit

Integrity

EN 60332 Tests on electric and optical fiber cables under fire

conditions

EN 60364-4-41 Low-voltage electrical installations - Part 4-41: Protection for safety - Protection against electric shock

EN 60529 Degrees of Protection Provided by Enclosures (IP Code)

EN 60534 Industrial control valves

EN 60584 Thermocouples

EN 60654 Industrial-process measurement and control

equipment. Operating conditions. Climatic conditions

EN 60670 Boxes and enclosures for electrical accessories





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EN 60751 Industrial Platinum Resistance Thermometers and

Platinum Temperature Sensors

EN 60754 Test on Gases Evolved During Combustion of Materials

from Cables

EN 60811 Common Test Methods for Insulating and Sheathing Materials of Electric and Optical Cables

EN 61000 Electromagnetic Compatibility (EMC)

EN 61034 Measurement of smoke density of cables burning

under defined conditions

EN 61140 Protection against electric shock Common aspects for

installation and equipment

EN 61386 Conduit systems for cable management

EN 61508 Functional safety of electrical/electronic/programmable

electronic safety-related systems

EN 61511 Functional safety - Safety instrumented systems for the

process industry sector

EN 62208 Empty enclosures for low-voltage switchgear and

controlgear assemblies - General requirements

HD 60364-5-54 Low-voltage electrical installations - Part 5-54: Selection and erection of electrical equipment -

Earthing arrangements and protective conductors

ISO 1000 SI units and recommendations for the use of their

multiples and certain other units

ISO 9001 Quality Systems

ISO 13443 Natural gas. Standard reference conditions

ISO 9951 Specification for turbine meters used for the measurement of gas flow in closed conduits

ISO/IEC 80079 Explosive atmospheres - Non-electrical equipment for use in potentially explosive atmospheres





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BS 5308 Instrumentation cables

BS 5490 Specification for degree of protection provided by enclosure

ISA S5.1 Instrument Symbols and Identification

ISA S5.4 Instrument Loop Diagrams

ISA S84 Functional safety: Safety instrumented systems for the process industry sector

API RP 520 Sizing, Selection, and Installation of Pressure Relieving

Devices in Refineries, Part I Sizing and Selection, and Part II Installation

API RP 521 Guide for Pressure-Relieving and Depressurizing

Systems

API Std. 526 Flanged Steel Safety-Relief Valves

API Std. 527 Seat Tightness of Pressure Relief Valves

API RP 551 Process Measurement Instrumentation

API RP 552 Transmission Systems

API RP 553 Refinery Control Valves

API RP 554 Process Instrument and Control

ANSI/ASME B1.20.1 Pipe Threads, general purpose (inch)

ANSI/ASME B16.5 Steel pipe flanges and flanged fittings

ANSI/ASME B16.36 Orifice Flanges

ASME/ANSI B31.3 Standards of Pressure Piping

ANSI/FCI 70.2 Standard for Control Valve Leakage Classification (Fluid Control Institute)

ANSI MC 96.1 Temperature measurement, thermocouple

ASME PTC 19.3 Temperature Measurement Instruments and Apparatus





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ASTM D2843 Standard Test Method for Density of Smoke from the

Burning or Decomposition of Plastics

2.2. General requirements for field instruments

2.2.1. General

a) This document gives basic requirements for the application of field instruments and

identifies the major systems to be provided for the control, monitoring and safeguarding

and operations of the packaged unit.

b) The established engineering philosophy for the plant shall be followed in the engineering

of the instrument and control systems for package units. Special attention must be given to

the compatibility of equipment/materials obtained from various sources, particularly in relationship to interfacing package unit instrumentation and systems within the plant.

c) Instrument systems will generally be based upon proven electronic technology. Digital electronic systems will employ standard hardware and software. Customisation beyond the

user level will be minimised. Specialised equipment shall be selected based on the

following guidelines:

- only proven equipment which has been successfully used in similar applications shall be short-listed;

- the more sophisticated devices shall be carefully reviewed to ensure that their

disadvantages have been identified and do not become apparent only after

installation, commissioning, operation and maintenance phases; e.g. limitations on cabling lengths, specialised cabling, complex set-up and commissioning

requirements which require specialised equipment, and require intervention by

vendor personnel for operation and maintenance.

d) Use of any field instrument that requires deviation from or relaxation of any standard, or

requires specialised cabling or installation methods, is not permitted, unless agreed by the

PETROM/Purchaser.

e) Instrument design will aim to offer a cost-effective solution that is fit-for-purpose for the

operational and safety needs of the project.

f) As far as practically possible, variations in the selection of controls and instruments for the

plant and for packaged unit used in the plant shall be kept to minimum. Standardising

instrumentation throughout the plant reduces maintenance costs and spare parts inventory. Safety is also promoted because of operations and maintenance familiarity with

the instrumentation. Therefore, the vendor package list of proposed manufacturers and

models of instrument and control equipment shall be subject to PETROM/Purchaser

approval.





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g) Instruments shall fail to a defined failsafe position upon component, signal, or utility

failure.

h) All instrumentation equipment to be installed in classified areas will be supplied complete

with relevant certification issued by a recognized institute and be in accordance with the

installation requirements, as defined by EN 60079 - Explosive Atmospheres, ISO/IEC 80079

Explosive atmospheres - Non-electrical equipment for use in potentially explosive atmospheres and EN 13463 Non-electrical equipment for use in potentially explosive

atmospheres.

i) All SIL classified instrumentation used in Safety Instrumented Systems shall be supplied

complete with relevant certification issued by a recognized institute.

j) Selection of the instruments explosion protection shall be made as per provision of RO-EP-SR-STD-001-01-E Company Standard for Selection of Ex Equipment.

k) Galvanic isolator protection devices will be used for intrinsically safe installations, unless

specific field instruments require Zener diode barriers in order to function correctly.

l) The instrumentation main data shall be shown on the individual instrument Data Sheets.

m) All the materials used shall have characteristics suitable for the operating data and

ambient, as specified on the individual Project Data Sheets. Field instruments utilised in

Sour Service require special attention to be paid to instrument diaphragms, to prevent

corrosion and hydrogen penetration. Material for impulse lines, manifolds, instrument pressure bodies for sour service shall be in accordance with the project material selection

philosophy. In addition, process instrumentation and analysers shall have drain and vent

ports tubed to closed drain and vent/flare headers, to divert any released fluids to safe

disposal routes.

n) All holes cases and the attachment for instrument connection shall be protected with plug

and clearly marked for identification purposes.

o) The instruments and their accessories requiring electric power supply shall be suitable for

the feeding specified on the individual instrument Data Sheets.

p) The instrument and their accessories requiring pneumatic feeding shall be suitable for

feeding with instrumental compressed air at the pressure specified on the individual

instrument Data Sheets.

q) The design life of field instrumentation shall be 25 years minimum. The design life of

control systems shall be 25 years minimum. This will be based on the following

prerequisites: - maintenance and support of the system will be available for this duration;





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- the entire system, including all sub-components, shall facilitate upgrade and are

selected from recognised manufacturers with a proven track record of system

maintenance and essential upgrades.

r) All instrumentation connected to process lines and equipments shall be in compliance with

European Pressure Equipment Directive 97/23/EC (PED) and all instruments to be installed

in a hazardous area meet all the relevant requirements of the ATEX Directive (94/9/EC) and

have the symbol clearly fixed to indicate compliance. All the electronic instrumentation

shall comply with Electromagnetic Compatibility (EMC) and radio frequency interference

(RFI) requirements in standard EN 61000 or similar applicable standard. Compliance must

be demonstrated by way of testing and/or certification performed/issued by recognised institutes.

2.2.2. Environmental conditions

a) The field instruments shall be erected and function in a temperate continental climate specific to Romania. It shall be designed as to be able to function continuous indifferent of

the season or ambient temperatures.

b) Field devices will be selected to be particularly robust to suit the environment and the hazardous area requirements.

c) Externally installed instrument enclosures and junction boxes will meet environmental

protection level IP65 as defined in EN 60529 - Degrees of Protection Provided by Enclosures (IP Code).

d) Instrument painting shall withstand weather conditions.

2.2.3. Electrical terminal strips

a) All electric connections shall terminate at one or more terminal strips located inside of the

case of each instrument, or in an external container assembled to the case of the

instrument concerned and having the same characteristics.

b) Each individual conductor terminal and terminal strip shall be numbered in accordance and

perfect compliance with the electrical diagrams and drawings.

c) Terminals shall be a type suitable to ensure and guarantee the thorough contact.

2.2.4. Pneumatic and hydraulic connections

a) All outlets relating to connections shall be marked so as to be identified in accordance with the technical documents to be supplied by manufacturer.





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2.2.5. Markings and tags

a) Each instrument shall be provided with corrosion - resistant nameplate, permanently

attached to the instrument body and including: - CE mark;

- manufacturers name or trademark;

- model and serial number;

- ATEX marking and IP degree; - range;

- inlet and outlet connections;

- material;

- working pressure; - any other key details, for example: compliance to NACE MR-0175 (latest edition).

b) Each instrument has to be provided with a dedicated AISI 316L plate showing the instrument tag number according to project.

2.3. Specific requirements for field instruments

2.3.1. Requirements common for all types of instruments

a) The instrumentation shall be according to the P&I diagrams and shall be based on pneumatic, electric and electronic technology.

b) SMART type transmitters are preferred with a 420 mA output signal obtained through a

two-wire system. HART protocol shall be supported. Trip signals for ESD/PSD and Fire & Gas applications shall be derived from analogue 420mA DC signals with the threshold

comparator implemented in controller logic, as far as possible.

c) Voltage signals for switches, solenoids and interlocks will be 24Vdc where 420mA signals

cannot be used. Optical isolation will be used to interface to other control circuits which

utilise Low Voltages, and interposing relays will be used to interface to High Voltages.

d) Unless otherwise indicated on the data sheet, all electronic transmitters shall have an integral

LCD indicator, capable to be configured to read in percentage or engineering units. Where

applicable, the indicator shall comply for the location and hazardous area classification. Only

where required by project P&ID, the electronic transmitter shall have remote mounted indicator (e.g. where the transmitter is not visible from normal viewing location).

e) Redundancy (dual control) shall be used for those controls which are critical to production continuity and safety level.

f) All instruments shall have the minimum degree of protection for field mounted

instruments/panel enclosures, when containing electric components, of IP65 according to EN 60529.





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g) As a minimum, AISI 316L material shall be employed for the instrument internal wetted

parts and for pressure and d/p transmitter bodies. Monel, Hastelloy, duplex or equivalent

corrosion resistant material shall be employed for instrument and valve wetted parts if Chlorides and/or CO2 / H2S / H2O / SO4

2 are present in the process. Physical and chemical

process fluid composition shall be analyzed.

h) Instruments shall normally be located as close as possible to process take-offs. All instruments and process take-offs shall be accessible from grade, platforms, walkways or

fixed ladders. Instrument process connections shall be as short as possible, self-draining if

on gas, sloped to the instrument when on liquid. Where these arrangements are not practicable, catch pots and vent/drain valves shall be provided.

i) Instrument process and pneumatic lines shall be made by using seamless tubing and twin-

ferrule compression fittings, throughout the whole project. Tubing material shall be AISI 316L as a minimum unless process fluid conditions justify a higher specification. Tubing

wall thickness shall be selected according to the maximum design pressure. A minimum of

10mm tubing shall be used for process impulse lines.

j) Instrument pneumatic signal lines and supply lines from air headers shall be AISI316L

Stainless Steel.

k) Suitable support clamps shall be used to ensure that galvanic corrosion between mild steel

and stainless steel does not occur.

l) Instrument electrical connections shall use steel-wire armoured cables and certified cable glands. Cables shall be fire retarding type (IEC codes) with toxic gas low emission in

accordance with cable specifications. Wire cores shall not be less than 1 mm2.

m) Cables trays will be prefabricated type in AISI 316L. As far as practically possible, the cables trays shall be segregated for cables type: power cables / signal cables / IS cables.

2.3.2. Pressure and differential pressure instruments

a) General - Pressure and differential pressure instruments will fall into four groups: transmitters,

direct reading instruments (local gauges), switches and local controllers;

- Pressure instruments measuring absolute pressure shall have compensation for barometric pressure changes;

- Pressure instruments used on vacuum service shall have under range protection of full vacuum;

- Generally, the following measuring shall be used:





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i. bourdon-type, for a wide-range of pressure services (they will normally be

used for pressure gauges, repeaters and local controllers);

ii. diaphragm and bellow elements used for low pressure local measurements; iii. diaphragm generally used for pressure transmitters;

iv. diaphragm seals will be generally used on liquid hydrocarbons pressure

connections, where the presence of paraffin may lead to solids formation.

- Fluid filled manometers shall not be used for process measurement services;

- Where seals are required on corrosive or solids type processes they shall be suitable for the process fluid and be equipped with armoured capillaries; or be directly

mounted on the vessels via flanges.

b) Local indication

- Local pressure measurement devices will be Bourdon tube type pressure gauges. The dial shall be of minimum 150mm (160 mm preferred) in diameter for process

monitoring. Smaller sizes may be used on local panels, and instrument air

regulators. Other sizes will be considered for special services. The dials shall be engraved black on white background;

- Gauges shall be safety pattern type armoured glass and blowout discs. All gauges

installed in applications of 10 barg and above shall be full safety pattern fitted with shatterproof safety glass. Gauges below 25 barg range shall have a safety blowout

disc in the back. Gauges for 25 barg and higher service shall have a solid front and

blowout rear;

- Pressure gauges shall be suitable for pressures of 1,3 x maximum stated design

pressure. Over-range devices shall be fitted where necessary;

- The gauges shall have a minimum accuracy of 1% at full scale;

- Pressure gauges are to be pulsation resistant (using pressure snubbers) and vibration resistant (using glycerine/silicon oil as filling liquid), where necessary.

Wetted parts shall be AISI 316L stainless steel as a minimum;

- Siphons shall be employed when required by process conditions (generally on

steam and high temperature services);

- Gauges shall be mounted on a close-coupled 2-valve manifold or on needle gauge valve isolation and a bleeder plug for gauge venting purposes (block & bleed);

- Pressure gauges will be line mounted on services as close as practical to all pressure transmitters, switches and local controllers;





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- Pressure and DP gauges shall be installed at points that can be viewed by the

operators. Remotely mounted indicators may be used for pressure measurements in

inaccessible plant areas;

- Pressure and DP gauges shall be ranged so that the normal operating pressure is

read in the middle third of the span. Ranges shall be selected from the standard list

in EN 837;

- Differential Pressure Gauges with integral switches (as required) shall be equipped

with differential pressure sensing bellows. Wetted materials shall be AISI 316L Stainless Steel as a minimum;

- Gauges shall be supplied with NPT male process connection;

- When a diaphragm seal is required the pressure gauge shall generally be of the

direct mounted integral / diaphragm type without capillaries.

c) Transmitters - Pressure transmitters will be Smart electronic type with AISI 316L stainless steel

wetted parts as a minimum or, if dictated by the process, an alternative material

shall be agreed with the purchaser. Carbon steel shall not be used.

- Electronic Pressure & DP Transmitters shall provide a minimum accuracy of 0,5%;

- Pressure and Differential Pressure Transmitters shall be suitable for a process

connection of NPT-M;

- Differential Pressure Transmitters shall be mounted on a close-coupled 3-valve

manifold as a minimum (5-valve manifold preferred). Pressure transmitters shall be

mounted on a close-coupled 2-valve manifold. All manifolds shall be of AISI 316L

stainless steel construction as a minimum;

- Remote mounted transmitters shall be suitable for 2 pipe mounting via the close

coupled valve manifold, unless otherwise specified on the data sheets;

- Pneumatic transmitters will be force-balanced type. The output signal shall be from

0,2 to 1 barg, with 1,6 barg air supply.

d) Controllers

- Local controllers, either direct and/or receiver type, are to be used generally for less

important controls;

- The measuring ranges shall be selected in accordance with the Manufacturers

standards; the span shall be reduced as much as allowed by process requirements

and by the use of suppressed ranges, if required.





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e) Switches

- Pressure and DP switches shall be used by exception only where continuous

measurement from a transmitter is not practical or necessary or in simple on-off controls services. Preferably, they shall not be used in ESD/PSD and Fire & Gas

applications;

- Switches shall have a minimum of type AISI 316L stainless steel wetted parts with hermetically sealed Single Pole Double Throw (SPDT) electrical contacts. The switch

shall be in the closed position when the process condition is in the Normal

Operating Range;

- Conventional-type electrical pressure switches may be used as interlocking

functions within package installations.

2.3.3. Flow instruments

a) General

- Generally, for flow rate measurements shall be carried out by means of differential

pressure method, generated via orifice plates, pitot, venturi, or v-cone where turndown ratio is not more than 3 to 1. Reference shall be made to EN ISO 5167 -

Measurement of Fluid Flow by means of Differential Devices;

- Generally, square edge orifice plate with concentric entrances and flange taps and / or carrier ring shall be used. For critical duties the orifice plates shall be removable

under pressure, as indicated on the specific project P&IDs;

- The allowable Beta ratio shall be 0,7 maximum and 0,2 minimum;

- Orifice plates shall dimensionally conform to and be installed to EN ISO 5167 (latest

edition);

- For Orifice plates, vent and drain holes will only be considered if the process fluid is

clean and the orifice bore is greater than 25mm. For orifice plates, minimum bore

size shall be 8mm. Orifice plates in lines less than 2 nominal size shall either have the line adjacent to the orifice increased to 2, or a 1 or 1 1/2 meter run shall be

used;

- All wetted parts shall be AISI 316L stainless steel as a minimum, unless the process

fluid requires higher quality materials;

- Orifice flanges materials shall match the relevant piping specification. Flange taps connection shall be in accordance with ANSI B16.36;

- Each orifice plate shall be provided with a tab handle that is clearly visible in the final installed position. The tab will be stamped, or deep engraved, on the upstream





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face with UPSTREAM, the tag number, orifice plate material, measured bore and

the I.D. of the pipe. The tab shall also be in line with the drain or vent hole, when

provided;

- The flow factors will be expressed in the following units:

i. Gas: Energy kWh/MJ; Nm3/h, referred to a 1,013 bar pressure and a 0C

temperature; Sm3/h, referred to a 1,013 bar pressure and a 15C temperature; ii. Liquids: m3/h, as referred to a 15C temperature.

- The preferred meter-range will be 2500 mm H2O; the alternative meter-ranges are: 125, 250, 500, 625, 1250, 5000, 6000, 10000 mm H2O.

- Specific requirements may call for the usage of one of the following flow

instruments: i. quick-replacement type calibrated orifice measuring elements; these shall be

used for measuring ranges exceeding the allowable rangeability for one

single plate;

ii. either Pitot tube or multihole Pitot tubes measuring elements; their calculation and application ranges shall comply with the Manufacturers

standards;

iii. Coriolis meters, Turbine meters, Vortex meters or positive displacement meters will be used on liquid service where a greater turndown and accuracy

are required. Vapour eliminators, where required, will be installed upstream

of the measurement device;

iv. vent / flare gas flow measurements shall utilise time of flight ultrasonic flowmeters for high accuracy and reliability. Where lower accuracy may be

acceptable variable area meters may be used providing an interface to PCS

system is available for the meter concerned;

v. magnetic flow meters may be considered for conductive fluids, where a low-pressure drop is required and/or where corrosive fluids are involved;

vi. for low flows in small lines, variable area flow meters with magnetically

coupled indicators (where necessary) will be used.

b) Flow metering purposes

- Metering is performed to varying purposes having the following degrees of

uncertainty: i. Well Testing - testing normally refers to the assessment of the volumes of

fluids produced from wells. This assessment is performed by individual

measurements of the 3 phases from a test separator, or by in-line multiphase

flowmeter. The test results are used for long term reservoir management, and also for short to medium term planning or reporting of the production

from the facilities. If not otherwise stated, the accuracy requirements shall be

in the order of 3 percent or better for net oil and 5 percent or better for gas;





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ii. Operational Standard for optimisation of processes for long term economic

benefit and the protection of the environment. Typical accuracy requirements

for the overall operational metered values shall be in the order of 10 percent or better;

iii. Allocation Standard - for allocation of production from facilities that produce

into common trunk line, so that the production will be properly attributed to

a source. As the measured values are not required for custody transfer from one party to another, the accuracy and uncertainty requirements are not as

stringent as those for custody transfer metering standards. Typical

uncertainty for the overall allocation metering values shall be in the order of 5 percent or better;

iv. Fiscal/Custody Transfer Standard - for fiscal/ custody transfer from one party

to another, for the verification of quantities transferred from one party to

another. The final metered value may be expressed in terms of volume, mass or energy terms. Typical uncertainty for the overall Custody metered values

shall be in the order of 1 percent or better.

2.3.4. Temperature instruments

a) General

- Temperature measurements may be made by Resistance Temperature Devices

(RTDs), thermocouples, filled bulb systems, or bimetallic thermometers.

b) Local indication

- Local thermometers shall be bimetallic with minimum 150 mm (160 mm preferred)

dials and stainless steel cases. Other sizes will be considered for special services;

- Thermometers will be mounted on services close to all temperature transmitters,

temperature switches and local controllers. Thermometers will be installed at points

that can be viewed by the operators;

- Thermometers shall have a spring mounted any angle head to allow viewing

access from acute angles. Remotely mounted indicators will be used for

temperature measurements in inaccessible plant areas;

- Scale graduations, zero adjustment and over-range protection shall be

manufactured standard, with accuracy to within 1% of span. Dials shall have black graduations on a white background;

- Filled systems may be used for local temperature indicators or where provided as

part of a mechanical package Vendors standard supply.

c) RTDs - The preferred method of temperature measurement shall be via RTDs unless the

process temperature dictates otherwise. Temperature transmitters will generally use





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three-wire platinum RTD elements with a resistance of 100 ohms at 0C and a

temperature coefficient of 0,385 ohms per degree Celsius (PT100), in accordance

with EN 60751. Temperature compensation on custody transfer metering measurements will use four-wire RTDs with direct input to flow computers;

- RTDs will normally be connected to temperature transmitters. Machine monitoring

temperature sensors may however use direct RTD inputs to a multi-point temperature reading device;

- All connections between thermoresistances and receiving instruments will generally carried out by means of a 420 mA transmitter, so as to make the connections

between thermoresistances and Control Room or local Unit Control System by a 2-

wire transmission system;

- Duplex sensors may be employed where replacement of the failed unit may be

difficult due to access or prolonged shutdown of packaged equipment is not

acceptable.

- Thermoresistances shall be used for narrow spans and whenever an accurate

measurement is required;

- Temperature Transmitters for RTDs shall have upscale burnout. Electronic

Temperature Transmitters shall provide a minimum accuracy of 0,5%; d) Thermocouples

- Consideration shall be given to the use of thermocouple sensors only where the

temperature range falls outside that which can be achieved by using RTDs;

- The thermocouple type shall be selected in function of the operating temperature

range to be measured. According to the EN 60584 and ANSI MC 96.1 codes as far as

possible it shall be K type;

- The measuring junctions of the thermocouple shall be insulated;

- Thermocouple shall be mineral insulation type and shall be provided with stainless steel external sheathing;

- Thermocouple construction features shall usually comply with: i. standard covering mineral oxide insulation type;

ii. ANSI MC 96.1 Code.

- All connection between thermocouples and receiving instruments will generally be carried out by means of a 420 mA transmitter, to make the connection to the

control room or packages local control system by a 2-wire transmission system.





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Temperature Transmitters for thermocouples shall have upscale burnout. Electronic

Temperature Transmitters shall provide a minimum accuracy of 0,5%;

- All short connection between thermocouples and PLC shall be provided with

balance rope;

- With the exception of those particular cases called for by either mechanical and/or

process requirements, duplex thermocouples located within the same thermowell

are not to be used on the following applications: i. control system;

ii. safety system.

e) Switches

- Temperature switches shall be used by exception only where continuous measurement from a transmitter is not practical or necessary or in simple on-off

controls services. Preferably, they shall not be used in ESD/PSD and Fire & Gas

applications.

- Switches shall have hermetically sealed Single Pole, Double Throw (SPDT) electrical

contacts. The switch shall be in the closed position when the process condition is in

the Normal Operating Range.

f) Controllers

- Self-regulating valves shall carry out local temperature controls.

g) Thermowells

- Thermowells shall be provided for temperature sensing in process systems for:

i. RTD assemblies; ii. Thermometers;

iii. Test points.

- Thermowells shall be fabricated from bar stock tapered construction, with flanged process connections and threaded sensor head connections. Thermowell

connections to process shall be 1 1/2 flanged;

- Materials for thermowells shall be dictated by the piping specification at the respective measurement location. Thermowells shall be in accordance with piping

interface designs. Installation will meet API RP551 and will meet vortex shedding

requirements as given in ASME PTC 19.3 Part 3 - Temperature Measurement.

- Thermowells for local indicators and transmitters at the same location are to be

identical, both in length and bore size;

- Thermowells shall be made from AISI 316L stainless steel as a minimum;

- The internal diameter of thermowells shall match the sensor elements;





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- The surface of the thermowell shall be smooth and free from burrs and notches;

- Thermowells shall be assessed for resonance effects. Where thermowells are installed in lines subjected to high fluid velocities, combined stress and frequency

calculations shall be carried out to a proven method;

- Thermowells shall be installed such that the element and head can be withdrawn without bending the element, or removing other equipment;

- Thermowells shall be directly installed in lines 4 inches or greater. For lines smaller than 4 inches the thermowell shall be mounted in an elbow, or in a suitably enlarged

section of line.

h) Filling bulbs - Filling-type primary elements will be used for thermostats, local controllers and

temperature self-regulating valves used for less important temperature controls (i.e.

liquid in storage tanks);

- Bulb to thermowell connection shall be made by sliding fitting with ANSI B1.20.1

NPT threaded end;

- Operating ranges and application limits of instruments mercury-filled bulb type and

of thermometers dial type shall be as per manufacturer's standards.

2.3.5. Level instruments

a) General

- Level measurement instruments employed shall include gauge glasses, magnetic

gauges, floats and displacers, differential pressure type, capacitance types, radar

and microwave/radioactive types;

- Consideration shall be taken of fluid type in selecting a measurement type.

Particular attention will be paid to fluid composition, measurement interface and

opacity;

- All external level instruments mounted on the equipment shall be provided with

isolation valves, drain valve and vent valve to allow drainage/venting;

- Level Transmitters shall provide a minimum accuracy of 0,5%.

b) Local indication

- Magnetically coupled level gauges shall be used for local indication on vessels rated

ANSI Class 900 / PN150 and above, where the risk of failure of glass type level

gauges is greater, or when dirty liquid services are involved;





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- For applications with lower pressure ratings and clean liquids, reflex glass gauges

shall be used whereas transparent type level glasses will be adopted for two liquids

interfacing; corrosive properties of the process fluid shall be taken into consideration. The visibility shall cover the maximum operative field of the level

gauge. The glass level gauges shall be provided with isolation valves and safety

ball check;

- These devices will be mounted on bridles attached to the exterior of vessels/tanks.

Maximum gauge range shall be 1600mm. After that, over-lapping gauges shall be

used. Gauges shall overlap the range of level transmitters;

- Device mounting will be such that the level indicators are given good access for

readability and routine maintenance. Acceptable means of access will include

walkways, platforms and ladders depending upon the specific application. Backlighting shall be installed where appropriate.

c) Displacer and float devices transmitters

- Type AISI 316L stainless steel displacers (as a minimum), with external gauges and rotatable heads shall be used with a maximum length of 1524 mm (60). Finned

torque tube extension shall be provided as necessary for high (>200 degC), or low

temperature service (





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- DP transmitters must be capable of withstanding maximum differential in both

directions. Transmitters shall be capable of withstanding over-range pressure on

either side of the capsule at least equal to the body rating, without damage or calibration shift.

e) Radar transmitters

- Radar type gauges will be used for measurements on tall tanks and vessels where appropriate. Radar instruments used in custody transfer allocations shall be of the

high accuracy type, with resolution in millimetres. Stilling wells may be provided as

necessary;

- An integrated tank gauging system may be provided to take an inventory of the

contents of product/storage tanks. Tank gauging systems are addressed in the

following philosophy EP FA IN 06 PH Philosophy for Tank Instrumentation.

f) Microwave/capacitance transmitters

- Microwave / Capacitance type gauges will be used for level measurements where it

is difficult to determine actual levels or interface levels due to emulsions or foaming, using conventional technologies described above.

g) Interface level - For interface level measurement in separator vessels and tanks should be used the

following principles:

i. radar;

ii. ultrasonic; iii. displacer (interface level or density: 0,08 minimum differential).

h) Switches

- Usage of float type level switches shall be carefully assessed. It is rather preferred to use vibrating fork as much as possible;

- When used, external float chamber level switches, shall be used for simple controls only. Switches shall be hermetically sealed single pole, double throw (SPDT) type.

2.3.6. Process stream analysers

a) Process Stream Analysers installed in facilities will be completely automatic and will be purchased from suppliers as total systems including the sample conditioning. On-line

process stream analysers will include the following services:

- density and/or gas composition analysis (as required) on export gas pipeline;

- BS&W analysis on export crude pipeline.

b) Process stream analysers will be equipped with manual sample points for both laboratory

testing and calibration sample injection and in general, be equipped with local indicators.





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2.3.7. Corrosion monitoring

a) Corrosion monitoring will use both sacrificial coupons and electrical probes. Coupons will

be used where an occasional only measurement is required. Electrical probes will be used where regular measurements are needed;

b) Consideration shall be given to both hand-held recording devices and to permanently

connected units. The latter will be used where a continuous measurement is required. 2.3.8. Control valves

a) General

- Modulating control valves shall generally be pneumatically actuated. Control valve signals will be 0,2 to 1,0 barg. Electro-pneumatic positioners shall be installed to

provide local feedback control where necessary. Selected positioners will be the

Smart type;

- In areas where Instrument air is unavailable control valves will utilise electric

actuators;

- Conventional control valves shall generally be installed in a horizontal position with

the actuator above the valve body. Where solenoid valves are used for intercepting

the pneumatic signal to the control valve actuator, the tubing between the two

devices shall be as short as possible and the solenoid valve shall preferably be installed directly on the control actuator;

- All the pneumatic tubing and fittings shall be in AISI 316L stainless steel;

- The noise level of the valves shall not exceed 85-dB (A);

- Minimum flange rating shall be ANSI Class 150/PN20;

- It is possible that a single control valve manufacturer will not have the correct valve

for every application. Severe service conditions may require customisation from a

specialised vendor.

b) Valve leakage

- Valve leakage specifications and classes will be in accordance with ANSI/FCI 70.2. Class IV will be specified for general services. Class V or VI is to be specified for tight

shut-off applications.

c) Valve sizing - Valves will normally be sized for 80% open at maximum flow and for 15% open at

minimum flow. Normal pressure drop will be 33% of the total process system

frictional drop;





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- Control valves shall be in accordance with Cv/Kv standards. EN 60534-1 calculation

method shall be applied;

- Clutched type solid hand wheel manual overrides will be provided where block and

bypass arrangements prove prohibitively expensive and where the line can be

blocked without shutting down major processes and jeopardising safety.

d) Valve accessories pneumatic

- Where utilised, valve accessories will use a 0,2 to 1,0 barg pneumatic signal format.

Each air-consuming valve will be provided with its own independent filter regulator. Current to pneumatic (I/P) converters shall be used to convert electronic signals to

pneumatic signals for control valve and damper actuation.

2.3.9. Self-contained regulators

a) Self-contained regulators will be used for simple processes (utilities) and where

approximate control only of the process parameter is required. Valve materials will be

equal or better the relevant piping line specification.

2.3.10. ESD/PSD & BDV valves

a) General

- ESD/PSD valves shall be provided and designed according to the project

philosophy;

- SDV valves shall be provided and designed failed closed upon loss of air or

hydraulic pressure;

- BDV valves shall be provided and designed failed open upon loss of air or hydraulic

pressure;

- Full bore style shall be applied for piggable lines and blow down valves and when process specifications require a low pressure drop. Valve style, material and

technical requirements shall be in conformance with the Std. Specification indicated

in the technical piping class Spec;

- The valve style shall normally be trunnion type, double block and bleed. Valves with

a size equal or greater than 2 for hydrocarbons service shall be FIRE SAFE, in

according to EN ISO 10497;

- Actuators for shutdown valves will be specified by the Instruments section, while

the valves shall be specified by the Piping section, in accordance with the relevant

piping line specification;





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- In some cases individual valves may be under the control of both the PCS and the

ESD/PSD systems. In such cases separate solenoid valves will be required for the

individual PCS and the ESD/PSD systems, connected in series along the valve actuator air supply line. The solenoid valve under control from the ESD/PSD system

will be installed closest to the valve actuator. The solenoid valve or current to

pneumatic transducer under control from the PCS will be installed upstream of the

ESD/PSD system solenoid;

- Partial stroke testing of valves in safeguarding applications shall be considered in

order to test the integrity of the system. These techniques shall be applied, based on the outcome of the Safety Integrity Level classification.

b) Pneumatic actuators

- Shutdown valves shall generally be pneumatically actuated. Generally, single acting,

spring return, piston type actuators shall be used. However, this will be reviewed after valve size and torque requirements have been established;

- Type orientable single acting piston shall be used for size valve





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- The actuators must be supplied with the equipments, accessories and relative

connections necessaries to implement the control circuit required in the Project

Technical Data Sheet;

- All hydraulic circuits shall be implemented with AISI316L SS tubing and

compression fittings;

- Valve manufacturer is responsible for the calculation of the applied force, of sizing

of the supporting structure and of the correct sizing of the actuator. Actuator shall

be sized including a 1,5 safety factor. 2.3.11. Motor operated valves

a) Motor operated valves (MOVs) shall have the capability to be controlled locally or from PCS

system. These valves will be connected back to the PCS for monitoring of valve status on operator station;

b) Normally, these valves shall not be used in safety services unless they are provided with some means of safety elements that will make the valve to turn to a safe position, either

close or open;

c) Typically, MOVs shall be used as switching valves (for e.g. on manifolds), or where valves are not normally accessible to Operators (are in remote locations) or for large valves where

manual operation is not practical.

2.3.12. Pressure safety valves

a) Pressure relief valves

- There will be four basic types of pressure relief valves used. These are as follows:

i. pilot operated relief valve;

ii. conventional spring type relief valves; iii. balanced bellows spring type relief valves;

iv. pressure/vacuum devices for protection of low pressure storage tanks where

no atmospheric vents exist.

- Safety and relief valves are to be in accordance with API RP520 and RP521.

Pressure/Vacuum devices for low-pressure storage tanks will be sized in accordance

with API 2000.

- Pilot-operated relief valves are to be used for clean gas service or clean liquid

service, where the set point is less than 10 percent above the operating pressure or where the total backpressure downstream of the valve exceeds 10 percent of the set

pressure. Pilot relief valves will be used only where the pilot valve is unlikely to be

subject to freezing, hydrates or accumulated foreign matter. No flow pilots will be

preferred.





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- General conventional relief valves will be used for liquid, gas or thermal relief

service where limited backpressure exists downstream of the valve.

- Balanced safety relief valves will be used in liquid service where the total

backpressure downstream of the valve exceeds 10 percent of the set pressure.

Bellows balanced safety relief valves may be used where it can be demonstrated

that the bellows will not be subject to rupture due to ambient temperature conditions or excessive use.

- If dual pressure relief valves are installed in a redundant configuration, an interlock system shall be provided to ensure that one valve is always on line.

b) Rupture discs

- Rupture discs will generally be the reverse buckling type. They will be applied to: i. accomplish a fast response time, which cannot be achieved with a relief

valve. This could be required to cope with a sudden gas breakthrough due to

a heat exchanger tube burst or malfunctioning of a level control valve into a

liquid filled system; ii. prevent relief valves in vacuum service from drawing gas or air back into the

process;

iii. protect relief valves from being in continuous contact with a corrosive or solidifying process fluid;

iv. prevent leakage of toxic substances through the relief valve.

- If a rupture disk is installed upstream of a relief valve, pressure alarm (in pressure service) or a pressure gauge shall be provided between the disk and the relief valve.

This will give an indication when the rupture disk has burst. The burst pressure

tolerances shall be evaluated and sufficient margin allowed between the burst

pressure and the relief valve set pressure.

- Two bursting disks shall not be installed in series to provide protection against

fatigue and creep.

- Safety valves, except for thermal expansion valves, shall be sized in accordance with

API RP 520. Dual PSV installation shall be mechanically interlocked.

2.4. Requirements for Unit Control Systems for packaged units

2.4.1. Field mounted/ skid mounted unit control panels may be provided for packaged units.

Main equipment packages such as compressors, turbines etc may require dedicated Unit Control Systems that perform management and monitoring of the system to perform the

complete control as well as the associated logic.

2.4.2. The Unit Control Systems shall be interfaced to PCS system via dual redundant configuration data interfaces for remote monitoring and control. Shut down signals or





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commands activation related with the Emergency Shut Down (ESD) system shall be

hardwired type.

2.4.3. Generally, there will be a local emergency stop button on all control panels.

2.4.4. Smaller packages may have their controls implemented in the PCS or ESD as appropriate.

The requirements will be further reviewed and defined in the Detailed Design stage.

2.5. Technical requirements for instruments utilities supplies, cabling systems and cabinets

2.5.1. Electrical power

a) Power supply and distribution will be in accordance with specific Project Electrical Design Philosophy.

b) The power supply voltage for field instruments will be standardised at 24 Vdc. However,

other direct current or alternating current supplies will be provided as necessary for specialised instruments.

c) Generally, field instruments shall be loop powered by the systems that they are connected to, via the 2 wire loop.

d) However, certain instruments may require separate power supply connections, via an

additional core in the cable (e.g. IR gas detectors), or a separate power supply cable (e.g. vortex, ultrasonic, magnetic flowmeters, analysers). The power from the system for the

loop will be disabled accordingly.

2.5.2. Air supply

a) Instrument air supplies will be free of oil, moisture and dust.

b) The Instrument air pressure shall normally be 6 barg, with maximum operating pressure of

8barg (design 10barg) and minimum of 4,2 barg.

c) The instrument air supply pressure at the various facilities will be monitored by the ESD

system to initiate an orderly shutdown in the event the pressure drops below a minimum

limit. This is in order to prevent erratic operation of the spring actuated shutdown valves. The instrument air buffer receivers will be sized for sufficient air to allow for a safe plant

shutdown.

d) Where there is no instrument air supply, hydraulically actuated valves shall be considered.





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2.5.3. Cable routing

a) Cable routings for the facilities will be laid in cable trenches or overhead cable racks/trays.

The actual configuration and routings will be determined during detail design stages, when information on local conditions and process package configurations are available.

b) Intrinsically Safe and non-Intrinsically Safe cables shall be routed in separate cable trays.

Where this not practicable, and both types of cable need to share the same cable tray, divider plates shall be installed to segregate the two types. Common routing of control and

power cables shall be avoided. Control cables and power cables shall be routed in separate

cable trays with a minimum distance of 150 mm between them.

2.5.4. Cables

a) General

- Single pair copper cables will be utilised for connecting field instruments to field

junction boxes and multi-core copper cables from the field junction boxes to the marshalling cabinets. Multi-core copper cables will be utilised for short haul data

links between control systems.

- Cables for field instruments will be manufactured to IEC 60331 for fire resistant and

EN 60332 for flame retardant properties. The cables will be composite multi-core

construction, with solid conductors for light current application, or multi-strand for

heavier current applications. The cables and cores will be sized and selected for the appropriate duty.

- Signals will be protected against RFI through the application of individual or

collective screens.

- Field cables will be mechanically protected against physical damage through the

use of embedded steel wire armouring, braiding or tape. - Specialised cables such as thermocouple extension, and system cables for

interconnection between cabinets will be utilised as appropriate.

- The field circuits in the marshalling cabinets shall be linked to the control equipment in the system cabinets by multi-core system cables, which shall have plug and

socket connections.

b) Specific characteristics

- The cables shall have at least the characteristics listed here below:

i. resistance to environmental conditions specified, in particular the test

methods for temperature resistance stated in EN 60811; ii. resistance to hydrocarbons in accordance with the tests stated in EN 60092;

iii. resistance to mineral oil immersion and ozone in accordance with the tests

stated in EN 60811;





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iv. non propagation of flame (self-extinguish and flame retardant), in accordance

with the tests stated in EN 60332;

v. fire resistance, if required, in accordance with the tests stated in EN 60331; vi. low emission of corrosive and toxic gases, in accordance with the tests

stated in EN 60754;

vii. low emission of opaque fumes, in accordance with the tests stated in ASTM

D 2843; viii.mechanical protection by metallic armour made in galvanised steel tape or

galvanised steel wire braid.

- Any deviation from these requirements shall be agreed in writing by the PETROM/Purchaser.

c) External sheathing

- The cable shall be covered by an external sheathing having the same characteristics of the internal one. The external sheathing shall be identified by a different colour:

i. for IS plants: light blue RAL 5015

ii. for power supply systems: black

iii. for all others plants (except IS): grey iv. for thermocouples: according to EN 60584-3

- If required, different external sheath colours shall be provided for cables for fire & gas detection systems.

d) Cable glands

- Entry into instrument housings and junction boxes will be via cable glands. Where

cable glands are intended for use in a Hazardous Area or where specified, cable glands shall be certified by a recognised ATEX Testing Authority.

- Entry into containers or cabinets will be via certified transit frames.

e) Cabinets

- Cabinets for housing instrumentation and control systems installed inside buildings

will be standard vendor supplied cabinets, suitable for mounting equipment in air-conditioned environments.

- Cabinets which are required for mounting in outside areas (if any), shall be

equipped with sunshades to protect against solar radiation. Equipment mounted inside the cabinets shall be rated to withstand the ambient temperature, with

consideration given to the temperature rise due to the internal heat generated.

- Air-conditioned cabinets shall be considered for long-term protection of electronic equipment mounted inside these cabinets. Passive cooling systems will be provided

where air conditioning is not practical.





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2.6. Technical requirements for instrumentation testing

2.6.1. Manufacturers internal test

a) Each instrumentation unit and accessory, which due to its nature requires it, shall be

subjected to manufacturers internal tests.

b) Internal tests shall be done before the official delivery date agreed upon, irrespectively of the official check tests.

2.6.2. Final tests

a) The following final tests are usually provided:

i. visual examination;

ii. dimensional check;

iii. material test; iv. performance test.

b) The relevant internal test certificate shall cover each instrumentation unit.

c) Each internal test certificate shall contain as more details as possible particularly

concerning the operation checks.

2.7. Maintenance in design

2.7.1. The instrumentation shall be designed taking maintainability into consideration by

simplifying maintenance and reducing maintenance costs where practical.

2.7.2. The SMART instruments shall have built-in test and diagnostic facilities with fault

indication.

2.8. Documentation requirements

2.8.1. Each module shall be tagged with detailed product information minimizing the potential for

incorrect installation, operation, or misapplication of a reconfigured instrument.

2.8.2. The deliverables during Front End Design shall be as per agreed project deliverables matrix

and shall include as a minimum the following documents/drawings:

- instrument list;

- instruments data-sheet; - sizing calculation sheets;

- instruments specifications;

- instrumentation philosophies; - instruments layouts;

- cable lists;





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- cable routing;

2.8.3. The deliverables during Detail Design shall be as per agreed project deliverables matrix and

shall include as a minimum the following documents/drawings: - as above;

- instrument detailed specifications;

- general arrangement drawings; - layout drawings;

- termination diagrams;

- loop drawings;

- data sheets; - process hook-ups diagrams ;

- pneumatic hook-ups diagrams;

- hydraulic hook-ups diagrams;

- electrical hook-ups diagrams.

2.8.4. The use of database design tools should be considered where they are deemed to provide

a clear advantage in project design, construction, and package operation and maintenance. 2.9. Certifying authority review requirements

2.9.1. Where required by the certifying authority the following documents shall be submitted as a

minimum for review: - certificates/approvals;

- basis of design document;

- philosophy documentation; - functional design specification;

- P&IDs.

2.9.2. These should be issued to the CA in a timely manner to obtain approval before commencing construction.

2.10. Spare parts

2.10.1. Spare parts shall be considered for commissioning and 2 years of operation. All spare parts shall comply with the same specifications and tests as the original

instrumentation and shall be fully interchangeable with original parts without any

modification at site.

2.10.2. They shall be correctly marked with reference number and the manufacturers part

numbers and shall be properly protected to prevent deterioration during shipment and

storage.

2.10.3. To all spares shall be attached metal plates giving full information for ready identification

including makers name, serial number and purpose. All spares will be inspected before





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delivery. The protection shall be such as to afford avoidance of corrosion and spoilage for a

minimum 3 years after delivery.

3. Responsibilities

3.1. The Contractors/Sub-contractors/Vendors/Manufacturers to comply with the requirements

stated in the current philosophy.

3.2. Facilities Engineers to ensure that the design of the packages conforms to the provisions of the philosophy.

3.3. Project Managers to ensure that the philosophy is distributed to the successful contractors

during project development and execution.

4. Terms and abbreviations

4.1. Into this document it shall be used the following terms and abbreviations:

PACKAGED UNIT Vendor packaged unit is an equipment assembly supplied on skids, or in a framework or housing, that is ready for

hook-up and operation to accomplish a standard process

function. Examples of such packaged unit include turbine

generators, utility service compressors, pumps, dryers, and blowers.

Vendor packaged unit is assembled and tested at the Vendor

site, shipped to the site of operation, and hooked up to the plant or process system, at which point it is ready for

commissioning

TECHNICAL SPECIFICATION Document that describes general requirements and basic data of certain product, assembly or plant

DATA SHEET Issued form specific to a certain product, assembly or plant

that involve also the required data for manufacturing and testing

SMART field devices Transmitters and control valves positioners that incorporate advanced diagnostics and data transmission that allows the

information to be transferred to systems such as Asset

Management Systems for analysis and remote intervention

ESD/PSD Short term for Emergency/Process Shut Down. It is a safety

system that ensure the automate shut down of some

equipment or plant in case of detection of an abnormal functioning situation





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PCS Short term for Process Control System. It is a system that

provide the Operator with a means to operate the plant

safely and efficiently and to alert the Operator to any alarms or events that require attention / action

SCADA Short form for Supervisory Control And Data Acquisition. It

is a computerized system for information collection and processing in real time designated for monitoring and

control by distance of some equipment and plant

ISCIR State Inspection for Boiler, Under-pressure Recipients of

Lifting Units

INSEMEX National Institute for Mining Safety and Explosion Proof

ANSI American National Standards Institute

API American Petroleum Institute

ASME American Society of Mechanical Engineers

IEC International Electrotechnical Commission

EN European Norm

IEEE Institute of Electrical and Electronics Engineers

ISA Instrument Society of America

BSI British Standard Institute

TEMA Tubular Exchange Manufacturers Association

CA Certifying Authority

CE European ID for conformity. Short term of Conformite Europeene

Must The word must is used in case of an legal requirements

Shall The word shall is used in case of an absolute

requirements

Should The word should is used where a solution is

recommended





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May The word may is used where alternatives are equally

acceptable

5. Obsolete regulations

None

6. Supporting documentation

6.1. This document is complemented by the following PETROM and OMV philosophies:

PETROM philosophies

EP FA IN 01 PH Philosophy for Instrumentation and Instrument Air

EP FA IN 02 PH Philosophy for Valve Actuation

EP FA IN 03 PH Philosophy for Flow Metering

EP FA IN 04 PH Philosophy for Process Control Systems

EP FA IN 05 PH Philosophy for Automation, Telecommunication and Security Systems

EP FA IN 06 PH Philosophy for Tank Instrumentation

EP FA IN 07 PH Philosophy for Facilities Emergency Shut Down /

Wellhead Protection Systems

EP FA HA 01 ST Company Standard for Area Classification

RO-EP-SR-STD-001-01-E Company Standard for Selection of Ex Equipment

RO-EP-GE-GDL-001-01-E Guideline for CE marking

EP FA MP 03 TS Technical specification for piping material classes

design according to EN 13480 OMV philosophies

TO-HQ-02-021 Philosophy for Process Control Systems - Onshore

TO-HQ-02-023 Philosophy for Safety Integrity Levels - Onshore

TO-HQ-02-024 Philosophy for Emergency and Process Shutdown

Systems - Onshore





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TO-HQ-02-027 Philosophy for Flow Metering Systems - Onshore

TO-HQ-02-035 Philosophy for Overpressure Protection and Safeguarding - Onshore

TO-HQ-02-036 Philosophy for Flare Relief & Blowdown - Onshore

6.2. Please refer also to the codes and standards listed under chapter 2.1.

7. Distribution list

Projects & Engineering Division Engineering Companies

8. Amendments from previous edition

Current edition Amended chapters Details about relevant amendments

1 New Philosophy Not applicable

9. Annexes

None

ro ep fe in phl 001 01 e philosophy control instrumentation packaged units

Documents