gs ep saf 021 - layout - pogc · gs ep saf 021 layout ... 4. location of the installation ......

Exploration & Production

This document is the property of Total. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.

GENERAL SPECIFICATION

Design of Field Facilities

GS EP SAF 021

Layout

Main Instructor for Derogation: ECI (Design of Field Facilities)

04 10/2009 Sections 2, 5, Appendices A and C updated. Appendix D created

03 10/2008 Complete review and update

02 10/2005 Addition of EP root to document identification

01 10/2003 Change of Group name and logo

00 04/2001 Old TotalFina SP SEC 021

Rev. Date Notes


General Specification Date: 10/2009

GS EP SAF 021 Rev: 04


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Contents

1. Scope .......................................................................................................................4 1.1 Purpose .............................................................................................................................4 1.2 Applicability........................................................................................................................4

2. Reference documents.............................................................................................4

3. Terminology and definitions ..................................................................................6

4. Location of the installation.....................................................................................8 4.1 Choice of a location ...........................................................................................................8 4.2 Impacted area....................................................................................................................9 4.3 Site Contingency Plan .......................................................................................................9

5. General arrangement ..............................................................................................9 5.1 Methodology ......................................................................................................................9 5.2 Unit sorting.......................................................................................................................10 5.3 Unit configuration.............................................................................................................13 5.4 Interconnection units........................................................................................................20 5.5 Location of rooms in the installation ................................................................................20 5.6 Layout of integrated platforms .........................................................................................22 5.7 Temporary facilities..........................................................................................................24 5.8 Future extensions ............................................................................................................25

6. Equipment layout ..................................................................................................25

Annex 1 (Informative) - Methodology to select layout .....................................26

Appendix A - Spacing - Default distances tables .....................................................27

Appendix B - Arrangement of interconnections between units ..............................46 B1. Pipe-racks........................................................................................................................46 B2. Cable routes ....................................................................................................................46 B3. Bridges (offshore only).....................................................................................................46

Appendix C - Equipment layout .................................................................................48 C1. General ............................................................................................................................48





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C2. Wells ................................................................................................................................49 C3. Unfired process equipment..............................................................................................50 C4. Fired equipment...............................................................................................................55 C5. Piping...............................................................................................................................57 C6. Flares and vents ..............................................................................................................58 C7. Storage ............................................................................................................................58 C8. Safety equipment.............................................................................................................59 C9. Buildings ..........................................................................................................................59 C10. Miscellaneous ..................................................................................................................60

Appendix D – Bibliographic references.....................................................................62





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1. Scope

1.1 Purpose This general specification lays down the minimum safety requirements for the layout of installations, both onshore and offshore.

The dispositions of this specification are in accordance with API RP 14J recommendations unless appropriate justification corresponding to COMPANY practices and tolerances is brought.

The main recommendations for the layout of installations and the main steps of the methodology are included in Annex 1 of this document.

1.2 Applicability This specification is not retroactive.

It shall apply to new installations and to major modifications or extensions of existing installations, both onshore and offshore.

This specification does not cover:

• Exploration drilling temporary facilities

• FPSO’s and boats

• LNG plants

• Jetty and shoreline terminals

• Refining and marketing facilities.

2. Reference documents The reference documents listed below form an integral part of this General Specification. Unless otherwise stipulated, the applicable version of these documents, including relevant appendices and supplements, is the latest revision published at the EFFECTIVE DATE of the CONTRACT.

Standards

Reference Title

Not applicable

Professional Documents

Reference Title

API RP 14J Recommended Practice for Design and Hazards Analysis for Offshore Production Facilities





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Regulations

Reference Title

Not applicable

Codes

Reference Title

Not applicable

Other documents

Reference Title

Statement Of Requirements (SOR)

Safety Concept

Operating Philosophy

Total General Specifications

Reference Title

GS EP ECI 001 Reference levels for offshore platforms

GS EP ELE 001 Electrical design criteria

GS EP ELE 079 Electrical apparatus for potentially explosive gas atmosphere

GS EP ELE 364 Electrical installations

GS EP LSO 110 Environmental effects considerations for helidecks

GS EP SAF 041 Technological Risk Assessment Methodology

GS EP SAF 216 Area classification

GS EP SAF 221 Safety rules for building

GS EP SAF 222 Safety rules for turbines, Diesel engines, gas engines and process units in sheltered or enclosed areas

GS EP SAF 227 Safety rules for fired heaters

GS EP SAF 253 Impacted area, restricted area and fire zones

GS EP SAF 261 Emergency Shut-Down and Emergency De-Pressurisation (ESD and EDP)

GS EP SAF 262 Pressure protection relief and hydrocarbon disposal systems

GS EP SAF 321 Fire pump stations and fire water mains

GS EP SAF 337 Passive fire protection: Basis of design





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Reference Title

GS EP SAF 341 Location and protection on onshore hydrocarbon storage

GS EP SAF 351 Escape, evacuation and rescue from fixed installations

GS EP STR 002 Permanent lifting or handling devices for offshore installations

3. Terminology and definitions There are three types of statements in this specification, the “shall”, “should” and “may” statements. They are to be understood as follows:

Shall Is to be understood as mandatory. Deviating from a “shall” statement requires derogation approved by the COMPANY

Should Is to be understood as strongly recommended to comply with the requirements of the specification. Alternatives shall provide a similar level of protection and this shall be documented

May Is used where alternatives are equally acceptable

For the purpose of this specification, the following definitions shall apply (the terms defined in this section are often in bold characters in the text of the specification):

Area (impacted) Area that extends beyond the boundaries of the installation but which is nevertheless affected either permanently by normal operation of the facility (e.g. noise, radiation) or exceptionally by the consequences of an emergency situation caused by a major failure (COMPANY)

Area (restricted) Area within the boundaries of the installation and hence under the control of COMPANY, which is affected permanently by normal operation of the facility (e.g. noise, radiation) or exceptionally by the consequence of an emergency situation caused by a major failure (COMPANY)

Credible event Incident likely to occur within a concerned area. Used for the definition of fire zones. Consequences corresponding to a credible event of a given fire zone shall not impact other fire zones (COMPANY)

Emergency Control Centre

Place where emergency response personnel go to undertake their emergency duties (COMPANY). Equivalent to ISO-definition of Emergency Station

Emergency Response (ER)

Action taken by personnel on or off the installation to control and/or mitigate a hazardous event (ISO)

Equipment Any component or group of components specifically identified and itemised on the P&IDs (COMPANY)

Escape Route Route from an area of an installation leading to a muster area, a Temporary Refuge (TR), an embarkation area and/or means to escape (ISO)





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Escape, Evacuation and Rescue (EER)

General term used to describe the range of possible actions including escape, muster, refuge, evacuation, escape to the sea and rescue/recovery (ISO)

Failure (major) A conceivable incident that can possibly occur on the facility. Used for the definition of the facility restricted area and impacted area (COMPANY)

Fire zone Area within the installation where equipments are grouped by nature and/or homogeneous level of risk attached to them. The partition into fire zones is such that consequences of a fire, flammable gas leak or an explosion corresponding to the credible event likely to occur in the concerned fire zone, shall not impact other fire zones to an extend where their integrity could be put at risk

FPSO Floating, Production, Storage and Offloading system includes, in addition to storage and offloading capability, facilities for receiving crude oil from producing wells and processing it for export by separating water and gas (OGP)

Fuel source Same as ISO definition of "source of release" (API)

General Arrangement (GA)

Also called Overall Plot Plan. Action of sorting and grouping equipment into units, defining their location considering environment, neighbourhood, unit inter-dependence and spacing to match safety and operability requirements (COMPANY)

Hazardous area and zone

A hazardous area is defined as a three dimensional space in which a flammable atmosphere may be expected to be present at such frequencies as to require special precautions for the control of potential ignition sources (IP 15). All other areas are referred to as non-hazardous areas (or safe areas) in this context. In a hazardous area three types of zones (0, 1 and 2) are recognised (IP 15)

Ignition source Source of temperature and energy sufficient to initiate combustion (API)

Installation Technical unit in which dangerous substances are produced, used, handled or stored, including all the equipment, structures, pipework, machinery, tools, private railway sidings, docks, unloading quays serving the installation, jetties, warehouses or similar structures, floating or otherwise, necessary for the operation of the installation (COMPANY from European Directive 96/82/EC, dated December 9th, 1996)

Layout Action of selecting the location of the installation, defining unit general arrangements and placing equipment within units (COMPANY)

Local Authority Organisation, body, office or individual responsible for approving the installation with regards to local applicable regulation and for defining jointly with COMPANY, approving and enforcing the Site Contingency Plan (COMPANY)





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Lower Flammable Limit (LFL)

Lower concentration of gas (by volume and expressed in percentage) in a gas-air mixture that will form an ignitable mixture (API, NFPA)

Site Contingency Plan Plan describing all the measures planned for dealing with the scenarios deduced from the major risks calculated for the installations

Source of release Point from which flammable gas, liquid or a combination of both can be released into the atmosphere (ISO)

TEMPSC Totally Enclosed Motor Propelled Survival Craft: Craft capable of sustaining the lives of persons in distress from the time of abandoning the installation (ISO)

Units Areas within the installation resulting from its partition into a reasonable number of geographical and functional groups of equipment having the same type (hydrocarbon, pressure, inventory, ignition, etc.) and levels (high, medium, low) of risks (COMPANY).

4. Location of the installation The location of any new installation or any major extension of an existing installation shall be approved by COMPANY.

The choice of the location shall always be justified by a supporting dossier as described below, particularly when several locations can be initially envisaged.

4.1 Choice of a location The following surrounding facilities and their foreseeable extension shall be identified:

• Other petroleum or industrial installations

• Access roads, ground, sea (waterways) and air transportation networks

• Electrical power, water, telecommunication, distribution networks

• Presence and density of population, public buildings.

The following environmental conditions shall be identified:

• Soil conditions, relief

• Local specific risks such as seismicity, landslides (either onshore or submarine), floods, sand storms, permanent frost, typhoons

• Meteorological conditions (temperature, hygrometry, sun, rain, wind, snow, ice, fog, lightning)

• Sea conditions (water depth, swell, currents, salinity)

• Cold source vicinity (sea, river, air)

• Protection of nature (site, fauna, flora) and visual impact

• Security risks.





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The Local Regulation in force shall be complied with (e.g. the requirements imposed by the Local Authority).

The different criteria, factors and rankings in the decision-making process shall be recorded. The selection shall be justified in all cases. Special attention shall be given to the selected location when several options can be initially envisaged.

4.2 Impacted area Once a location has been selected:

• The impacted area around the installation is defined taking the major failures scenarios using the consequence analysis methods and criteria as specified in GS EP SAF 253

• Permanent settlements, public places and transport corridors encroaching the impacted area shall be particularly identified and the need to relocate them shall be specifically addressed.

4.3 Site Contingency Plan From the very beginning of this process and before a location is eventually selected, a preliminary Site Contingency Plan is prepared in close relationship with Local Authorities.

It shall be ensured that dispositions it includes regarding communication (alerting neighbourhood and Local Authorities), evacuation, rescue means to public and implementation of mitigation measures are fulfilling Local Authorities’ requirements.

The Site Contingency Plan may also cover areas extending beyond the impacted area but it is not the purpose of the present document to elaborate upon it.

5. General arrangement

5.1 Methodology Different approaches are possible to determine minimum distances between different fire zones and between units within the same fire zone.

COMPANY's practice is to proceed as follows:

• At Preliminary and Conceptual stages, issue a preliminary General Arrangement based on the recommendations provided in various General Specifications, including this one (in particular refer to Appendix A tables and figures), and/or COMPANY engineering expert judgment

• At Pre-Project stage, issue the plot plans and improved partitions between fire zones and units, using consequence analysis software(s) available in-house (refer to GS EP SAF 253)





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• At Basic Engineering stage, issue layouts within units and, if proven necessary, carry-out further consequence analysis and/or a QRA1 to confirm/optimise distances and partition

• At Detailed Engineering stage, incorporate VENDOR data to finalise equipment layouts (refer to Appendix C for equipment location requirement and recommended distances between equipments).

Detailed work on General Arrangement (GA) shall not commence before :

• The location of the installation has been selected (refer to Section 4)

• The restricted area has been defined (as per GS EP SAF 253)

• The installation has been split into fire zones (as per GS EP SAF 253).

GA of any new installation or any major extension of an existing installation shall be subject to approval by COMPANY and shall incorporate all provisions for temporary facilities and/or future extensions.

5.2 Unit sorting

5.2.1 Main Principles

• Fire zones, unit partitions and number of units shall be coherent

• Unit partition: The split into units shall be compatible with the split into fire zones. Each unit is included into one, and only one, fire zone. A unit cannot sit over two fire zones. One fire zone can incorporate one or several units. Units are further divided into pieces of equipment, and bulk. Each fixed equipment belongs to one, and only one, unit. A piece of fixed equipment cannot belong to two units

• Fire-fighting and emergency capabilities: The capability for the active fire-fighting and emergency systems to operate efficiently on the biggest units within their fire zones and with maximum acceptable risk for the assets shall be ensured

• Risk level: Partition should be such that each unit is composed of elements (equipment and/or components) having comparable process risk levels

• Process flexibility and availability: The break-down into units should be such as to allow optimum operational flexibility and required availability. For instance in the case of an installation composed of two separators and two compressors, it shall be assessed whether it is preferable to group them into two identical processing trains comprising one separator and one compressor each, or into a separation unit (comprising both separators) and a compression unit (comprising both compressors). Input for such arrangement shall be provided by the OPERATING PHILOSOPHY

• Asset protection: The split into units shall be such that the risk acceptability criteria set forth in GS EP SAF 041 for assets is complied with

• Interconnection between units: An interconnecting unit is defined only if it links different process units and if it is mainly composed of all-welded piping with few flanges, or single run cables with few junction boxes. A pipe-way within a single process unit or with

1 QRA shall be used only on large projects or when imposed by applicable regulation and in order to keep individual risk within

acceptable limits. In practice QRA shall be carried out by the end of the basic engineering i.e. soon enough so as to allow feed back of its main findings into the layout, if necessary.





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numerous flanges, valves, vents, drains, etc., shall be considered as being part of the unit it pertains to. Offshore, bridges between platforms are interconnecting units

• Sub deluge zones: The possible partition into sub-deluge zones shall also be considered and made compatible with the unit sorting (Refer to GS EP SAF 253).

5.2.2 Group of equipment With reference to API RP 14J, units shall be sorted out into nine different categories called "groups of equipment" (refer to table below) presenting homogeneous risks, both in terms of nature and level.

The objective is two-fold:

(i) Achieve segregation of fuel source from ignition source by separation of equipment

(ii) Define compatibility of units between each-other (refer to Section 5.2.3).

Group Type Main equipment Hazard

T1 Wellhead Wellheads, chokes, wellhead manifolds and headers

Fuel source

T2 Unfired process Manifold and headers, separators, heat exchangers, water treatment, pumps, compressors, unit enclosures, finger type slug catcher, metering

Fuel source

T3 HC storage Storage tanks, sump tanks, produced water treating tanks

Fuel source

T4 Fired process Fired equipment, fired heaters, TEG reboilers

Ignition source

T5 Machinery and power generation

Generators, electric equipment, air compressors, engines, turbines

Ignition source

T6 Buildings Living quarters, technical buildings, maintenance areas and buildings, offices, control room, sewage disposal, water makers

Ignition source

T7 Pipelines and risers Risers, pig launchers, pig traps Fuel source

T8 Vents Fuel source

T9 Flares Including burn pits Ignition source

5.2.3 Compatibility Units are compatible together when they can be located beside each other:

• Either without particular precautions dictated by safety that would come in addition to other considerations such as constraints of construction, operability or maintenance

• Or providing supplementary precautions (e.g. enlarged distance or separation wall) are duly implemented.





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Two units indicated as non compatible shall be located in two different fire zones.

Unit Compatibility T1 T2 T3 T4 T5 T6 T7 T8 T9

T1 Wellhead Y

T2 Unfired process N (1) Y

T3 HC storage (10) N (8) N (2) Y (3)

T4 Fired process N Y (4) N Y

T5 Machinery N (8) Y N Y Y

T6 Buildings N N (5) N (5) N (5) N (5) Y

T7 Pipelines and risers Y Y N (6) N N N Y

T8 Vents (9) N N (7) N N N N N (6) Y

T9 Flares N N (7) N N N N N (6) N Y

(1) Not compatible as a general rule however exception for unfired process units attached to wellhead unit e.g. test separator.

(2) Not compatible as a general rule except (i) unfired process units attached to storage unit e.g. pumping station for hydrocarbon transfer and (ii) small (less than 50 m3) propane storage used in cooling units and providing they are suitably protected (additional distance + embankment).

(3) Liquid hydrocarbon storage is not compatible with liquefied hydrocarbon storage.

(4) Units indicated as non compatible by API RP 14J but considered compatible by COMPANY if sufficient distance is provided (as per Appendix A or consequence analysis as per GS EP SAF 253).

(5) Buildings are not compatible with any other units. This restriction does not apply to technical buildings housing process (hazardous or non-hazardous) or utility.

(6) Not compatible as a general rule but it is tolerated that pipelines (excluding risers, manifolds, pig traps) can cross storage units or flare/vent areas if they are without flange and suitably protected against explosion (from storage units) and radiation (from storage units and flare/vent).

(7) Units indicated as non compatible by API RP 14J but COMPANY tolerates that flare/vent drum and auxiliaries (e.g. condensate pumps, purge/pilot gas skid) are in the flare/vent fire zone providing radiation criteria given in GS EP SAF 262 are fulfilled..

(8) Except for wells with pumping units.

(9) Cold vents (as per GS EP SAF 262) only. Degassing vents (as per GS EP SAF 262) compatible with all other units.

(10) This category includes both liquid hydrocarbon and liquefied HC storage.





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On highly congested installations, and in particular offshore, units cannot always be segregated by position. In order to provide sufficient independence, they shall be separated by passive fire and blast protection that can resist the effects of a fire or an explosion (based on the scenarios retained in the SAFETY CONCEPT and corresponding to the credible events) and conserve the following default fire and blast ratings after the fire or explosion has occurred:

• H-120 (or J-120 if and where relevant) within the impact distance of a process or hydrocarbon storage fire zones and for units necessary for Emergency Response and/or EER

• H-60 (or J-60 if and where relevant) within the impact distance of a process or hydrocarbon storage fire zones for non-EER or non-ER equipment

• A-0 in a non-hazardous area, but in the restricted area

• Blast protection ratings are evaluated according to the congestion within the platform

• No particular requirement outside the restricted area.

5.3 Unit configuration

5.3.1 Objectives Unit configuration shall be such that the main safety objectives listed below are fulfilled:

• Generic for any industrial installation

o To prevent logistics accidents, and in particular to pay attention to security and control of access (refer to Section 5.3.2), traffic (refer to Sections 5.3.3 & 5.3.5) and lifting (refer to Section 5.3.6)

o To ease operability of the installation with a special emphasis on accesses to working areas (refer to Section 5.3.7) and space reservations around equipment (refer to Section 5.3.8).

• Specific to hydrocarbon production, processing and storage installations

o To locate ignition sources and fuel sources with due consideration of wind, in order to prevent ignition after a gas release (refer to Section 5.3.9)

o To locate fuel sources with due consideration of wind, sea swell and current, to minimise the consequences of fires (refer to Section 5.3.9)

o To ease mitigation measures, and in particular facilitate access for Active Fire-Fighting (refer to Section 5.3.10)

o To provide adequate arrangements for safety to life, and in particular EER (refer to Section 5.3.11).

5.3.2 Security and control of access (onshore only) The installation under the control of COMPANY shall be closed to general public access.

The installation under the control of COMPANY shall be fenced. Refer to Figure 1 - Security and access control (typical onshore).





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The installation shall be divided into a general service area and a plant area as defined below:

• The general service area comprises activities in relation with the outside world (T6 classification) and that cannot cause hydrocarbon hazards, such as parking lots, workshops, warehouses, offices, living quarters, control rooms, muster areas, embarkation area, bus stations or helidecks

• The plant area incorporates activities that can cause hydrocarbon or other chemical and ignition hazards, such as well heads (T1); process units, unfired or fired (T2 and T4); hydrocarbon storage units (T3); machinery and power generation (T5); pipelines and risers (T7); vents (T8); flares and burn pits (T9).

Entry point(s) from outside the installation to the general service area shall be located to meet security requirements. Entry points from the general service area to the plant area shall be located to meet safety requirements.

Direct access of public to the plant area shall be made impossible.

Access of public to the general service area shall be made normally possible via one single main entrance with a security check-point.

Other means of access shall be normally closed and limited to exceptional or emergency purposes e.g. exceptional heavy loads, Emergency Response or emergency exits.

The access from the general services area to the plant area shall be limited to authorised personnel only. The access of authorised personnel from the general service area to the plant area shall be made normally possible via a limited number of main entrances, preferably one with a safety check-point.

The other means of access between the general services area and the plant area shall be limited to exceptional or emergency purposes, with the same principles as above.

5.3.3 Access roads (onshore only) Access roads shall be segregated into three categories:

• Outside up to the security check point

• In the general services area

• In the plant area.

5.3.3.1 General for all access roads Access roads shall be practicable all year round and of adequate type for the vehicles that are likely to be used, in particular for the following: overall maximum weight, maximum axle weight, head and width clearance, roadway width and bending radius.

Special consideration shall be paid for snow, ice, defrosting and heavy rains conditions.

At least one access road shall remain passable in any combination of fire scenario and environment conditions.

Provision for the specific risks to the installation and its environment such as cattle guards, illuminating at night or under fog conditions, risk of water flood or heavy rains (e.g. monsoon) shall be considered.





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5.3.3.2 Additional requirements in the installation Inside the installation, the restrictions for traffic use and directions to reach the loading/unloading posts or the parking lots shall be clearly identified and marked.

Access roads shall conveniently stop at the muster areas in the general service area.

5.3.3.3 Additional requirements in the plant area The restrictions for entry into the plant area applicable to all vehicles shall be assessed taking into account type of engine, fuel and exhaust system.

Access ways in the plant area shall provide safe and easy access for any service vehicles (e.g. mobile fire-fighting means, crane or heavy truck), with (refer to Section 5.3.10 & Appendix C1.1):

• Adequate headway and width at overhead pipeline crossing points

• Capacity to bear the biggest load

• Adequate turning bend radius

• Where necessary, protection of access road nearby piping equipment against vehicle collision.

PREVALING WIND

FIRE ZONE #2FIRE ZONE #1

FIRE ZONE #3

HAZARD AREA (no public allowed)

UNIT 11 UNIT 12 UNIT 21 UNIT 22 UNIT 23

UNIT 31 UNIT 32

ACCESSTO PLANT

SECONDARYACCESS / EXIT

NON HAZARD AREA(public authorised)

Warehouse/workshopHigh occupancy bldg.

Safe utilities

hazardous storageload/unload area

Safety fence at edge of restricted area

Saf

ety

fenc

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Sec

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fenc

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MAIN ACCESS / EXIT(security check point)

PLANTAREA

GENERAL SERVICEAREA

Figure 1 - Security and access control (typical onshore)

5.3.4 Boat approach (offshore only) Boat landings shall not be on the same platform side as risers.

Boat landings should not be located above sea lines that are not suitably protected against maximum load impact by boats using the landing.





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Furthermore the boat-landing position shall take into account risks due to:

• Flare, vent and exhaust locations

• Wind, sea swell and current direction (refer to Section 5.3.9).

• Hazardous areas, including when wire-line operations are performed on any well.

The location of the landing should take into consideration the direction of the prevailing wind, swell and/or tidal currents in order to minimise the likelihood of collision by a drifting boat.

Boats should normally approach the boat-landings against swell and current.

Ideally boat landings should be downstream of the most stringent prevailing wind, swell or tidal current (see Figure 2 - Typical layout of offshore fixed platforms) downwind of the platform.

A perpendicular position (see Figure 3 - Typical layout of offshore integrated platform) to the prevailing weather and sea might be acceptable, but there could then be limitations on the operational envelop of the boat.

The position and operation of the boat landing shall take into consideration the possible presence of a jack-up or tender support rig alongside the platform including flaring from the platform, jack-up or tender support rig. Appropriate operational constraints shall be put in place whenever flaring takes place.

Where a boat landing platform location, orientation or approach procedure does not comply with the above, a risk assessment shall be carried out, and a justification dossier produced supporting the reasons why the boat landing does not comply with these requirements.

5.3.5 Helicopter approach Helideck position shall take into account risks due to:

• Flare, vent and exhaust locations

• Wind direction (refer to Section 5.3.9)

• Hazardous areas.

Helicopter should normally approach helidecks into the wind. The 210° approach sector shall be free, up to 1 km away, of any obstacle to air navigation and in particular of any flare, drilling mast/pole, crane and exhaust chimney.

For further details, refer to specification GS EP LSO 110.

5.3.6 Location of cranes and lifting devices Cranes and lifting devices shall be located aside loading/unloading posts.

Loading/unloading posts shall be close to the main ways of access but shall not encroach upon them.

• Offshore and shoreline crane. o Operational swing zones are prohibited above sea lines and risers unless they are

suitably protected against maximum load impact

o The loads shall not pass over supply boats, except for routine loading/unloading operations.





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o The routine operational swing zones of permanently installed cranes shall not pass over equipment containing hydrocarbon unless said equipment has been designed for resistance to impact from loads dropped by the crane or properly protected

o Crane movement above such equipment shall be limited to heavy maintenance activities. In these cases, the equipment shall be depressurised and drained and a specific procedure implemented or a lifting study and a dropped object risk assessment study shall be carried out.

• Onshore, the same recommendations shall be applied regarding swing zones over equipment containing hydrocarbon. Where a mobile crane is given preference over a set of fixed cranes, its possible and foreseeable operational locations shall be reserved and reinforced with concrete slabs. The safe access of mobile crane to its operational spots shall be demonstrated.

In all cases the crane operator shall have view over the whole swing zone and traffic around.

5.3.7 Access to working areas Access arrangement for all routine operations should be straightforward and simple.

Operation and inspection points should be accessible and visible from main floors or aisles, preferably without the help of ladders.

All equipment requiring human intervention (for operation, maintenance, inspection, etc.) with a periodicity of at least once a month should be provided with permanent and fixed access devices.

Equipment, instruments, valves hand-wheels and piping shall not protrude into access ways so as to cause a hazard or to obstruct the escape ways. For further details dealing with the minimum clearances of the access ways, refer to Appendix C1.1.

5.3.8 Space reservations around equipment Provisions shall be made to ensure that all routine operation involving handling of materials and equipment can be conducted in a safe manner.

Where simultaneous operations (SIMOPS) may take place between drilling or work-over and production, sufficient space shall be made available for pipe handling, mud handling, chemical delivery or sludge removal without interfering with the safety of personnel or with the safe operation of the installation.

Space shall also be provided for the lay-down of equipment during maintenance or replacement, particularly for large items, such as heat exchanger bundles, flame tubes, turbine and/or compressor shafts (overhauls).

5.3.9 Wind, sea swell and current Several main criteria shall be considered. Refer to Figure 2 - Typical layout of offshore fixed platforms.

5.3.9.1 Ignition of a gas cloud Flammable gas sources (release sources) shall not be located up the prevailing wind of any ignition source. This general rule may be deviated from in the specific case of integrated platforms (refer to Section 5.6).





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5.3.9.2 Ignition of liquid hydrocarbon spills The potential sources of liquid hydrocarbon spillage from production/processing units (release sources) should not be located up the prevailing wind of any ignition source.

5.3.9.3 Fire escalation Any hazardous area shall be located down the prevailing wind of any hazardous area of lesser danger.

In particular, the accommodations and non-hazardous areas shall be located up (preferred option) or perpendicular (alternative option) to the prevailing wind of hydrocarbon production/processing units.

5.3.9.4 Flares and cold vents Ignited flares are sources of ignition and should not be located down-wind of sources of flammable gas (or should be located far enough from them), except where flare are high enough to avoid any risk.

Conversely, the risk of flame-out where the flares become sources of fuel (i.e. release source) shall be considered.

Cold vents (refer to GS EP SAF 262) are source of release (i.e. fuel source) and could become ignition sources in case of accidental ignition.

As a consequence of the flares and cold vents being both sources of release and ignition, their preferred location is perpendicular to the prevailing wind.

5.3.9.5 Escape, Evacuation and Rescue (EER) EER routes and systems shall be located up the prevailing wind of hazardous areas. TEMPSC which can head for a safe place by their own, should be located up and on the sides parallel to the prevailing wind. Life-rafts best location is on the sides parallel to the prevailing wind (refer to Section 5.3.11 & GS EP SAF 351 for further details).





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LIVINGQUARTERS

UTILITYPLATFORM

PROCESSPLATFORM

BOAT

APP

ROAC

H SE

CTO

R

PREVAILINGWIND

Life raft

Life raft

Life raft TEMPSC

BOAT UNLOADINGPOSITION

Figure 2 - Typical layout of offshore fixed platforms





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5.3.10 Fire-fighting-related requirements The maximum unit size shall be compatible with the maximum fire zone size (refer to GS EP SAF 253 for further details).

Monitors shall either be accessible in case of fire, or alternatively they shall be remote controlled. Monitor control panels shall be shielded from thermal radiation coming from any potential fire.

The access ways shall be designed in such a manner that each unit handling hydrocarbon is accessible over the whole length of its sides, the loop surrounding them shall be connected to the general access system at a minimum of two points distant from one another and preferably from opposite side of the unit.

Access for active fire-fighting shall be possible under any combination of fire scenario and weather conditions. In particular, units shall be convex and should preferably be rectangular.

The layout shall be such that the fire water can be contained, or drained, to preclude any risk of liquid running fire.

5.3.11 Escape, Evacuation and Rescue systems In addition to provisions for normal operation, the layout shall incorporate specific requirements to face an emergency situation.

Escape, Evacuation and Rescue (EER)-related requirements in the SAFETY CONCEPT shall be considered as mandatory for safety to life, and shall prevail over any assets protection, operability or technical constraints for unit layout.

The EER facilities, including temporary refuges, shall be located with due consideration for wind, sea swell and current (refer to Section 5.3.9) in addition to requirement mentioned in GS EP SAF 351.

5.4 Interconnection units Appendix B provides guidelines for the arrangement of interconnections between units such as pipe-racks, cable routes and bridges. It does not deal with other location and protection cases, for which another general safety specification is available:

• ESDV’s (refer to GS EP SAF 253 & GS EP SAF 261)

• Flare network (refer to GS EP SAF 262)

• Fire main ring (refer to GS EP SAF 321).

5.5 Location of rooms in the installation The location of rooms in the installation shall be selected with a particular attention, and shall be supported by a specific justification dossier for approval by COMPANY.

The different rooms in the installation shall be classified either as:

• Technical rooms or

• Control rooms or

• Laboratories (and other rooms containing fuel sources as analyser shelters) or

• Workshops and warehouses or





/64

• Offices or

• Living quarters.

No pipe penetration is allowed inside any rooms if piping contains hydrocarbons or hazardous substances.

No GRP piping transporting water is allowed inside any room if water hammer phenomenon is to be expected.

5.5.1 Technical rooms Technical rooms are not permanently manned and their occupancy is strictly limited to few authorised persons performing controlled activities.

They contain ignition sources (but no fuel source) and therefore they shall be either located in a safe area or constitute a safe area (ventilation/pressurisation with HVAC air intakes in safe area, and air locks) as close as possible from process or equipment (refer to GS EP SAF 216).

Technical rooms that are necessary in Emergency Response or EER operations shall be adequately fire and blast-proofed and shall conserve, after the fire and explosion, their specified fire and blast rating (refer to GS EP SAF 337).

5.5.2 Control rooms Control rooms are permanently manned and their normal occupancy shall be strictly limited to few authorised persons performing controlled activities.

Under no circumstances control rooms shall constitute a Temporary Refuge or the Emergency Control Centre.

Control rooms shall either be located in a safe area or constitute a safe area (pressurisation with HVAC air intakes in safe area and air locks).

Onshore, control rooms shall be at sufficient distance to ensure that consequences (based on major failures as per GS EP SAF 253) do not put their integrity at risk (outside the Restricted Area). Control rooms installed in the Restricted Area and that perform functions that must remain operational for Emergency Response and/or are required to control sustained operation of remote facilities shall be adequately pressurised, fire and blast-proofed and shall conserve, after a possible fire or explosion, their specified fire and blast ratings (same as in Section 5.5.1). In this particular case, they shall be surrounded on all external faces by an area approximately 30 metres wide left totally unobstructed.

Offshore, it is recommended to locate control rooms in the accommodation quarters in order to reduce the exposure of hazards generated by process units.

5.5.3 Laboratories and analyser shelters In the limit of what is technically achievable, laboratories should be located as far as possible from main fuel sources.

Laboratories should be located in a non-hazardous area. If a laboratory is located inside a hazardous area, its HVAC system shall be designed in agreement with the requirements of GS EP SAF 216.





/64

Analyser shelters may be in the immediate vicinity of the units they serve providing they are not used for other duties. Their HVAC system shall be designed in agreement with the requirements of GS EP SAF 216.

5.5.4 Workshops and warehouses Workshops and warehouses can be permanently manned. They constitute premises where, or around which, various uncontrolled hazardous activities may take place (e.g. traffic, hot work).

Onshore, workshops and warehouses shall be located in the general services area (refer to Section 5.3.2).

Offshore, workshops and warehouses should be at sufficient distance of units handling hazardous material so that they are not exposed to a flammable gas cloud at LFL in the case of an incident corresponding to a major failure (refer to GS EP SAF 253). If not possible, they shall be isolated from the rest of the installation by a gas-tight, fire and blast proof partition rated H-120.

5.5.5 Offices2 Onshore offices shall be located in the general service area (refer to Section 5.3.2), away from sources of hazards, at sufficient distance to ensure that consequences (based on major failures as per GS EP SAF 253) do not put their integrity at risk.

Offshore offices shall be located preferably on the accommodation platform except if protected by a fire and blast proof wall and if openings are oriented towards a safe area.

5.5.6 Living quarters3 Living quarters (LQ’s) are permanently manned.

Living Quarters shall be located in the safest area within the installation, so that life is not endangered in case of an explosion (and subsequent fire) from the process & utilities areas.

Onshore LQ’s shall be located in an inherently safe area as the general services area (refer to Section 5.3.2), or offsite and outside the restricted area.

Offshore, they should preferably be installed on a specific platform without process, storage, well and major utility equipment. Wherever this specific requirement cannot be fulfilled, the recommendations in Section 5.6 shall apply.

5.6 Layout of integrated platforms Offshore integrated platforms can present specific layout problems caused by their congestion, incompatible units arranged close to each other, and their position with respect to the prevailing wind. As a result some of the requirements conveyed by the present specification are not practicably attainable. The general arrangement of integrated platforms shall therefore be subject to a particular study and shall be supported by a justification dossier for approval by

2 Office occupancy is not limited and all persons in offices are considered mentally capable and awake. Occupancy

can however include persons that are physically disabled or that are not aware of the specific hazards of an installation containing hydrocarbon.

3 Living Quarters occupancy is not limited and can include persons that are physically disabled that are not aware of the specific hazards of an installation containing hydrocarbon and/or can be sleeping, thus slowing down their capacity to react in case of an emergency. In addition living quarters can contain special hazards and in particular some fuel sources and ignition sources e.g. kitchen, laundry, boilers and waste temporary storage.





/64

COMPANY, and the following set of rules is provided as a guideline (refer to Figure 3 - Typical layout of offshore integrated platform):

• Permanently manned rooms, muster areas, emergency control centre, radio room and evacuation means in accordance with the requirement of GS EP SAF 351 shall be grouped and located upwind the rest of the installation

• Temporary Refuges and means of evacuation shall be provided in the hazardous area for Emergency Response and evacuation of the personnel that cannot escape from the downwind part of the installation in case of an emergency. Capacity of TR and means of evacuation shall be based on the OPERATING PHILOSOPHY and SAFETY CONCEPT requirements. By default, a capacity of 50% of the POB shall be taken

• Permanently manned rooms, ER and EER facilities shall be separated from the rest of the installation by a fire and blast proof wall, H-120 fire rated, as high as the equipment it protects and presenting no open section with the exception of access ways to the plant area, at the edges of the platform

• Safe utility units (e.g. air compressors or water injection) shall be grouped upwind the units containing hydrocarbon and shall constitute a buffer zone between the permanently manned area and the process areas

• Units requiring fresh air to be drawn from safe locations (e.g. HVAC, power plant, gas turbines) shall be located upwind of any hazardous areas

• Units containing ignition sources shall be either located upwind units containing fuel sources or enclosed in pressurised premises

• Hazardous units shall be segregated by their increasing level of hydrocarbon risks. The most severe hazards shall be downwind and farther away from the living quarters

• Integrated flares tips shall be located downwind the installation, at a sufficient distance and height from hazardous areas to avoid ignition of a flammable gas cloud or a liquid hydrocarbon spillage to sea

• The structure of the elevated flares and the main flares headers shall be blast and fire proofed to ensure they are kept operational over the time it takes to complete an Emergency De-Pressurisation (refer to GS EP SAF 337)

• One lateral side of the platform shall be devoted to boat traffic and heavy lifts, and the opposite lateral side shall be reserved to risers and ESDV’s.





/64

High hazard area

Low hazard area

PR

EVA

ILIN

G W

IND

Machinery & sources of ignitionR

ISER

S

BO

AT

LAN

DIN

G

BO

AT

AP

PR

OAC

H S

ECTO

R

Air intakes

Safe utilities (buffer area)

210°

heli

copt

er

ELEVATED

TR TR

Fired heater

Life Raft

Life Raft

TEM

PSC

TEMPSC

Structure with passive fire protection

Zone 2 hazardous areaZone 1 hazardous area

VENT

TEM

PSC

FLARE

H LIVING QUARTERS CONTROL ROOM

OFFICES

approach sector

Radio room

Bla

st p

roof

/ fir

e pr

oof w

all

Figure 3 - Typical layout of offshore integrated platform

5.7 Temporary facilities The layout shall take into account the temporary facilities such as construction campsite and temporary accommodations, temporary power generation and other utilities or early production systems.





/64

These facilities shall form part of the project, shall be identified separately (considering they might have been forgotten in the STATEMENT OF REQUIREMENTS and can produce specific hazards) and shall be represented in dotted lines on all plot plans and elevations, until their complete de-commissioning and removal.

In the case of "grassroots" installations, particular consideration shall be paid to all measure likely to ensure the required safety standards during the period when simultaneous operations (SIMOPS) between construction and production activities will take place, i.e. from commissioning up to a few months after start-up. Four main configurations can be identified that may entail impact on layout:

• The construction campsite and temporary accommodations are likely to be manned for a significant period of time after oil and gas-in

• Construction activities are likely to continue while part of the process plant is already on stream, especially when initial production is obtained through an Early Production System (EPS) and more especially so when said EPS shares some systems (generally piping) with final units

• Temporary utilities, such as power generation, are kept operational until the new facilities have proven reliable

• Mechanical completion (and hence commissioning and start-up) of units operating in parallel (e.g. separation or compression trains) are time staggered and lead inevitably to a lengthened period of simultaneous construction and production operation.

5.8 Future extensions The layout shall take future foreseen extensions into account, as per STATEMENT OF REQUIREMENTS. This includes, but not limited to, additional wells, increased water handling, secondary or tertiary recovery systems, additional process trains and, as mentioned above, their associated construction area and related safe accesses.

Future extensions shall be represented in dotted lines on all plot plans and elevations. Their location should be such that the amount of work to be carried out in the vicinity of live equipment is limited or even totally avoided.

6. Equipment layout The spacing between equipment within a unit shall meet the requirements stipulated in the hazardous area classification and/or the equipment specification for hazardous area suitability. Refer to GS EP SAF 216.

The requirements for equipment location and recommended distances between equipment are given in Appendix C.




Annex 1


/64

Annex 1 (Informative) - Methodology to select layout

The following main principles should be applied:

• Containment of hydrocarbon: Hazardous releases to atmosphere of both liquid and gaseous compounds should be minimized as much as possible and the quick removal of any accumulated hazardous released product should be achieved.

• Prevention of ignition: Ignition sources should be segregated from fuel sources, and non hazardous areas from hazardous areas.

• Mitigation: Consequences of fires and explosions should be minimized, with respect to escalation and ease of access for fire-fighting.

• EER: Adequate measures for emergency situation should be provided.

In addition, layout should meet other requirements (valid for any other industrial facility) and in particular ensure easy operation (monitoring and maintenance), cater for vehicle and personnel traffic, security, safe working conditions, access for operation and maintenance, low impact to others (noise, toxicity, pollution, risk, etc.) and protection of the environment. Furthermore, layout should incorporate provisions for future extensions.

The methodology to select the layout of an installation includes three main steps:

• Choice of the location of the installation (refer to Section 4)

• General arrangement of units inside the installation (refer to Section 5)

• Layout of equipment in units (refer to Appendix C).




Appendix A


/64

Appendix A - Spacing - Default distances tables

Distances between fire zones Although not specifically included into the scope of the present General Specification, the table of default fire zones (FZ) and Restricted Area (RA) distances (refer to Table A1) is enclosed hereafter for better linkage with tables of default distances between units (refer to Table A2 through to Table A9 and Figure A2 through to Figure A9)).

It is reminded that distances between fire zones mentioned in Table A1 are onshore default distances, to be used for preliminary General Arrangement or quick check and that, in all cases, calculation of distances based on consequence analysis to match a set of pre-defined impact criteria are required. It is also reminded that these distances may be reduced or enlarged if physical partitions (e.g. fire and blast proof walls) are implemented. Refer to GS EP SAF 253 for more details.

Distances between units within their own fire zone COMPANY has established a set of default onshore distance tables (Tables A2 to A9) and subsequent sketches (Figures A1 to A9) for proper implantation of units within their own fire zones. Distances indicated in Tables and Figures A2 to A9 are not only dictated by safety considerations, but also and principally by constraints of construction, operability, access and maintenance. They represent COMPANY best engineering judgement, in terms of typical layout. Distances in tables below are devised to:

• Provide adequate safety to life in all cases

• Provide high degree of protection of the environment (although applicable requirements may vary from place to place)

• Provide a good (but not maximum) capacity to protect the asset in case of an incident

• Incorporate all foreseeable provisions for construction, operation, maintenance and inspection routine tasks with the possible exception of highly hazardous simultaneous operation.

Distances indicated in Tables and Figures A2 to A9 are plane horizontal 2D distances between the closest points of two different units (battery limits), without any obstacle and assuming that adequate safety features (e.g. fire-fighting systems, ESD system and qualification of personnel) are provided.

Onshore, default distances of Tables and Figures A2 to A9 may be reduced or enlarged. Distances between units shall then be supported by a justification dossier for approval by COMPANY.

Offshore, Tables and Figures A2 to A9 can be used as guidelines. However, the general arrangement of offshore platforms is subject to a particular study, based on best industry practices and recommendations given in Section 5.6, supported by a justification dossier for approval by COMPANY

There is no minimum distance between equipment and the unit battery limit, providing access to the equipment is granted (refer to Appendix C for distances between equipment).

The distance tables proposed below do not deal (at least in detail) with some specific cases, in particular onshore overhead hydrocarbon storage tanks (refer to GS EP SAF 341), FPSO’s, LNG plants, shorelines terminals and buried storage, for which either another general specification is available or a specific study is to be carried-out.




Appendix A


/64

Table A1 – Onshore default Fire Zones (FZ) and Restricted Area (RA) distances

Rem

inde

r: Th

is ta

ble

prov

ides

ons

hore

def

ault

Fire

Zon

es (F

Z) a

nd R

estr

icte

d A

rea

(RA

) di

stan

ces

and

not d

ista

nces

bet

wee

n eq

uipm

ents

or u

nits

with

in a

Fire

Zon

e.

Not

e :

All

dist

ance

s in

met

res.

D

ista

nces

take

n fro

m e

dge

of u

nit o

r equ

ipm

ent g

ener

atin

g Fi

re Z

one

or R

estri

cted

Are

a.

FZR

A11

1213

2122

3132

3341

4243

4445

46

11E

rupt

ive

oil /

gas

-lifte

d oi

l / g

as w

ell

5020

050

12N

on-e

rupt

ive

oil w

ell

1515

050

1513

Wat

er in

ject

ion

/ wat

er p

rodu

ctio

n w

ell

7.5

5050

157.

5

21N

on b

urie

d st

orag

e10

030

010

010

010

010

022

Bur

ied

stor

age

(1)

40 (1

)20

0 (1

)50

40 (1

)40

(1)

100

40 (1

)

31La

rges

t tan

k ca

paci

ty (2

) ≤ 1

0 00

0 m

370

(2)

170

(2)

70 (2

)70

(2)

70 (2

)10

070

(2)

70 (2

)

32La

rges

t tan

k ca

paci

ty (2

) ≤ 2

0 00

0 m

311

0 (2

)21

0 (2

)11

0 (2

)11

0 (2

)11

0 (2

)11

0 (2

)11

0 (2

)11

0 (2

)11

0 (2

)

33La

rges

t tan

k ca

paci

ty (2

) > 2

0 00

0 m

315

0 (2

)25

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)15

0 (2

)

41G

as w

ith o

pera

ting

pres

sure

> 7

0 ba

rg (3

)60

(3)

250

60 (3

)60

(3)

60 (3

)10

060

(3)

7511

0 (2

)15

0 (2

)60

(3)

42G

as w

ith o

pera

ting

pres

sure

≤ 7

0 ba

rg40

200

5040

4010

040

(1)

70 (2

)11

0 (2

)15

0 (2

)60

(3)

4043

LPG

pro

cess

100

200

100

100

100

100

100

100

110

(2)

150

(2)

100

100

100

44O

il or

con

dens

ate

proc

ess

8020

080

8080

100

8080

110

(2)

150

(2)

8080

100

8045

Slu

g ca

tche

r (4)

8025

080

8080

100

8080

110

(2)

150

(2)

8080

100

8080

46U

tiliti

es (u

sing

fuel

gas

) (5)

3050

5030

3010

040

(1)

70 (2

)11

0 (2

)15

0 (2

)60

(3)

4010

080

8030

51G

ener

al S

ervi

ce a

rea

(6)

NA

NA

200

150

5030

020

0 (1

)17

0 (2

)21

0 (2

)25

0 (2

)25

020

020

020

025

050

61Fl

ares

, col

d ve

nts,

bur

n pi

ts (7

)N

A15

020

015

015

030

020

0 (1

)17

0 (2

)21

0 (2

)25

0 (2

)25

020

020

020

025

015

0

(1) :

Def

ault

dist

ance

s pr

ovid

ed a

ll st

orag

e liq

uid

outle

ts a

re b

urie

d up

to th

e au

tom

atic

isol

atio

n va

lve.

(2) :

Def

ault

dist

ance

s to

be

take

n fro

m e

dge

of c

rude

oil

stor

age

tank

bun

ded

area

; eac

h co

ntai

ning

a s

ingl

e st

orag

e ta

nk. L

imit

bund

siz

e to

a m

axim

um o

f 700

0 m

2 .(3

) :

A

dd 1

5 m

etre

s if

oper

atin

g pr

essu

re a

bove

150

bar

g.(4

) :

Fi

nger

or v

esse

l-typ

e sl

ug c

atch

er w

ith V

liq >

50

m3 o

r P x

Vga

s > 1

000

bar

.m3 .

(5) :

May

als

o in

clud

e sa

fe u

tiliti

es o

n la

rge

plan

ts.

(6) :

(7) :

Flar

es, c

old

vent

s, b

urn

pits

Fire

Zon

es a

re p

ositi

oned

out

side

the

plan

t Res

trict

ed A

rea.

Con

vers

ely,

pla

nt is

pos

ition

ed o

utsi

de th

e R

estri

cted

Are

a ge

nera

ted

by fl

ares

, ven

ts, b

urn

pits

. (8

) :

D

efau

lt di

stan

ce to

ens

ure

that

flar

es, c

old

vent

s, b

urn

pits

are

inde

pend

ant.

Gen

eral

Ser

vice

are

a co

ntai

ns li

ving

qua

rters

, offi

ces,

con

trol r

oom

s, fi

re s

tatio

n, w

orks

hops

and

war

ehou

ses,

gua

rd h

ouse

, saf

e ut

ilitie

s, m

uste

r are

as, e

mba

rkat

ion

area

, gar

bage

inci

nera

tor,

helid

ecks

, wor

ship

room

s an

d re

crea

tion

area

s, lo

gist

ics

build

ings

, tel

ecom

she

lter a

nd ra

dio

mas

t, pe

trol s

tatio

n pa

rkin

g lo

ts a

nd b

us s

tatio

ns.

Gen

eral

Ser

vice

are

a Fi

re Z

one

is p

ositi

oned

out

side

the

plan

t Res

trict

ed A

rea.

FLAR

ES15

015

0 (8

)

CR

UD

E O

IL S

TOR

AG

E

PRO

CES

S &

UTI

LITI

ES

BU

ILD

ING

SN

A5161

WEL

LS

LPG

STO

RAG

E

Def

ault

Fire

Zon

es a

nd R

estri

cted

Are

a di

stan

ces

are

to b

e us

ed fo

r pre

limin

ary

Gen

eral

Arr

ange

men

t or q

uick

che

ck. I

n al

l cas

es, c

alcu

latio

n of

dis

tanc

es b

ased

on

cons

eque

nce

anal

ysis

as

per G

S E

P SA

F 25

3 ar

e re

quire

d to

take

in

to a

ccou

nt S

ite s

peci

fic d

esig

n ch

arac

teris

tics.

WEL

LSLP

G S

TOR

AGE

CR

UD

E O

IL S

TOR

AGE

PRO

CES

S &

UTI

LITI

ESB

UIL

DIN

GS

FLAR

ES




Appendix A


/64

Figure A1 – Typical sketch of onshore General Arrangement

45 46

44

4341

PIP

ELI

NES

FZ :

80 m

13FZ

: 7.

5 m

12FZ

: 15

m

11FZ

: 50

m AC

CE

SS11

RA

: 20

0 m

12R

A :

150

m

13R

A :

RA : 250 m

(3) FZ :

RA : 250 m RA : 200 m

FZ :

100

m

FZ :

30 m

RA : 50 m

FZ :

80 m

RA : 200 m

22RA : 200 m

21RA : 300 m

22FZ

: 40

m

21FZ

: 10

0 m

61R

A :

150

m

RA : 170 m

RA : 210 m

RA : 250 m

31

32

33

FZ : 70 m

31FZ : 1

10 m

32FZ : 1

50 m

3351

RIG

AR

EA

60 m

PIP

ER

AC

KS

ER

UPT

IVE

OIL

/GAS

-LIF

TED

OIL

/GAS

WEL

L11

WE

LLS

NO

N-E

RU

PTIV

E O

IL W

ELL

12

WAT

ER

INJE

CTI

ON

/ W

ATER

PR

OD

UC

TIO

N W

ELL

13

NO

N B

UR

IED

STO

RAG

E21

BU

RIE

D S

TOR

AGE

22

LAR

GE

ST T

AN

K C

AP

ACIT

Y ≤

10 0

00 m

³ 31

LAR

GE

ST T

AN

K C

AP

ACIT

Y ≤

20 0

00 m

³ 32

LAR

GE

ST T

AN

K C

AP

ACIT

Y >

20 0

00 m

³ 33

GAS

WIT

H O

PER

ATI

NG

PR

ES

SUR

E >

70 b

arg

41

LPG

PR

OC

ESS

43

OIL

OR

CO

ND

ENSA

TE P

RO

CES

S44

SLU

G C

ATC

HER

45

UTI

LITI

ES

( USI

NG

FU

EL

GA

S )

46

GEN

ER

AL S

ER

VIC

E A

RE

A (O

UT

OF

PLAN

T AR

EA)

51

FLA

RE

S, C

OLD

VE

NTS

, BU

RN

PIT

S61

LPG

STO

RAG

E

CR

UD

E O

IL S

TOR

AG

E

PR

OC

ES

S &

UTI

LITI

ES

BU

ILD

ING

S

FLA

RE

S

LEG

EN

D:

PER

IMET

ER F

EN

CE

FIR

E Z

ON

E (F

Z)R

ES

TRIC

TED

AR

EA (R

A)

NO

TE:

(3) A

DD

15

ME

TRE

S IF

OPE

RAT

ING

PR

ESS

UR

E IS

ABO

VE

150

barg

.

ITEM

50 m




Appendix A


/64

Table A2 – Onshore distances between units within well Fire Zone

All

dist

ance

s in

met

res.

WEL

L FI

RE

ZON

EA

BA

Wel

ls s

paci

ng(1

)

BP

erim

eter

fenc

e20

0N

A

(1) :

No

defa

ult d

ista

nce

prov

ided

; dis

tanc

es s

hall

be g

over

ned

by d

rillin

g rig

con

side

ratio

ns.

Not

es :

Uni

ts n

orm

ally

ass

ocia

ted

with

wel

ls in

a w

ell c

lust

er a

rea,

suc

h as

gas

or l

iqui

d pr

oces

s un

its, t

est s

epar

ator

and

au

xilia

ries,

pig

trap

s, c

hem

ical

sto

rage

, ven

ts/fl

ares

/bur

n pi

ts, b

uild

ings

, ove

rhea

d po

wer

line

s, fi

re fi

ghtin

g un

it (ta

nk a

nd p

umps

), ga

s or

liqu

id m

eter

ing

stat

ions

, fire

d he

ater

s un

it, D

iese

l sto

rage

, etc

... s

hall

be lo

cate

d ou

tsid

e th

e w

ell F

ire Z

one

in d

edic

ated

and

inde

pend

ant F

ire Z

one(

s), a

s pe

r tab

les

A2

to A

9.Fo

r def

ault

dist

ance

s be

twee

n Fi

re Z

ones

, ref

er to

Tab

le A

1.

Ons

hore

, no

units

are

inst

alle

d w

ithin

the

wel

l Fire

Zon

e , w

hich

is le

ft fre

e fo

r dril

ling

rig fa

cilit

ies.




Appendix A


/64

Figure A2 – Typical sketch of onshore well Fire Zone

41

RA

: 250

m

RA

: 200

m

FZ :

40 m

FZ

: 50

m

FZ

: 7.5

m

FZ

: 15

m

RA

: 50

m

RA

: 15

0 m

RA

: 200

m

51

RIG

AC

CES

S AR

EA

RA : 150 m

PIP

ELI

NE

13

12

11

61

12

11

FZ :

60 m

42 4113

A 42

41 42

15m

ER

UPT

IVE

OIL

/GA

S-LI

FTED

OIL

/GAS

WEL

L11

WE

LLS

NO

N-E

RU

PTIV

E O

IL W

ELL

12

WAT

ER IN

JEC

TIO

N /

WA

TER

PR

OD

UC

TIO

N W

ELL

13

GEN

ERAL

SER

VIC

E AR

EA (O

UT

OF

PLAN

T AR

EA)

51

BU

ILD

ING

S

FLA

RE

S, C

OLD

VE

NTS

, BU

RN

PIT

S61

FLA

RE

S

GAS

WIT

H O

PER

ATI

NG

PR

ESSU

RE

> 70

bar

g41

PR

OC

ESS

& U

TILI

TIE

S

GAS

WIT

H O

PER

ATI

NG

PR

ESSU

RE ≤

70 b

arg

42

PIG

TR

APS

A

ITE

M

LEG

EN

D:

PER

IMET

ER F

ENC

EFI

RE

ZO

NE

(FZ)

RES

TRIC

TED

AR

EA (R

A)D

ISTA

NC

ES

BETW

EEN

UN

ITS




Appendix A


/64

Table A3 - Distances between units within flare Fire Zone

Rem

inde

r :

Not

es :

FLAR

E FI

RE

ZON

E (1

)A

BC

DE

FA

Elev

ated

flar

e 15

0 (2

)

BBu

rn p

it15

015

0 (2

)

CEn

clos

ed g

roun

d fla

re15

015

030

DFl

are

KO

dru

m +

aux

iliarie

s13

0 (3

)13

0 (3

)30

NA

EC

old

vent

150

150

150

130

(3)

150

(2)

FPe

rimet

er fe

nce

150

150

3030

150

NA

(0) :

(1) :

Flar

es, c

old

vent

s, b

urn

pits

Fire

Zon

es a

re c

alcu

late

d w

ith R

estri

cted

Are

a cr

iteria

(Ref

er to

GS

EP S

AF 2

53) a

nd a

re th

eref

ore

equi

vale

nt.

(2) :

(3) :

All d

ista

nces

in m

etre

s.D

ista

nces

take

n fro

m e

dge

of u

nit.

For c

omm

odity

pur

pose

s, th

e di

ffere

nt ty

pes

of d

ispo

sal s

yste

ms

are

furth

er re

ferr

ed a

s 'fl

ares

', an

d re

fere

nce

is m

ade

to 'f

lare

fire

zon

e' fo

r 'd

iffer

ent t

ypes

of d

ispo

sal s

yste

ms

fire

zone

s'.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

diffe

rent

type

s of

dis

posa

l sys

tem

s (0

) (diff

eren

t typ

es o

f fla

res

and

vent

s)

Ons

hore

, no

units

are

inst

alle

d w

ithin

the

flare

Fire

Zon

e , w

ith th

e po

ssib

le s

ingl

e ex

cept

ion

of th

e fla

re K

O d

rum

.Fo

r def

ault

dist

ance

s be

twee

n Fi

re Z

ones

, ref

er to

Tab

le A

1.

Def

ault

valu

e to

ens

ure

that

flar

es, b

urn

pits

or c

old

vent

s ar

e in

depe

nden

t. Sh

ould

it n

ot b

e th

e ca

se, t

hen

a m

axim

um d

ista

nce

of 1

0 m

etre

s to

be

inst

alle

d be

twee

n tw

o fla

re ti

ps o

n th

e sa

me

stru

ctur

e, tw

o bu

rner

s in

the

sam

e bu

rn-p

it, o

r tw

o ve

nt ti

ps o

n th

e sa

me

stru

ctur

e, in

line

with

GS

EP S

AF 2

62.

Flar

e K

O d

rum

and

aux

iliarie

s ca

n be

loca

ted

in fl

are

Fire

Zon

e pr

ovid

ing

radi

atio

n cr

iteria

giv

en in

GS

EP

SAF

262

are

fulfi

lled.

How

ever

, it i

s re

com

men

ded

to lo

cate

them

out

side

the

flare

Fire

Zon

e.




Appendix A


/64

Figure A3 – Typical sketch of onshore flare Fire Zone

RA

= 15

0 m

RA =

150

m

B

A

OR

E

130

m

DC

FLAR

E LI

NES

FRO

M P

RO

CES

S30 m

30 m30

m

ELE

VATE

D F

LAR

EA

BU

RN

PIT

B

EN

CLO

SED

GR

OU

ND

FLA

RE

C

FLA

RE

KO

DR

UM

+ A

UXI

LIAR

IES

D

CO

LD V

ENT

E

DES

CR

IPTI

ON

ITE

M

LEG

EN

D:

PER

IME

TER

FEN

CE

FIR

E ZO

NE

(FZ)

RE

STR

ICTE

D A

REA

(RA)

DIS

TAN

CES

BET

WEE

N U

NIT

S




Appendix A


/64

Table A4 - Distances between units within process Fire Zone

Rem

inde

r :

Not

es :

All d

ista

nces

in m

etre

s.D

ista

nces

take

n fro

m e

dge

of u

nit.

PRO

CES

S FI

RE

ZON

EA

BC

DE

FG

HI

JK

LM

NA

Pig

traps

NA

BG

as m

eter

ing

stat

ion

15 (6

)7.

5C

Liqu

id e

xpor

t pum

ping

/ m

eter

ing

stat

ion

15 (6

,7)

15 (6

,7)

7.5

DG

as p

roce

ss u

nit (1

)15

(6)

15 (6

)15

(6)

15 (6

)

EO

il / c

onde

nsat

e pr

oces

s un

it (2

)15

(6)

15 (6

)15

(6)

15 (6

)15

(6)

FG

as c

ompr

essi

on u

nit (3

)30

3030

3030

15G

Ope

n an

d cl

osed

dra

in d

rum

s +

auxi

liarie

s15

1515

1515

30N

AH

Mai

n pi

pe ra

ck7.

57.

57.

57.

57.

57.

57.

5N

AI

LPG

pro

cess

uni

t (4)

3030

3030

3045

307.

5N

AJ

Oily

wat

er tr

eatm

ent u

nit

3030

3030

3045

7.5

7.5

30N

AK

Fire

d he

ater

s un

it30

(8)

30 (8

)30

(8)

30 (8

)30

(8)

45 (6

)30

7.5

6030

30L

Tech

nica

l / E

&I ro

om15

1515

1515

15 (6

)7.

57.

515

3030

(8)

7.5

MC

ontro

l roo

m (p

erm

anen

tly m

anne

d) (5

)30

3030

3030

30 (6

)30

3060

3030

(8)

NA

NA

NPe

rimet

er fe

nce

250

250

200

250

200

250

5025

020

050

30 (8

)30

30N

A

(1) :

Incl

udes

gas

sep

arat

ion,

deh

ydra

tion

units

, sw

eete

ning

uni

ts, d

ewpo

intin

g un

its, t

urbo

-exp

ande

rs, m

olec

ular

sie

ves,

fuel

gas

uni

t. (2

) :In

clud

es o

il an

d co

nden

sate

sep

arat

ion,

des

altin

g un

its, s

tabi

lisat

ion

units

.(3

) :In

clud

es s

crub

bers

and

coo

ling

units

.(4

) :In

clud

es fr

actio

natio

n un

its a

nd tr

eatm

ent u

nits

.(5

) :

(6) :

Add

15 m

if n

orm

al o

pera

ting

pres

sure

> 7

0 ba

rg.

(7) :

Add

15 m

if li

quid

is L

PG.

(8) :

Add

15 m

if d

uty

> 10

MW

.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e pr

oces

s Fi

re Z

one

and

not b

etw

een

units

per

tain

ing

to d

iffer

ent f

ire z

ones

. Fo

r def

ault

dist

ance

s be

twee

n Fi

re Z

ones

, ref

er to

Tab

le A

1.

Con

trol r

oom

sha

ll be

ade

quat

ely

pres

suris

ed, f

ire a

nd b

last

-pro

ofed

and

sha

ll co

nser

ve, a

fter a

pos

sibl

e fir

e or

exp

losi

on, i

ts s

peci

fied

fire

and

blas

t rat

ings

. It

shal

l be

surr

ound

ed o

n al

l ext

erna

l fac

es b

y an

are

a ap

prox

imat

ely

30 m

etre

s w

ide

left

tota

lly u

nobs

truct

ed.




Appendix A


/64

Figure A4 – Typical sketch of onshore process Fire Zone

J K

I

GE

D

F

RA : 50 m

RA : 200 m

BC

OR

RA : 50 m

RA : 250 m

H

ED

RA : 200 m

M 30 mRA :

A

RA : 250 m

PIP

ELI

NES

BR

A : 2

50 m

C

L RA : 30 m

RA : 250 m

RA : 250 m

15 m

15 m

30 m

30 m

30 m (6)

15 m

15 m

RA

: 200

m

45 m

30 m

RA : 30 m

7.5 m

45 m

60 m

30 m

15 m

15 m

15 m 15 m

7.5 m

RA

: 250

m

30 m

PIG

TR

APS

A

GA

S M

ETE

RIN

G S

TATI

ON

B

LIQ

UID

EXP

OR

T P

UM

PIN

G /

MET

ERIN

G S

TATI

ON

C

GA

S P

RO

CE

SS

UN

ITD

OIL

/ C

ON

DE

NS

ATE

PR

OC

ESS

UN

ITE

GA

S C

OM

PR

ES

SIO

N U

NIT

F

DES

CR

IPTI

ON

ITEM

OP

EN

AN

D C

LOS

ED

DR

AIN

DR

UM

S +

AU

XIL

IAR

IES

G

MA

IN P

IPE

RA

CK

H

LPG

PR

OC

ES

S U

NIT

I

OIL

Y W

ATE

R T

RE

ATM

EN

T U

NIT

J

FIR

ED

HE

ATE

RS

UN

ITK

TEC

HN

ICA

L / E

&I R

OO

ML

CO

NTR

OL

RO

OM

(PE

RM

AN

EN

TLY

MAN

NE

D)

MNO

TE:

(6) A

DD

15

ME

TRE

S IF

NO

RM

AL

OP

ERA

TIN

G P

RES

SUR

E IS

> 7

0 ba

rg.

LEG

END

:P

ERIM

ETER

FEN

CE

FIR

E ZO

NE

(FZ)

RE

STR

ICTE

D A

RE

A (R

A)D

ISTA

NC

ES

BE

TWEE

N U

NIT

S

(6)




Appendix A


/64

Table A5 - Distances between units within utility Fire Zone

Rem

inde

r :

Not

es :

All d

ista

nces

in m

etre

s.D

ista

nces

take

n fro

m e

dge

of u

nit.

UTI

LITY

FIR

E ZO

NE

AB

CD

EF

GH

IJ

KL

MN

OP

APr

opan

e st

orag

e (1

)15

BPr

opan

e lo

adin

g po

st30

30C

Ove

rhea

d po

wer

line

s10

030

NA

DEl

ectri

cal s

ubst

atio

n10

030

157.

5E

Fire

d he

ater

s un

it10

030

4530

30F

Pow

er g

ener

atio

n un

it in

clud

ing

emer

genc

y10

030

4515

30 (5

)15

GTe

chni

cal /

E&I

room

100

3030

NA

30 (5

)15

7.5

HFi

re fi

ghtin

g un

it (ta

nks

and

pum

ps)

100

3045

3030

(5)

3015

NA

IW

ater

trea

tmen

t uni

t10

030

3030

307.

57.

515

7.5

JFu

el g

as u

nit

100

3045

3030

(5)

3030

3030

7.5

KC

hem

ical

sto

rage

100

3045

3030

(5)

3030

3015

30N

AL

Air /

N2 u

nits

100

3030

3030

7.5

7.5

157.

530

15N

A

MSt

eam

gen

erat

ion

unit

100

3045

3030

(5)

3030

3030

3030

30N

AN

Con

trol r

oom

(2) (p

erm

anen

tly m

anne

d)10

030

4530

30 (5

)30

NA

3030

3030

3030

NA

OD

iese

l sto

rage

(200

0 m

3 max

.(3) ) +

aux

iliarie

s10

030

4530

30 (5

)30

1515

7.5

307.

57.

530

30N

AP

Perim

eter

fenc

e10

045

(4)

3030

(5)

3030

307.

530

3015

3030

30N

A

(1) :

(2) :

(3) :

Die

sel s

tora

ge w

ith a

cap

acity

larg

er th

an 2

000

m3

shal

l be

loca

ted

in th

e oi

l sto

rage

Fire

Zon

e.(4

) :G

ener

ally

, ove

rhea

d po

wer

line

arr

ival

sta

tion

loca

ted

at th

e pe

rimet

er fe

nce

to a

llow

acc

ess

by e

lect

rical

dis

tribu

tion

Com

pany

.(5

) :Ad

d 15

m if

dut

y >

10 M

W

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e ut

ility

Fire

Zon

e an

d no

t bet

wee

n un

its p

erta

inin

g to

diff

eren

t fire

zon

es.

For d

efau

lt di

stan

ces

betw

een

Fire

Zon

es, r

efer

to T

able

A1.

Prop

ane

max

imum

con

side

red

stor

age

is 5

0 m

3 , prov

idin

g ve

ssel

s ar

e su

itabl

y pr

otec

ted

and

fire

proo

fed.

Pro

pane

is fo

r uni

ts c

oolin

g pu

rpos

es o

nly.

15

met

res

indi

cate

s di

stan

ces

betw

een

two

prop

ane

vess

els.

Con

trol r

oom

sha

ll be

ade

quat

ely

pres

suris

ed, f

ire a

nd b

last

-pro

ofed

and

sha

ll co

nser

ve, a

fter a

pos

sibl

e fir

e or

exp

losi

on, i

ts s

peci

fied

fire

and

blas

t rat

ings

. It s

hall

be s

urro

unde

d on

all

exte

rnal

face

s by

an

area

app

roxi

mat

ely

30 m

etre

s w

ide

left

tota

lly u

nobs

truct

ed.




Appendix A


/64

Figure A5 – Typical sketch of onshore utility Fire Zone

MJ F

E

DC J

KO

A A

L

HG

30 m

30 m

30 m

30 m

30 m

30 m

30 m

15 m

15 m

45 m

45 m

30 m

30 m

30 m 15 m

7.5

m

15 m

30 m 30 m

30 m

30 m

100

m

RA

: 10

0 m

15 m30 m

N

100 m

B

RA

: 45

m

(5)

AP

RO

PA

NE

STO

RA

GE

+ L

OAD

ING

PO

ST

ITE

M

B

OV

ER

HE

AD

PO

WE

R L

INES

C

ELE

CTR

ICA

L S

UBS

TATI

ON

D

FIR

ED

HE

ATE

RS

UN

ITE

PO

WE

R G

EN

ER

ATI

ON

UN

IT IN

CLU

DIN

G E

MER

GE

NC

YF

TEC

HN

ICA

L / E

&I R

OO

MG

FIR

E F

IGH

TIN

G U

NIT

(TAN

KS A

ND

PU

MP

S)H

WA

TER

TR

EA

TMEN

T U

NIT

I

FUE

L G

AS

UN

ITJ

CH

EM

ICA

L S

TOR

AG

EK

AIR

/ N

2 U

NIT

SL

STE

AM

GE

NE

RA

TIO

N U

NIT

M

CO

NTR

OL

RO

OM

(PE

RM

AN

EN

TLY

MAN

NED

)N

DIE

SE

L S

TOR

AG

E (2

000

m³ m

ax.)

+ AU

XIL

IAR

IES

O

DE

SCR

IPTI

ON

LOA

DIN

G P

OST

NO

TE:

(5)

AD

D 1

5 M

ETR

ES

IF D

UTY

> 1

0MW

LEG

END

:P

ER

IME

TER

FEN

CE

FIR

E Z

ON

E (F

Z)R

ES

TRIC

TED

AR

EA (R

A)D

ISTA

NC

ES

BE

TWE

EN U

NIT

S




Appendix A


/64

Table A6 - Distances between units within slug catcher Fire Zone

Rem

inde

r :

Not

es :

SLU

G C

ATC

HER

FIR

E ZO

NE

AB

CD

EF

ASl

ug c

atch

er (1

)30

BPi

g tra

ps15

NA

CLi

quid

-rec

eivi

ng v

esse

l (2) +

pum

ps7.

515

15D

Cat

ch /

spilla

ge p

it (2

)30

3030

NA

EC

hem

ical

sto

rage

uni

t7.

57.

57.

57.

5N

AF

Perim

eter

fenc

e25

025

025

050

50N

A

(1) :

Fing

er o

r ves

sel-t

ype

slug

cat

cher

with

Vliq

> 5

0 m

3 or P

x V

gas >

1 0

00 b

ar.m

3 .(2

) :

Ap

plic

able

to fi

nger

-type

slu

g ca

tche

rs o

nly.

All d

ista

nces

in m

etre

s.D

ista

nces

take

n fro

m e

dge

of u

nit.

Uni

ts n

ot li

sted

in h

ere

belo

w ta

ble

are

loca

ted

outs

ide

the

slug

cat

cher

Fire

Zon

e.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e sl

ug c

atch

er F

ire

Zone

and

not

bet

wee

n un

its p

erta

inin

g to

diff

eren

t fire

zon

es.

For d

efau

lt di

stan

ces

betw

een

Fire

Zon

es, r

efer

to T

able

A1.




Appendix A


/64

Figure A6 – Typical sketch of onshore slug catcher Fire Zone

RA

: 25

0 m

PIPELINES

FZ : 80 m

B

E

FZ : 8

0 m

AC

D

FROM OUTSIDE

RA : 250 m

7.5 m

15 m

7.5

m

30 m

(FIN

GE

R T

YP

E S

LUG

CAT

CH

ER

)

7.5

m

SLU

G C

ATC

HER

A

PIG

TR

APS

B

LIQ

UID

- R

EC

EIV

ING

VES

SEL

+ PU

MP

SC

CA

TCH

/ S

PIL

LAG

E PI

TD

CH

EM

ICA

L S

TOR

AG

E U

NIT

E

DE

SCR

IPTI

ON

ITE

M

LEG

END

:P

ER

IME

TER

FE

NC

EFI

RE

ZO

NE

(FZ)

RE

STR

ICTE

D A

REA

(RA)

DIS

TAN

CE

S B

ETW

EEN

UN

ITS




Appendix A


/64

Table A7 - Distances between units within LPG storage Fire Zone

Rem

inde

r :

Not

es :

LPG

STO

RAG

E FI

RE

ZON

EA

BC

DE

FG

HA

Abov

e gr

ound

sto

rage

uni

t(1

)

BU

nder

grou

nd o

r und

er-e

mba

nkm

ent s

tora

ge u

nit

2 (2

)1

CLP

G p

umpi

ng s

tatio

n15

(3)

15N

AD

LPG

met

erin

g st

atio

n15

(3)

157.

5N

AE

Load

ing

post

30 (4

)30

(4)

30 (4

)30

(4)

30F

Tech

nica

l / E

&I ro

om45

(3)

3030

3030

(4)

7.5

GM

ain

pipe

rack

15 (3

)15

7.5

7.5

30 (4

)30

NA

HP

erim

eter

fenc

e30

020

020

020

045

3020

0N

A

(1) :

Vess

el to

ves

sel d

ista

nce

= 1.

5 x

diam

eter

of l

arge

st v

esse

l (sp

here

or b

ulle

t) +

5 m

etre

s, w

ith a

min

imum

of 3

0 m

etre

s.(2

) :U

nder

grou

nd o

r und

er-e

mba

nkm

ent s

tora

ge u

nit P

SV d

isch

arge

to b

e lo

cate

d 10

met

res

away

from

abo

ve g

roun

d ad

jace

nt s

tora

ge u

nit.

(3) :

Dis

tanc

e fro

m e

dge

of re

tent

ion

basi

n.(4

) :Lo

adin

g po

sts

are

loca

ted

outs

ide

the

LPG

sto

rage

Fire

Zon

e, in

thei

r ded

icat

ed a

nd s

epar

ated

Fire

Zon

es.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e LP

G s

tora

ge F

ire Z

one

and

not b

etw

een

units

per

tain

ing

to d

iffer

ent f

ire

zone

s.

All

dist

ance

s in

met

res.

Dis

tanc

es ta

ken

from

edg

e of

uni

t.U

nits

not

list

ed in

her

e be

low

tabl

e ar

e lo

cate

d ou

tsid

e th

e LP

G s

tora

ge F

ire Z

one.




Appendix A


/64

Figure A7 – Typical sketch of onshore LPG storage Fire Zone

C D F

RA

: 20

0 m

RA

: 20

0 m

RA

: 20

0 m

RA

: 30

m

RA : 200 mB

RA : 300 m

A

G

E

BFZ

:

AFZ

: 10

0 m

RA

: 45

m

AB

30 m

(1)

7.5 m 30 m

45 m

:

15 m

15 m

E

E

RA

: 45

m

30 m E

30 m

:

BA

7.5

m

7.5

m

A B C D E F G

ITEM

AB

OV

E G

RO

UN

D S

TOR

AGE

UN

IT

UN

DE

RG

RO

UN

D O

R U

ND

ER

-EM

BA

NK

MEN

T ST

OR

AGE

UN

IT

LPG

PU

MP

ING

STA

TIO

N

LPG

ME

TER

ING

STA

TIO

N

LOA

DIN

G P

OST

TEC

HN

ICA

L / E

&I R

OO

M

MA

IN P

IPE

RAC

K

DES

CR

IPTI

ON

LEG

END

:P

ER

IME

TER

FEN

CE

FIR

E Z

ON

E (F

Z)R

ES

TRIC

TED

AR

EA (R

A)D

ISTA

NC

ES

BE

TWEE

N U

NIT

S

40 m

(1) V

ES

SE

L TO

VE

SSE

L D

ISTA

NC

E :

-

1.5

x Ø

OF

LAR

GE

ST V

ESSE

L +

5 m

-

MIN

IMU

M O

F 30

m

NO

TE:




Appendix A


/64

Table A8 - Distances between units within crude oil storage Fire Zone

Rem

inde

r :

Not

es :

OIL

STO

RAG

E FI

RE

ZON

EA

BC

DE

FG

AC

rude

oil

stor

age

unit

(1)

BO

il pu

mpi

ng s

tatio

n15

(2)

NA

CO

il m

eter

ing

stat

ion

15 (2

)7.

5N

AD

Load

ing

post

30 (3

)30

(3)

30 (3

)30

ETe

chni

cal /

E&I

room

45 (2

)30

3030

(3)

7.5

FM

ain

pipe

rack

15 (2

)7.

57.

530

(3)

30N

AG

Perim

eter

fenc

e25

020

020

045

3020

0N

A

(1) :

Tank

to ta

nk d

ista

nce

= di

amet

er o

f lar

gest

tank

if la

rges

t tan

k ca

paci

ty >

150

0 m

3 or 0

.5 x

dia

met

er o

f lar

gest

tank

if la

rges

t tan

k ca

paci

ty ≤

150

0 m

3 .(2

) :D

ista

nce

from

edg

e of

rete

ntio

n ba

sin.

(3) :

Load

ing

post

s ar

e lo

cate

d ou

tsid

e th

e oi

l sto

rage

Fire

Zon

e, in

thei

r ded

icat

ed a

nd s

epar

ated

Fire

Zon

es.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e cr

ude

oil s

tora

ge F

ire Z

one

and

not b

etw

een

units

per

tain

ing

to d

iffer

ent

fire

zone

s.

All d

ista

nces

in m

etre

s.D

ista

nces

take

n fro

m e

dge

of u

nit.

Uni

ts n

ot li

sted

in h

ere

belo

w ta

ble

are

loca

ted

outs

ide

the

crud

e oi

l sto

rage

Fire

Zon

e.




Appendix A


/64

Figure A8 – Typical sketch of onshore crude oil storage Fire Zone

B C

E

RA

: 20

0 m

RA

: 20

0 m

RA

: 20

0 m

RA

:

RA : 170 m - CAPACITY ≤ 10000 m³

RA : 210 m - CAPACITY ≤ 20000 m³

F

D

FZ :

70 m

RA

: 45

m

A

30 m

(1)

7.5 m 30 m

45 m

15 m

FZ :

110

m

FZ :

150

m

D

D

RA

: 45

m

30 m D

D

RA

: 45

m

30 m D

RA : 250 m - CAPACITY > 20000 m³

7.5

m

7.5

m15

m

A B C D E F

ITE

MC

RU

DE

OIL

STO

RAG

E U

NIT

OIL

PU

MP

ING

STA

TIO

N

OIL

ME

TER

ING

STA

TIO

N

LOA

DIN

G P

OST

TEC

HN

ICA

L / E

&I R

OO

M

MA

IN P

IPE

RA

CK

DE

SCR

IPTI

ON

(1) T

AN

K T

O T

AN

K D

ISTA

NC

E :

-

Ø O

F LA

RG

ES

T TA

NK

(CA

PAC

ITY

> 15

00m

³)

- 0

.5 x

Ø O

F LA

RG

ES

T TA

NK

(CAP

ACIT

Y ≤

1500

m³)

NO

TE:

LEG

EN

D:

PE

RIM

ETE

R F

EN

CE

FIR

E Z

ON

E (F

Z)R

ES

TRIC

TED

AR

EA (R

A)D

ISTA

NC

ES

BE

TWE

EN U

NIT

S

CA

PA

CIT

Y ≤

100

00 m

³

CA

PA

CIT

Y ≤

200

00 m

³

CA

PA

CIT

Y >

200

00 m

³

30 m




Appendix A


/64

Table A9 - Distances between units within building Fire Zone

Rem

inde

r :

Not

es :

BU

ILD

ING

FIR

E ZO

NE

AB

CD

EF

GH

IJ

KL

MN

ALi

ving

qua

rters

7.5

BO

ffice

s7.

57.

5C

Wor

ksho

p/w

areh

ouse

1515

15D

Con

trol r

oom

7.5

7.5

15N

AE

Labo

rato

ry15

1515

15N

AF

Fire

sta

tion

3030

3030

30N

AG

Gua

rd h

ouse

7.5

7.5

157.

515

30N

AH

Boi

ler r

oom

(1)

15 (1

)15

(1)

15 (1

)15

(1)

15 (1

)30

15 (1

)N

AI

Ele

ctric

al s

ubst

atio

n30

3030

3030

3030

307.

5J

Inci

nera

tor (2

)30

(2)

30 (2

)30

(2)

30 (2

)30

(2)

30 (2

)30

(2)

30 (2

)30

(2)

NA

KO

verh

ead

pow

er li

nes

4545

4545

4545

4545

1545

NA

LSe

wag

e tre

atm

ent p

lant

/ sa

nita

ry la

ndfil

l60

6060

6060

6060

3060

3045

NA

MTe

leco

m s

helte

r / ra

dio

mas

t (3)

30 (3

)30

(3)

30 (3

)30

(3)

30 (3

)30

(3)

30 (3

)30

(3)

30 (3

)30

(3)

45 (3

)30

(3)

NA

NPe

rimet

er fe

nce

3030

3030

3030

530

3030

(4)

3030

(3)

NA

(1) :

Boi

ler u

sing

flam

mab

le g

as o

nly.

Dis

tanc

es n

ot re

quire

d fo

r boi

lers

usi

ng n

on h

azar

dous

liqu

id fu

el (d

iese

l oil)

or e

lect

rical

pow

er.

(2) :

Dis

tanc

es to

inci

nera

tor c

an b

e re

duce

d if

inci

nera

tor a

nd a

ppur

tena

nces

are

isol

ated

by

H-1

20 fi

re ra

ted

parti

tions

(ref

er to

GS

EP

SA

F 33

7).

(3) :

Use

tabl

e di

stan

ces

or (m

ast h

eigh

t + (2

0 %

or 5

met

res)

) whi

chev

er th

e la

rges

t.(4

) :G

ener

ally

, ove

rhea

d po

wer

line

arri

val s

tatio

n lo

cate

d at

the

perim

eter

fenc

e to

allo

w a

cces

s by

ele

ctric

al d

istri

butio

n C

ompa

ny.

This

tabl

e pr

ovid

es o

nsho

re d

efau

lt di

stan

ces

betw

een

units

with

in th

e bu

ildin

g Fi

re Z

one

and

not b

etw

een

units

per

tain

ing

to d

iffer

ent f

ire z

ones

. Fo

r def

ault

dist

ance

s be

twee

n Fi

re Z

ones

, ref

er to

Tab

le A

1.

All

dist

ance

s in

met

res.

Dis

tanc

es in

dica

ted

in p

rese

nt ta

ble

are

not o

nly

dict

ated

by

safe

ty c

onsi

dera

tions

, but

als

o an

d pr

inci

pally

by

cons

train

ts o

f con

stru

ctio

n, o

pera

bilit

y, a

cces

s an

d m

aint

enan

ce. T

hey

repr

esen

t CO

MPA

NY

best

eng

inee

ring

judg

emen

t, in

term

s of

Gen

eral

Ser

vice

are

a ty

pica

l lay

out.

Dis

tanc

es ta

ken

from

edg

e of

uni

t.




Appendix A


/64

Figure A9 – Typical sketch of onshore building Fire Zone

HE

D

J

AA

B

M

G

CC

FI

L

K

30 m

15 m

15 m

7.5

7.5

7.5

5 m

30 m

30 m

30 m

15 m

30 m

30 m

30 m

30 m

30 m

(3)(3)

30 m30 m

30 m30 m

30 m

30 m60 m

15 m

15 m

30 m

K

15 m

30 m

A B C D E F G H

ITE

MLI

VIN

G Q

UAR

TER

S

OFF

ICES

WO

RK

SH

OP

/ W

AR

EH

OU

SE

CO

NTR

OL

RO

OM

LAB

OR

ATO

RY

FIR

E S

TATI

ON

GU

AR

D H

OU

SE

BO

ILE

R R

OO

M

DE

SC

RIP

TIO

N

I J K L M

ELE

CTR

ICA

L S

UBS

TATI

ON

INC

INE

RAT

OR

OV

ER

HE

AD

PO

WE

R L

INES

SE

WA

GE

TR

EA

TME

NT

PLA

NT

/ SAN

ITA

RY

LAN

DFI

LL

TELE

CO

M S

HE

LTE

R /

RAD

IO M

AST

(3)

MA

ST

HE

IGH

T +

(20%

OR

5m

.) O

R 3

0m, W

HIC

H E

VER

IS L

AR

GE

STN

OTE

:

LEG

END

:P

ER

IME

TER

FEN

CE

FIR

E Z

ON

E (F

Z)R

ES

TRIC

TED

AR

EA

(RA

)D

ISTA

NC

ES

BE

TWEE

N U

NIT

S

mm

m




Appendix B


/64

Appendix B - Arrangement of interconnections between units

Appendix B provides guidelines for the arrangement of interconnections between units such as pipe-racks, cable routes and bridges.

B1. Pipe-racks Pipe-ways within a single process unit can be provided with numerous flanges, valves, vents, drains and shall be considered as being part of the unit.

Pipe-runs between different process units shall be grouped in pipe-racks (overhead or ground level), with the exception of pipes that are to be buried for specific reasons (e.g. freezing, protection against fire, explosion or traffic). Pipe-racks should be as straight as practicable and shall be located outside process units.

The main pipe-racks mainly consist of all welded piping, and the number of flanges, valves, vents, drains or sample points shall be strictly limited.

Pipe-rack runs above access ways shall be minimised. Crossings of access ways should be at right angles and not above access way junctions and bends. Pipe-racks should not pass over the main access ways for mobile fire-fighting means. A very special emphasis shall be put on the routing and location of the flare header (or sub-header) pipe rack that shall minimise its exposure to external hazards such as traffic accident, fire or explosion in a process unit or others.

Overhead pipe-racks should preferably contain one single layer of piping. In a multi-layer pipe-rack, pipes carrying corrosive fluids shall be on the bottom level. Cable trays supported by pipe-racks shall be above the piping layer. Cable trays shall be so arranged that any foreseeable operation carried out on the below piping layer will not cause damage to the electrical cable trays. This may be achieved by suitable spacing between layers or the use of mechanical shielding. The flare headers shall be on the bottom level layer.

Pipe-runs outside the plant area should be on pipe tracks at grade level.

B2. Cable routes Cable routes, cable segregation and cable installation shall be as per GS EP ELE 079 and GS EP ELE 364.

B3. Bridges (offshore only) Bridges between platforms normally constitute escape ways and primary means of evacuation and shall therefore not be exposed to high hazards, such as those coming from risers and/or high pressure equipment. Bridges used as escape ways and primary means of evacuation shall remain passable under any prevailing weather conditions. If necessary or imposed by local regulation a QRA shall be carried out to determine the best bridge location with respect to such hazards as risers or high pressure gas piping.

Net clearance above sea level shall include high tide, swell and, wherever possible, the air draught of the supply boats normally posted to the concerned installation.

Bridges between platforms shall be free of any equipment with the single exception of fire monitors located at a convenient distance from the platforms. Bridges shall not pass under the routine operation swing zones of cranes and shall not be considered as temporary storage areas for loading/unloading operations.




Appendix B


/64

The bridges should normally consist in two levels with:

• The lower level devoted to main access and moderate load carriage and shall have minimum clearances of 2.3 m (height) and 1.2 m (width) or width of design load + 0.8 m, whichever the largest

• The upper level devoted to the routing of pipes and cables, with a secondary access way having a 0.8 m minimum width clearance.

Both bridge level floors should preferably be grating.

Bridge movement shall be compatible with an easy balance of personnel walking on it, and the fixed point should preferably be located on the platform of first access.

Bellows shall be carefully positioned so as to allow an easy inspection and minimise the consequences of a leak (refer to Appendix C3).




Appendix C


/64

Appendix C - Equipment layout

C1. General

C1.1 Access ways and clearances The dimensions of the means of egress from any building are specified in GS EP SAF 221.

The dimensions of the Escape routes from the installation, which are part of the EER facilities, are specified in GS EP SAF 351.

Clearances for electrical equipment to be installed inside technical rooms and outdoors shall be as per GS EP ELE 001 and GS EP ELE 364.

This section is intended to specify the minimum requirements for the access ways and clearances that are not part of the required means of egress or escape routes and that should be provided where operation or inspection are required with a periodicity of at least once a month.

Minimum access ways clearance

Vehicles Pedestrians

Width 5 m

• Normal walkway: 1.0 m

• Elevated platform: 0.8 m

• Walkway receiving two or more routes: 1.2 m

• Maintenance access around equipment: 1.2 m

Headroom 4.5 m

• Normal walkway: 2.2 m

• Elevated platform: 1.9 m

• Maintenance access under equipment: 0.76 m

For dimensions of stairs, ramps, means of egress and routine access for personnel, refer to GS EP SAF 221.




Appendix C


/64

C1.2 Routine operation

Equipment Piece of equipment Requirement for location Recommended distance

Actuator and hand-wheel

May be conveniently reached when standing at grade level or from a permanent platform.

N/A

Horizontal spindle Between 0.75 and 1.5 metre above the grade or platform.

Should be 1 metre above grade level or platform.

Vertical spindle Between 1 and 1.5 metre above the grade or platform.

Should be 1.1 metre above grade level or platform.

Valve

Local position indicator

Clearly visible from working floor.

Positive isolations

Spades, spectacle blinds, removable spools

Accessible during operation without any requirement for scaffolding if access required with a periodicity of at least once a month.

N/A

Sampling Should be located at grade or accessible from a permanent platform.

Best location 1 metre above floor level.

Emergency showers and eyewash stations

Close to locations where personnel may be exposed to injurious or corrosive material such as laboratory, chemical injection skids, methanol storage or transfer units.

• < 15 metres away from hazard.

• 3 to 6 metres if possible or if the fluid is highly corrosive or irritative.

C2. Wells Distance between wells shall be governed by the rig foot print and by the need (addressed in the STATEMENT OF REQUIREMENTS and/or SAFETY CONCEPT) to keep wells in operation while the rig is performing drilling or work-over activities on an adjacent well.

X-mas trees and wellhead assemblies shall be accessible from any side for operation and maintenance. Casing pressure gauges shall be readable from grade or from a permanent fixed platform.

The wells spacing shall take into consideration wellhead series and all foreseeable multiple completions.




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The minimum width clearance around wellheads and appurtenances (e.g. chokes, valves, instruments, actuators) shall be 0.8 metre; the minimum clearance at grade or platform level shall be 1.2 metre.

Sufficient space reservation shall be available for drilling, workover, wire-line, stimulation or other well servicing activities, without interfering with production installation or production personnel.

To avoid collision between wells during drilling, a slot spacing of 2.3 m for a 24” Conductor Pipe (CP) and 2.5 m for a 30” CP is recommended.

C3. Unfired process equipment

Equipment Requirement for location Recommended distance

• Accessible from any side for operation and maintenance.

• Preferably, should be in open air at or near above grade level.

• Where handling flammable or toxic fluids, shall not be located in pits to meet any requirement (NPSH or others).

• Provide adequate space for lifting and handling facilities for maintenance.

• Provide retention basin.

• Retention basin preferably sloping downwards so that liquid hydrocarbons are collected and routed away from the ignition source.

• Provide adequately ventilated shelters for machine requiring in-situ maintenance or where a protection from the environment is required.

Pumps

LPG transfer pumps

• In open air.

• Preferably at the outer sides of installation, in a dedicated fire zone.




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Pumps handling hydrocarbon at pressures above 35 barg

• Can be grouped together (and matching access requirement as per Appendix C1.1).

• Onshore, > 5 metres away from other pump units.

• Offshore, > 3 metres away from other pump units.

Air-coolers4 • Hot air emitted shall not be a hazard or an inconvenience to personnel.

• No adverse effect on the operation of adjacent equipment.

• Onshore, ground around air coolers gravelled to limit dust movement.

• Onshore, space underneath air coolers latticed wherever necessary.

• Offshore, air coolers installed on the edge or in cantilever over the edge of the platform5.

• > 10 metres away from fired equipment (heaters) and hot spots (chimneys)6.

• Not be above or within less than 5 metres to fuel sources (e.g. compressors and pumps handling hydrocarbons)7.

• Minimum headroom of 2.5 metres for induced draught and 3 metres for forced draught, if access underneath is provided for inspection.

Shell/Tube exchangers8

• Bundle shall be readily withdrawn without any hindrance into an escape route or traffic path.


• Provide space reservation for 2 bundles (the defective and the new one) for bundle replacement9.

Cooling towers10

• Should be downwind from the rest of installation.

4 Air-coolers shall be considered as having a high ability in promoting the spread of a fire, and particular attention shall be paid to

their location with respect to any areas of special fire risk. 5 If not possible, it shall be assessed whether the deck under air coolers shall be open gratings or tight. 6 These distances are given considering that the air movement increases the fire spread and that the failure of a tube could

release additional combustible fluid to the fire. 7 Air-cooler may be located above pipe-racks, where practicable and economical, providing valves and flanges are avoided

underneath. 8 Units handling HFC-134 should be preferably located in their own fire zone, in such a way that the risk of HFC-134 to be

decomposed in toxic products when exposed to fire is minimized and/or shall be adequately fitted with passive fire protection. 9 Where economical and practicable, shell/tube exchangers may be stacked. 10 Cooling towers are a source of HC release and the fog they may generate should not cause corrosion or obstruct vision.




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Filters • Provide access so that the cartridges can readily be changed-out from grade or from a permanent fixed platform.


• Provide space reservation for 2 cartridges (the old one and the new one) for cartridge change-out.

• No equipment allowed above filters.

Process vessels

• All instruments, stand pipes or sampling points on one side of process vessels.

• Horizontal process vessels preferably perpendicular to the main pipe-rack onto which they are connected.

• No equipment over process vessels unless there is a tight deck in between.

• Onshore, at least 5 metres wide of unobstructed access on one side and normal access for operation (refer to Appendix C1.1) on the other sides.

• Offshore, at least 3 metres wide of unobstructed access on one side and a second access fulfilling the requirement of Appendix C1.1.

Process gas compressors

Offshore

• Preferably on the upper deck

• No equipment on top of process compressors except the seal-oil tank.

> 3 metres between compressors (from edge of skid).




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Onshore

• Downwind, on the periphery of their fire zone and as far as possible from ignition sources.

• Preferably perpendicular to the pipe-rack they are connected to.

• Provide an unobstructed access on two sides (a).

• Provide an unobstructed access on the third side facing the pipe-rack (b).


• (a) > 5 metres wide.

• (b) 10 metres wide

Driven by gas turbines

• Very special attention shall be paid to the location of degassing vents (lube oil tank) with regards to hot surfaces (e.g. chimneys).


> 5 metres to hot spots11

Desalters • On the periphery of the fire zone they pertain to, preferably downwind12.

• No equipment over desalters unless there is a tight deck in between.

• Heater-treaters, i.e. electrostatic desalters in which a flame tube is installed to enhance coalescence are not recommended onshore and are prohibited offshore.

• Offshore, 5 metres away from other process vessels.

• Onshore, 7.5 metres away from other process vessels.

11 Auto-ignition temperature of gas released by breathing vent may drop below 100°C. 12 Considering the large hydrocarbon inventory contained




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Sub-surface water pumps

• Provide protection against boat collision.

• Where practical, should not be on a side of the platform where a boat landing is provided.

• Provide sufficient head clearance above sub-surface water to allow change-out.


• Provide space reservation for 2 pumps and/or motors (the defective and the new) for their replacement.

Bellows/ jambles

In open air outside process units13 > 10 metres off the edge of the platform

13 Bellows/jambles constitute a weak point and are likely to become a release source.




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C4. Fired equipment


Fired heaters14 Refer to GS EP SAF 227

• Should preferably be at the outer sides of the installation in a dedicated fire zone.

• Away from fuel sources.

• Minimum spacing as per Appendix A, Tables A2 and A4 or as stipulated by local applicable regulation, whichever is greater.

• Whenever practical, should be at higher elevation than storage equipment or other bulk quantities.

• No equipment above fired heaters.

• Fired equipment comprising a fire tube, such as glycol re-boilers, shall be located and arranged so that the fire tube can readily be withdrawn without any projection to an escape route.

• The bolted flange should not be oriented towards an escape route or a traffic path.

• Provide adequate space for lifting and handling facilities for maintenance in particular for fire tube replacement.

Refer to GS EP SAF 227

14 Fired heater should be regarded as a main cause of hazard. They are permanent source of ignition. For further details and in

particular exhaust chimney, refer to GS EP SAF 227.




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Machinery15 Refer to GS EP SAF 222

• Any source of ignition should be located at higher elevation than storage equipment (or other bulk quantities of hydrocarbon).

• Air intakes (HVAC, gas turbines, internal combustion engines, air compressors, etc.) located away from areas where air contamination by dust, flammable or toxic gas can occur (a).

• Air intakes (HVAC, gas turbines, internal combustion engines, air compressors, etc.) located preferably upwind the installation (a).

• Separate air intakes and discharges to avoid cross contamination by re-circulation, taking into account natural wind effects (b).

• Locate air discharges16 from HVAC systems so that the waste air emitted is not a hazard or inconvenience to personnel and has no adverse effect on the operation of adjacent equipment.

• Air exhausts shall not create a specific hazard for air traffic, especially during approach.

• (a) > 2 metres from any classified hazardous area.

• (b) > 6 metres.

• Turbine exhaust shall be at least 30 metres away from the helidecks.

15For further details and in particular exhaust chimneys, refer to GS EP SAF 222. 16 Air discharges from ventilation systems serving hazardous areas shall be considered as sources of release and shall be sited

accordingly.




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C5. Piping


Risers, riser ESDV’s and conductor pipes

• Should be positioned or protected to minimize the likelihood of damage caused by ship impact and/or dropped objects.

• Riser ESDV’s should be located where they are unlikely to be affected by fires and explosion or any other damage.

• Wherever above requirement is not achievable, protect riser ESDV against radiation, blast, missiles and falling objects.

• Riser ESDV’s should be located to allow access for operation, maintenance and inspection.

• Risers are strictly prohibited under accommodation buildings with the single possible exception of existing installations and where the riser is protected with a Sub-Sea Isolation Valve (SSIV).

Pig trap • Oriented such as any failure of pig trap could not affect the integrity of the installation or of the nearby assets (e.g. temporary rig or bridged platform).

• Not oriented towards a main access way or a traffic path.

• Horizontal.


A minimum headroom of 0.76 metre above grade or platform for adequate drainage and inspection under the pig traps.

Manifolds • Pay particular attention to the access to and the operation of valves (refer to Appendix C1.2).

• Adequate space for lifting and handling facilities for valves change-out shall be provided.




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C6. Flares and vents

Equipment Requirement for location

Flares and burn pits

• Refer to GS EP SAF 253 & GS EP SAF 262.

• In the case of several flares or burn pits operating in parallel within the same fire zone, distances indicated in Appendix A - Table A3, are given by default and shall in any case be subject to a particular radiation and dispersion calculation note. These calculations shall address the particular requirements relative to simultaneous operation (e.g. tip maintenance) set forth in the OPERATING PHILOSOPHY.

Vents • Should be grouped as far as it is practicable.

• Vents creating a Zone 1 hazardous area17 should release in one single point as far as possible from manned areas and from sources of ignition.

• In addition to dispersion calculation (flammable gas and toxic gas when applicable) cold vents shall also be calculated to fulfil radiation criteria as per GS EP SAF 253 & GS EP SAF 262.

Flare piping Refer to Section 5.3.3 of the main document & Appendix C1.1.

C7. Storage


Storage tanks and vessels

Bullet vessels should be oriented such as in case of any explosion of the vessel the effects of the missile impacts of the ends of the vessel are minimized (for further details refer to GS EP SAF 341).

Trucks loading/unloading stations

• For flammable and combustible liquids, should be located near the plant gates to avoid truck traffic near process areas.

HC loading/ unloading stations

LPG loading/unloading stations18

• Should preferably be installed at the outer sides of the installation in a dedicated fire zone. The main roads to and from loading stations shall not cross the rest of the installation.

The main roads to and from loading stations shall not run parallel to the rest of the installation at a distance of less than 100 metres.

17 For specific requirement related to vents hazardous areas classification, refer to GS EP SAF 216. 18 Shall be considered as a main cause of hazard.




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Metering units

• Accessible from any side for operation and maintenance.

• Preferably be positioned at or just above grade.

• No equipment and no pipe-rack allowed above metering units.

Minimum spacing between 2 branches: 1.2 metres.

C8. Safety equipment


Fire-fighting equipment19

• As away as possible from equipment that could release a flammable gas un-ignited cloud.

• Preferably upwind the rest of the plant.

Fire monitors shall be 15 metres away from the edge of the fire zone they protect.

Life saving equipment

Refer to GS EP SAF 351.

PSVs and TSVs20

• Be readily accessible and fitted with all necessary access platforms and working areas for safe intervention21.

C9. Buildings

C9.1 Accommodation buildings and technical rooms Guidance about internal arrangement within living quarters and office building is provided in GS EP SAF 221.

Rules for the location of building depending upon their type and environment are provided in Section 5.5 of the main document. In addition and in the absence of special safety requirement, all building shall be spaced so as to provide clearance for access as per requirements set forth in Appendix C1.1.

C9.2 Process or utility buildings In the case of process or utility units being enclosed in buildings (e.g. to ensure sufficient protection against adverse weather conditions) the rules applicable to outdoor units remain applicable with the exception that minimum distances shall be considered from the edge of buildings instead of edge of units, in spite of the additional internal clearance between units and building walls.

19 For further details, refer to GS EP SAF 321. 20 For further details, refer to GS EP SAF 262. 21 PSV’s and TSV’s are likely to undergo frequent dismantling for calibration.




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Considering also that building require adequate ventilation, it shall be checked that ventilation air intakes and exhaust position remain compatible with the position of other units (either outdoor or enclosed) regarding hazardous area classification.

C10. Miscellaneous

C10.1 Air gap All safety equipment or process equipment having a safety function shall never be located in or under the air gap on an offshore installation.

The only exception to this requirement is for inlet and outlet ESDV’s that are located (by order of preference) as per Figure C1 - Offshore platforms ESDVs locations:

• Option 1: onto the drain deck just above the air gap (and below the cellar deck, this one being plated)

• Option 2: onto the cellar deck with adequate passive protection (PFP or separation wall)

• Option 3: within the air gap space. In that case, the design of ESDV’s and their associated instrumentation & piping (as well as their supports) shall take into consideration the maximum wave loads developed on each item of equipment.




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Cellar deck

Drain deck

Air Gap (1)

Centennial wave height (1)

Max surge height +

MHWS (1)

Separation wall

(1) Refer to GS EP ECI 001

LAT (1)

Option 1

Option 3

Option 2

Figure C1 - Offshore platforms ESDVs locations

C10.2 Cranes and lifting devices Refer to GS EP STR 002.




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Appendix D – Bibliographic references

Professional Documents

Reference Title

GE GAP 2.5.2 Guideline on oil and chemical plant layout and spacing

CCPS Guidelines for facility siting and layout

Regulations

Date Object Modified date Object

10/01/1969 Arrêté du 10 janvier 1969 fixant les règles d'aménagement et d'exploitation des usines de traitement de pétrole brut, de ses dérivés et résidus

12/09/1973 Arrêté du 12 septembre 1973 relatif aux règles d'aménagement et d'exploitation des usines de traitements de pétrole brut, des ses dérivés et résidus

04/09/1967 Arrêté du 4 septembre 1967 relatif aux règles d'aménagement et d'exploitation des usines de traitements de pétrole brut, de ses dérivés et résidus

19/11/1975 Arrêté du 19 novembre 1975 relatif aux règles d'aménagement et d'exploitation des usines des traitements de pétrole brut, de ses dérivés et résidus


19/11/1975 Arrêté du 19 novembre 1975 relatif aux règles d’aménagement et d’exploitation des dépôts d’hydrocarbures et des titulaires d’autorisations spéciales d’importation de produits pétroliers

09/11/1972 Arrêté du 9 novembre 1972 fixant les règles d’aménagement et d’exploitation des dépôts d’hydrocarbures liquides

28/04/2008 Arrêté du 28 avril 2008 portant modification de l’arrêté du 9 novembre 1972 relatif aux règles d’aménagement et d’exploitation des dépôts d’hydrocarbures liquides et de l’arrêté du 9 novembre 1972 relatif à l’aménagement et l’exploitation de dépôts d’hydrocarbures liquéfiés




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Regulations


09/09/1993 Arrêté du 9 septembre 1993 modifiant l'arrêté du 9 novembre 1989 relatif aux conditions d'éloignement auxquelles est subordonnée la délivrance des nouveaux réservoirs de gaz combustibles liquéfiés

02/06/2000 Arrêté du 2 juin 2000 modifiant l'arrêté du 9 novembre 1989 relatif aux conditions d'éloignement auxquelles est subordonné la délivrance des nouveaux réservoirs de gaz combustibles liquéfiés

30/10/2001 Arrêté du 30 octobre 2001 modifiant l'arrêté du 9 novembre 1989 relatif aux conditions d'éloignement auxquelles est subordonnée la délivrance des nouveaux réservoirs de gaz combustibles liquéfiés

05/06/2003 Arrêté du 5 juin 2003 modifiant l'arrêté du 9 novembre 1989 relatif aux conditions d'éloignement auxquelles est subordonnée la délivrance des nouveaux réservoirs de gaz combustibles liquéfiés

09/11/1989 Arrêté du 9 novembre 1989 relatif aux conditions d'éloignement auxquelles est subordonnée la délivrance des nouveaux réservoirs de gaz combustibles liquéfiés

02/01/2008 Arrêté du 2 janvier 2008 relatif aux stockages contenant plus de 50 tonnes de gaz inflammables liquéfiés relevant du régime de l'autorisation au titre de la rubrique n° 1412 de la nomenclature des installations classées à l'exception des stockages réfrigérés ou cryogéniques

Abroge et remplace l'arrêté du 9 novembre 1989 modifié (art. 16)




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Regulations


10/05/1993 Arrêté du 10 mai 1993 relatif au stockage de liquide inflammable sous pression

02/01/2008 Arrêté du 2 janvier 2008 relatif aux stockages contenant plus de 50 tonnes de gaz inflammables liquéfiés relevant du régime de l’autorisation au titre de la rubrique n° 1412 de la nomenclature des installations classées à l’exception des stockages réfrigérés ou cryogéniques

Abroge et remplace l’arrêté du 10 mai 1993 (art. 15)