Chapter 1

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SWT SURFACE WELL TEST SET-UP SRPC M. Manual

Chapter 1- Safety and Precautions

This information is CONFIDENTIAL and must not be copied in whole or any part, and should be filed accordingly by the addressee.It must not be shown to or discussed with anyone outside the SCHLUMBERGER organization.

TABLE OF CONTENTS

Chapter 1

Page

Safety and Precautions ..................................................................................................................4

1. General Rules............................................................................................................................5

1.1 Danger to Personnel...............................................................................................................5

1.1.1 Introduction.......................................................................................................................5

1.1.2 Responsabilities..............................................................................................................6

1.1.3 Personnel Safety. ............................................................................................................6

1.1.4 Operational Hints.............................................................................................................8

1.1.5 H2S Defense...................................................................................................................8

1.1.6 H2S Service. ....................................................................................................................8

1.1.7 H2S Toxicity......................................................................................................................9

1.1.8 H2S Detection................................................................................................................10

1.1.9 H2S Protection...............................................................................................................12

1.1.10 Reanimation...................................................................................................................15

1.1.11 Toxic Materials. .............................................................................................................20

1.1.12 Advanced Well Test Design.........................................................................................21

1.1.13 General Rules for Pressure Testing Surface Equipment..........................................291.1.13.1 General Safety Aspects of Pressure Testing ..................................................................29

1.1.13.2 Communications and Sealing off Pressure Testing Area..................................................29

1.1.13.3 Fluids for Pressure Testing...........................................................................................30

1.1.13.4 Environmental Aspects of Pressure Testing ...................................................................30

1.2 Danger to Equipment............................................................................................................31

1.2.1 Equipment Safety..........................................................................................................31

1.2.2 Equipment Installation on Classified Zones. ..............................................................37

1.2.3 Safety Standards...........................................................................................................38

1.2.4 Recommended Distances. ..........................................................................................41

1.2.5 Effect of H2S on the Equipment. ..................................................................................45

2. Emergency Shut Down Specific Rules. ...........................................................................47

2.1 Personnel Safety...................................................................................................................47

2.2 Equipment Safety..................................................................................................................47

Dominique SabinaPROVISORY

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3. Flowheads Specific Rules. ..................................................................................................48



4. Surface Safety Valves Specific Rules...............................................................................50



5. Sand Equipments Specific Rules. .....................................................................................51



6. Data Headers Specific Rules...............................................................................................52



7. Choke Manifolds Specific Rules. .......................................................................................53



8. Steam Exchangers Specific Rules. ...................................................................................55



9. Indirect Heaters Specific Rules. .........................................................................................56



10. Separators Specific Rules. ..................................................................................................57

10.1 Personnel Safety...............................................................................................................57

10.2 Equipment Safety..............................................................................................................58

11. Surge Tanks Specific Rules................................................................................................59



12. Gauge Tanks Specific Rules...............................................................................................61



13. Oil & Gas Manifolds Specific Rules. ..................................................................................62

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14. Pumps Specific Rules...........................................................................................................63



15. Booms Specific Rules...........................................................................................................66



16. Burners Specific Rules.........................................................................................................67



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Chapter 1

Safety and Precautions

There are three indicators of special types of care needed with tools that areused in the text of this manual:

Indicates danger to personnel.

Indicates danger to equipment

NOTE: Indicates special care needs to be taken

It is your responsibility to be sure that you and anyone working with you ornear the tool is aware to the risk described

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1. General Rules

1.1 Danger to Personnel

1.1.1 Introduction

Well testing operations deal with highly inflammable fluids at high pressures and temperatures.

As such, they require well-trained operators and well maintained equipments, especially in the presence ofgas or high GOR oils.Moreover, IT ESSENTIAL THAT THESE EQUIPMENTS, HANDLED BY COMPETENT OPERATORS BEINTALLED AND OPERATED IN ACCORDANCE WITH STANDARD PRACTICE AND SAFETYREGULATIONS.

A perfect understanding of all-operational steps, possible hazards and emergency shut-down procedures is aprerequisite for all well Testing operations and should be discussed with the client beforehand:

Do think safety when arriving at the well site. It is too late!Most of Well Testing jobs requires nowadays detailed and advanced planning.

Whenever possible, visit the well site to check for hazards prior to the job.Collect from the client (On the site or at his office) accurate information on:

- Completion or test string,- Well head pressure,- Produced fluids (H2S, corrosive fluids),- Need of hydrate inhibitors,- Set-up and distances between well testing devices (Heater, Separator),- Etc.

For long testing operations, relief crews must be made available. A tired operator is a potential danger for therest of the crew. Plan in advance with client what operations can or cannot be performed at night.

The general safety considerations related to the layout of the surface testing equipment are:

Equipment layout and spacing must be done in accordance with classified zones. All of the pieces of surface testing equipment must be grounded. The electrical connection required for certain pieces of surface testing equipment, such as the

transfer pump or the laboratory cabin, must be safe and approved. Piping used for high-pressure wells must be anchored. Piping must be color coded to identify the working pressure of the pipe. It is helpful if the piping is

labeled to identify the fluids passing through it. The dominant wind direction must be identified to properly orient equipment that vents or burns gas.

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1.1.2 Responsabilities.

Responsibilities must be clearly defined between Schlumberger and client before starting the job.

Schlumberger recognizes that the rig owner or clients have primary responsibilities concerning the safety of thepersonnel and Equipment, and we must respect the general and particular safety regulations prevailing on therig or the country.

It is the clients responsibility to ensure that rig safety regulations are understood and followed by our personnel(Alarm sound coding, etc.) and to ensure abandonment of the site or evacuation of a victim.But we are the specialists as far as our equipment and our techniques are concerned. Therefore, the actions tobe taken in case of emergency must be clearly defined beforehand. In particular, in which circumstances theSchlumberger crew chief must stop type operation.

It is the Schlumberger Base Managers responsibility:

- To organize the Schlumberger job in cooperation with the client: WHO does WHAT, WHERE and WHEN.- For H2S jobs, to verify that all Schlumberger crew members know what to do in case of contamination, how

to operate safety equipment and where it is located :

ON LOCATION, THE OPERATION MUST BE REHEARSED BEFOREHAND: A PRATICAL DEMONSTRATIONOF THE H2S REANIMATION KIT MUST BE MADE, DANGER AREAS DEFINED AND MARKED, ESCAPE

AND RESCUE ROUTES DECIDED.

One attendant of the rig crew should be present during the demonstration of the reanimation kit.

1.1.3 Personnel Safety.

On location, hold safety Meeting with rig or production crew. Review all operational steps, possible safetyhazards, open and shut-in procedures.

Know and practice emergency procedures, including fire, abandonment of the site. Review location andoperation of fire extinguishers.

Always wear safety equipment (Boots, fireproof loud colored coveralls, gloves, hard hat).

Firmly anchor to the rig structure or the ground all flowlines especially bursting disc line, safety valveslines, flow lines, etc.

Particular attention must be paid to hoses when used. Have hoses positively attached to heavy pieces ofequipment since they can easily swing under pressure. Check them for pressure ratings and damages.

Clean muddy slippery rig floors.

Clear area from unnecessary personnel, especially during pressure tests of equipments before the job. Do not smoke. Leave matches and lighters in the accommodations.

Do not use steel sledgehammers (sparks!) to tighten connections. Brass is a must. Make sure BrassHammers are in top shape. Serious injuries may happen from clips or brass cuttings.

When working on superstructures of derricks, etc. Wear safety harness.

When working above water, wear life jacket.

For night operations ensure that proper lighting is available.

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Safety with nitrogen

High pressure Nitrogen is more and more used in our techniques, for instance in FlowheadAccumulators, or to check and calibrate Separator Safety Valves

Safety is perfectly insured in countries requesting high standards regarding the quality control of thegases manufactured. However, in some other countries where the quality control of N2 gas is not asstringent it could be a lethal operation.

Fatal accidents with Downhole Test Tools explode while pre-charging Pressure Chambers with Nitrogenhave been reported.The cause seems to be that if pressurized N2 contains small percentages of oxygen it reacts with thegrease and oil, lowering the flash point and causing combustion.

After inquiring with Nitrogen suppliers, we can henceforth fix the upper safe limit for Oxygenconcentration in Nitrogen i.e. 10 PPM.

To check this concentration a Precision Oxygen Analyzer must be used:

The model 320 B Oxygen Analyzer from Teledyne Analytical Instruments is recommended. It is availablefrom Schlumberger NOM under Ref. N 59986.

High Pressure Pumps:

1. When releasing Pressure, always Bleed-off SLOWLY via Bleed-off vale of the Pump2. At each TRIM session, Pressure test the circuit downstream of the pump, including Pump Hose,

at maximum WP, with Bleed-off Valve closed. This check is also to insure that seal efficiency ofPump Bleed-off Valve and Check Valves is perfect.

3. When Pressure Testing Equipment, always start with the Pump Tank completely filled-up with testfluid.

4. While Pressure Testing Equipment, avoid refilling the Pump Tank. This is achieved most of thetime by evacuating the equipment to be tested, to insure Test fluid fills up complete theequipment to be tested: In case of accidental backflow, the quantity of fluid recovered in thePump Tank is thus lower than the volume of the Tank itself.

5. Make sure the Tank Filling Plug of the Pump is free to pop in a safe direction in case ofaccidental backflow. Use Pumping Units with large vents for that plug.

6. Close beed-off Valves before connecting a pump to any circuit to be pressurized.

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1.1.4 Operational Hints.

Remember that a well supposed with low H2S concentration may develop into a high H2S concentrationone.

Have escape ways prepared and clearly routed with labels. Comply with general and particular rig safety procedures to avoid conflict actions in case of emergency

especially rig evacuation. No H2S must be allowed to escape to atmosphere in a place where it can accumulate and be dangerous.

Wind direction should be monitored constantly. If a leak develops, every effort should be made to stop the leak at once. Shrinkage measurements must be performed with shrinkage tester in a well-ventilated position (breathing

set donned). If H2S is present, long range protection systems must be used (See hereafter). Breathing apparatus must be worn during all operations where personnel might be in contact with effluent,

for example :

- Surface sampling,- Changing DANIEL orifice,- Changing Chicksans,- Changing Chokes on Heaters, Floor Choke Manifolds,- Bleeding off lubricators,- Walking on Burner Boom,- Opening pig rap on fixed stationsetc.

Any operation or handling on the well testing line (opening Bop's, changing Daniel orifice, disconnection,opening or closing valves) must also steadily be observed by another operator or someone from the rigcrew, ready for emergency action. Do not hesitate giving alarm in case of any unusual behavior of anoperator.

Pilot circuits must be supplied with air, nitrogen or bottled gas (heaters). IN NO CASE SHOULD PILOTCIRCUITS BE SUPPLIED WITH SEPARATOR GAS IF H2S IS PRESENT.

If compressed air is used, care should be exerted to have it from a compressor having its air intake locatedoutside the danger area or windward.

1.1.5 H2S Defense.

For the H2S detection and protection (Passive defense) we do not force our locations to comply with givenprocedure or models. Follow particular rig descriptions; purchase what is available locally.

However, for H2S reanimation (Active defense) when speed is the most important factor, we have standardizedon one system only, so that everyone within Schlumberger worldwide is familiar with this system and canoperate it without delay.

1.1.6 H2S Service.

H2S properties

Color NoneOdor Very offensive, often referred to as rotten eggsDensity 1.189, heavier than air (1.000)

Explosive limits 4.3 to 46%Ignition temperature 500F 260CWater solubility Four volumes of gas in one volume of water @ 32F 0C

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1.1.7 H2S Toxicity.

H2S Toxicity

1 PPM 0.0001% H2S can be smelled

Caution: IF H2S exceeds 1 PPM, escape or useprotective equipment (breathing apparatus)

10 PPM 0.001% Working allowed for 8-hr maximum.

100 PPM 0.01% Smell disappears in 3 to 15 min, burns eyes andthroat

200 PPM 0.02% Smell disappears quickly, burns eyes and throat500 PPM 0.05% Loose sense of reasoning and balance,

respiratory problems within 2 to 15 min, needprompt artificial resuscitation

700 PPM 0.07% Becomes unconscious quickly, breathing stops,death occurs if not rescued and given artificialresuscitation immediately

1000 PPM 0.1% Unconscious at once, permanent brain damagemay result unless rescued immediately

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1.1.8 H2S Detection.

NEVER USE SMELL FOR DETECTION

Hydrogen sulfide is generally recognized by a characteristic foul odor. Prolonged exposure to lowconcentrations has a tendency to act upon the olfactory nerves, thereby dulling the sense of smell. This isimportant, especially to those who think they can detect dangerous concentrations by the sense of smell. Itacts on the eyes and respiratory system, resulting in irritation. Irritation to the eyes often causes severe painand may incapacitate the worker.

When high concentrations are present, death may occur before the odor is detected, death being due to lungparalysis.

1. Use of central monitoring unit :This unit is able to scan 4 to 6 detectors located up to 40 m apart and signals by sound and lightwhen H2S concentration is above a predetermined level near one of these detectors.

These expensive systems are normally used in heavy, permanent installations.

For the time being we consider that the rig operator should furnish such systems, However in somecases, in particular when Schlumberger is the only contractor, we may have to furnish the equipmentand charge the client for it.

They can be purchased from general Monitors, Draeger, etc.

Location of H2S detectors and alarms must be arranged with client.

2. Use of Lead acetate capsuleSchlumberger recommends the use of these capsules:

They consist of a tiny glass container containing lead acetate, and placed inside a cotton woolenvelope.

When the capsule is broken the lead acetate impregnates the cotton wool, which will darkenaccording to H2S concentration.

They can be used in large quantities to beacon work area and shall be located along strategic paths.

Their low price allows dense flaring .

They are very sensitive to H2S.

They shall be stuck near all possible source of leakage (Weco quick connection, chicksan swivel,flanges, DANIEL orifice bearer, valves, etc.).

A visual control of these strips has to be arranged on a regular basis (once or twice an hour).

The control shall be effected by an operator carrying an escape mask (see hereafter).

They also can be worn by all for individual protection.

There is no limit to the concentration of the capsule as long as the glass is not broken and it can beused several days after the glass has been broken.

They are cheap and we strongly recommend that all locations having to work in H2S environment,oeder some of them and do not hesitate to use them. They are advantageously used in light,temporary installations.

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Reference: Hydrogen Sulfide Detector, Ref.: 1709, available from:

SAFETY SUPPLY COMPANY214 King Street East

TORONTO ONTARIO M 5 A 1 J 8Canada

Telex: 065.24.390

They may also be ordered fromE.F.F. Manufacturing under ref.: G 826 528, per pack of 10 capsules.

3. Use of sniffers (Draeger) with the proper reactive tube :

67 19001 (1 to 20 PPM H2S)CH 29801 (50 to 600 PPM H2S)CH 29101 (100 to 2000 PPM H2S)

They can be used in different places and even where access is difficult or dangerous by using aflexible extension CH 7271).

The reactive tubes should be stored in sufficient quantity in a cool place (between 5C and 30C i.e.40F and 85F). If so, they are usable for 2 years.

We recommend that two sets be available on jobs when H2S is expected. They can be of the Dreagermake or any other similar equipment available locally.

Phone: Toronto 416 364.32.34

DRAEGER SNIFFER

For lower ranges of freactive tubethat is in low H2S concentrations.

The bellows pump should beactuated ten (10) times before

reading scale. In high H2Sconcentrations, actuate pump one

time and read scale.

DRAEGER H2S REACTIVE TUBE

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1.1.9 H2S Protection.

Practically, all products available on the market are similar, since they are based on physical or chemicalproperties of the substances.

The main point to watch is the design of the mask, especially:- eye protection and panoramic vision,- demisting of the glass while in use,- Possibility of wearing spectacles underneath.

a) Short range protectionMasks fitted with filtering cartridge (Attention!Use the proper cartridge for H2S) may onlyby used for escape.

They must be worn in waiting positionduring the entire operation.

Although manufacturers claim a long-rangeprotection with these masks, Schlumbergerpolicy is to consider them as short-rangeprotectors or ESCAPE SETS :

For given cartridge size, the efficiency ofduration of the cartridge is a direct function ofthe poison concentration and respiratoryrhythm of the user, both parameters being noteasily monitored.

Each crewmember must be provided with a ESCAPE SET (Mask and cartridge ready for use).

Two spare sets are also requested on location.

Any cartridge stored without protective plugs must be discarded.

Filtering for H2S are identified by the letter B and are painted in Grey (Adopted InternationalStandard DIN 3181).

The fitting to the mask is a round thread according to adopted International Standard DIN3183.

The ESCAPE SET must be worn around the neck in waiting position during the entireoperation.

This type of equipment is preferably purchased locally.We recommend PARAT from Draeger, 3S fromMSA, or similar products.

In selecting a mask the facility of putting it on shouldbe a criterium of the choice. Operators must be trainedto put them on quickly. Breards and moustaches mayhave to be shaved.

Before the job, eachoperator reveives a maskand a filtering cartridge.

Operators fits the maskand adjust straps forcorrect tightness (checkby plugging inlet whilebreathing.

The cartridge is thenscrewed to the mask.

Any cartridge foundwithout protective plugsmust be discarded.

After Job the cartridge isthrown away.

DRAEGER Type PARAT ESCAPE MASK

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b) Long range protection.

The masks as described above should never be used for work. Anytime work is necessary in contaminatedarea an airpack respiratory apparatus must be used.

It gives the protection needed to carry out continuously work in contaminated environment. This can last from afew minutes to several hours. Schlumberger does not normally perform such service, except when changingchokes, Daniel orifice, Sampling In emergency also we might be forced to use such protection equipment,especially in case of equipment breakdown or RESCUE of PERSONNEL.

It includes:

- Independent breathing apparatus, with compressed air bottles, similar to those used in divingoperations.

The autonomy depends on the capacity of the bottle, air-filling pressure, and on the job to be carried out(light or heavy ).

Example: with a consumption of 30 l/min:- A 4 liter bottle / 200 bars has an autonomy of about 20 minutes.- A 6 liter bottle / 300 bars has an autonomy of about one hour.

All existing products have an end of bottle indicator (sound or visual).

Many of them can be switched over to an air supply pipe.

They can be used in any climatic environment.

Here again we would suggest local purchase of equipment.

Airpacks should be of the overpressure type (contaminated air from outside cannot get inside). Again thefacility to put them on should be an element of the choice.

For your information, we recommend:

DRAEGEL Model P.A. 80 with pressurized Panorama Nova Mask and 5 l Bottle.

DRAEGER: Type P.A. 54 (Dorsal type) SIMPLAIR (ventral type) for work in limited space.

AUER Type BD 73/1800-3 (Dorsal type)

MSA Type BD EG (Ventral type)

2 Sets of INDEPENDENT BREATHING APPARTUS MUST BE GIVEN TO THE CREW

- Apparatus to be connected a general air supply pipe .Due to our particular working conditions, we do not recommend their use on an air oilrig since:

The hose can easily be cut, and poison gas inhaled.

The connection hose forces the user to return by the same route he took when entering the contaminatedarea.

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An escape bottle must be provided with this apparatus. This required additional attention.

- Recirculation apparatus (Not recommended).

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1.1.10 Reanimation.

Every location that may have to conduct H2S operation should have at least one kit at the site. Schlumbergerhas chosen the M.S.A. (Mining Safety Appliance) twin bottle kit.

The M.S.A. reference for Schlumberger is 91109011.

This model is Slightly different from the standard M.s.A. unit, since the automatic vacuum system to clean thepatient airways is replaced be a hand operated cleaner having the same efficiency and which does not wasteoxygen See emergency instructions hereafter.

All patient data for operating this kit are part given hereafter. See emergency Instructions.

M.S.A. Reanimation Kit may be ordered from E.F.F. Manufacturing under reference M 814 941.

Oxygen bottles & ManifoldOpen one of the valve manometers reads 200 bars.Open fully counterclockwise. Flowmeter needle moves erratically, thengoes back to zero.Wait for 5 minutes in this postion, obesving for leaks.Close .Close .Open .Pressure gauge needle kicks, then goes back to zero:Oxygen bleeds off,Manometer reads zero.Close .

Repeat the process for the other bottle.

Note: For additional safety it is recommended to weigh the bottles: Theweight when empty is stamped on bottle (ex: PV 3,23 kg) Add to this

CHECK LIST

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weight about 750 kg representing 550 liters O2 at 200 bars.

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Retec Valve / Coanda Effect:

At the output of the RETEC VALVE, connect item Test Balloon.Open one of the valves .Open fully CCWSlowly open ; adjust pressure between 10-15 cm H2O. Observe inflation and depletion of TEST BALLOON at a rhythm of10 to 15 cycles/min.Close , and .Disconnect TEST BALLOON.

Accessories:

Check that thread of adapter for STD oxygen bottle (item 13) fitsis available on the rig:In case of emergency, WELDING OXYGEN CAN BE USED!

Check visually bellows pump item . Connect it to the flexible hose item .Check Operation of Automatic One Way Valve.

Everyone of the crew check fits of mask on himself and also checks tightnessby plugging inlet while breathing.

REMEMBER: 2 Full Bottles = ONE HOUR Autonomy!

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1.1.11 Toxic Materials.

Hydraulic oil

According to MDSD Fr 1080, FINA Hydran B 2512 F.Dangerous substance: Phosphoric Ester

Warning: CE directives do not classify hydraulic oil. However care has to be taken.Wearing gloves, security glasses and protective clothes is recommended

In case of skin contact, wipe the maximum, wash with large amounts of soap and water. In case of eye contact, open eyelid and flush eyes with water for 15 minutes Do not ingest. If done accidentally, do not bring up. Call immediately the doctor. In case of inspiration inside the lungs especially in case of spontaneous vomiting-, rush to hospital.

Waste disposal method: discard the product in its disposal container, including any associated material, in anenvironmentally acceptable manner in full compliance with Federal State and local regulations.

Hydraulic oil is flammable up to 103degC. In case of fire, carbon dioxide, dry powder and fire fighting foams are recommended. Water is prohibited.

In any case, avoid the leakage and wipe correctly the tool, especially for tests at temperature.

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1.1.12 Advanced Well Test Design.

All surface testing equipment manufactured and operations performed by Schlumberger, obeys to a set ofrecognized standards, and internal guidelines.

The general standards and general Schlumberger specifications described below apply to all Schlumbergersurfaces testing equipment. Local authorities have issued additional regulations which relate to well testingoperations, such as:- Det Norske Veritas rules for mobile offshore units Pt. 6 DRILL (N)- UK Statutory Instruments N 289 and HSE Guidance Notes- NPD regulations for drilling, etc., for petroleum in Norwegian internal waters.

General standards

Surface testing equipment used by Schlumberger shall comply with the following standards:- API Specification 6A for Flowheads, valves and Chicksans- API RP 14E and API Specification 6A for choke manifolds- API RP 14E and/or ANSI B31.3 for piping- API Specification 12K for heaters and steam exchangers- API RP 14C for surface safety systems- API Specification 14A and 14D for surface safety shutdown valves, and ESD systems- API 16A Specification for Drill Through Equipment (Includes API Hubs)- ASME boiler and pressure vessel code Section VIII for pressure vessels- NACE MR-01-75 for all H2S service equipment.

Well Test Design

For high pressure/high temperature, and/or high rate well tests a HAZOP and a well test design review must becarried out for each test or project. The well test design review is based on the safety analysis techniquesdefined in API RP 14C, and emergency shutdown systems designed accordingly. For applications above10,000 psi and High Flow Rate: (High rate tests are defined as > 30 MMSCF/D for gas wells and/or > 8000BOPD for oil well) The following guidelines are recommended

- Basic 3-stage architecture of the safety systems with:

1) Well parameters (pressure, temperature, flow rate, H2S content, etc.) monitored continuously with redundantelectronic and manual systems; measured parameters compared with the operating envelope parametersdefined for the well test design

2) Emergency shutdown systems controlling wellhead valve, subsea safety valve and flowlines valve activatedby manual control, Lo/Hi pressure pilots, or fusible loops and temperature sensors.

3) Pressure safety valves venting from each section of the flowlines having a WP rating less than the maximumshut-in wellhead pressure.

- Redundancy of safety at every stage, with sufficient segregation of operations to prevent system failure due toany component breakdown.

- Total protection at surface:

a) On a semi-submersible rig, incorporate the Subsea-Tree into the ESD system

b) On a jack-up or land rig run an E-Z valve linked to the ESD.

c) Wellhead valve closure and shutdown of test equipment if well parameters exceed the operating envelope,the pilots are actuated or surface equipment essential to well control fails creating a safety or environmentalhazard; closure at subsea safety valve in case of catastrophic failure

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d) Bypass of the automatic ESD controls in a) and b) whenever wireline or coil tubing is in the well; only manualactuation allowed

- Operating time of the safety system commensurate with the well and reservoir characteristics; less than 10seconds full closure of the surface safety valves when operated manually or by the slowest pilot device.

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API 14 C S.A.F.E. Chart

DELAY SHUT DOWN HORN MESSAGE RECOMMENDED PRESSUREFLOWLINE ON ON SET POINT RELIEF

CONTROL CONTROL CONTROLINTERNAL PLC FLOWLINE PANEL PANEL PANEL

TIME VALVE AUDIBLE MESSAGE PLC OPERATOR 14th DEC 1993 Preliminary REV 1. ALARM INTERFACE

DEVICE SDV SDV PANELIDENT. SERVICE I.D. SAC NO. ALTERN. 001 002

FLOWLINE UPSTREAM PSL-001 N/A X X PSH NOT REQ AS MWHP bottom of sightglassLSLL-111 2 SEC X X X X 0 CM Bottom of sightglassLOOP X

D-002 PRESSURE PT-401 (4-20mA SIGNAL TO CPU IN CONTROL ROOM) THIS INSTRUMENT PERFORMS THE PSHH, PSL & PSLL PRESSURE FUNCTIONS.SURGE TANK PSHH-401 1 SEC X X X X 50 PSIG

PSH-401 1 SEC X X 35 PSIGPSLL-401 1 SEC X X 0 PSIGPSV-006 50 PSIG XLOOP X

OIL LEVEL LT-411 (4-20mA SIGNAL TO CPU IN CONTROL ROOM) THIS INSTRUMENT PERFORMS THE PSHH, PSL & PSLL PRESSURE FUNCTIONS.LSHH-411 2 SEC X X X X Top of sightglassLSH-411 2 SEC X X 20cm < top of sightglassLSLL-411 2 SEC X X Bottom of sightglassLOOP X

ESD MANUAL ESD ESD 1 N/A X X LOCATED ON DRILL FLOORPANEL-C001 PNEUMATIC SYSTEM

ESD MANUAL ESD ESD 2 N/A X X LOCATED AT CHOKE MANIFOLDPANEL-C002 PNEUMATIC SYSTEM

REMARKSALT. PROTECTIONPROCESS COMPONENT

API 14 CSAFETY ANALYSIS

FUNCTION EVALUATION CHART(S.A.F.E.)

Example of chart used in HAZOP analysis to log in the various levels of alarms and protections by segment.The information on each segment or equipment is derived from the S.A.T. (Safety Analysis Tables) for eachsegment, and from the general safety design philosophy. Examples of those are provided in the followingpages.

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Safety Design Philosophy

Customer :Rig :Well : Job N :Updated:

FIRST STAGEWell parameters ( pressure, temperature and flow rates ) are continuouslymonitored by the following :-

A) COMPUTER ACQUISITION SYSTEM1) Real time digital / analogue output of well parameters2) Hi/lo settings for any well parameters giving audible/visual alarm (manual reset)

B) MECHANICAL PRESSURE/TEMPERATURE RECORDERS1) Foxboro pressure/temperature recorder for wellhead2) Barton pressure/temperature recorder for separator

C) MANUAL PRESSURE/TEMPERATURE MONITORING1) Dead Weight Tester, manual or electronic for pressure at wellhead.2) Dial pressure gauges/pencil thermometers throughout the well test equipment.

DURING WELL TEST OPERATIONS, THE WELL PARAMETERS ARE CONTINUOUSLY MONITORED WITH CROSS CHECKS BETWEEN A, B AND C TO ENSURE ACCURACY.

SECOND STAGEEmergency shut down system

A) OVERALL SYSTEM CONTROLLING FLOWHEAD ISOLATION VALVE (SDV1) AND FLOWLINE ISOLATION VALVE (SDV2)THIS SYSTEM IS ACTIVATED BY : -1) Electrical ESD system.2) Manual pull buttons.3) Pneumatic hi pilots.4) Pneumatic ESD erosion probe.

THIRD STAGEPressure safety valves (PSV) venting to safe areas from the following points:

1) PSV3 located on flowline to burners to allow for pressure relief.2) PSV4& PSV5 located on the separator vessel to allow for pressure relief.3) PSV1,PSE1 and PSV 2 located on heat exchanger vessels to allow for pressure relief

in case of over pressure of steam vessels.4) PSV6 located on surge tank to allow for pressure relief.

This system is designed to protect from any blockage/rupture in the well test train betweenthe rig floor and burners

SAFETY SYSTEM PHILOSOPHY

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S.A.T. Tables

SAFETY COMPONENT : Customer :ANALYSIS Rig :TABLE FLOWLINE SEGMENTS Well : Job N :

Updated:UNDESIRABLE EVENT CAUSE DETECTABLE CONDITION PROTECTION

AT COMPONENT PRIMARY SECONDARY

15K FLOW SEGMENTOVERPRESSURE CHOKE FAILURE HIGH PRESSURE NONE NONE

ON HEAT EXCHANGER NOTE 1 NOTE 1BLOCKED LINE

LEAK DETERIORATION LOW PRESSURE PSL-001 ESD RUPTURE AND BACKFLOW PSL-201ACCIDENT SDV-002

1.1K FLOW SEGMENTOVERPRESSURE BLOCKED LINE HIGH PRESSURE PSH-301 PSV-003, ESD

LEAK DETERIORATION LOW PRESSURE PSL-301 ESDRUPTURE AND BACKFLOWACCIDENT

NOTE 1 : PSV NOT REQUIRED ON FLOWLINE SEGMENT PROVIDING MAWP>SITP

SAFETY COMPONENT : Customer :ANALYSIS Rig :TABLE SEPARATOR Well : Job N :

Updated:UNDESIRABLE EVENT CAUSE DETECTABLE CONDITION PROTECTION

AT COMPONENT PRIMARY SECONDARY

OVERPRESSURE BLOCKED OUTLET HIGH PRESSURE PSH-101,PSH-301 PSV-004, PSV-005PSV-003

UNDERPRESSURE OUTFLOW EXCEEDS INFLOW LOW PRESSURE PSL-101 ESD

OVERFLOW INFLOW EXCEEDS OUTFLOW HIGH LIQUID LEVEL LSH-111 ESDLEVEL CONTROL FAILURE NOTE 1

GAS BLOW-BY LEVEL CONTROL FAILURE LOW LIQUID LEVEL LSL-111 ESDNOTE 2

LEAK DETERIORATION LOW PRESSURE PSL-101 ESDAND BACK FLOW

NOTE 1 : EQUIPMENT DOWNSTREAM CAN SAFELY HANDLE MAXIMUM LIQUID CARRY-OVER. SEPARATOR CONTINUOUSLY MANNEDDURING OPERATIONS

NOTE 2 : EQUIPMENT DOWNSTREAM CAN SAFELY HANDLE MAXIMUM GAS RATES THAT CAN BE DISCHARGED THROUGH LIQUID OUTLET

SEPARATOR CONTINUOUSLY MANNED DURING OPERATIONS

Similar tables are provided for each item

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Surface SafetyEquipment overview

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Safety barriersSafety barriers and ESD requirements have to comply, as a minimum, to Schlumberger internal pressurepolicy. This is governed by an internal document: Pressure Operations Manual. The following table is anextract if this document.

Flowrateand/or

Shut-in Wellhead

Nature of Fluid

Pressure (psi) Oil Gas Oil H2S Gas H2S

High Flow RateGas > 30 MMSCF/DLiquid > 8000 bpd

S2 + ESDSS1D1

S3 + ESD SS1 D2

< 3000S2

SS0D1

S2 + ESDSS0D2

3000 < < 5000S2

SS0D1

S2 + ESDSS1D2

5000 < < 10,000S2 + ESD

SS1D1

S3 + ESDSS1D2

10,000 < < 15,000S3 + ESD

SS1D2

> 15,000Production string mandatory

S3 + ESDSCSSV

D0Legend S2 = Master valve + flowline valve

S3 = Master valve + flowline valve + SSV (Surface Safety Valve)SS0 = Subsurface valve not mandatorySS1 = E-Z valve or E-Z tree or SCSSVD1 = DST valveD2 = DST valve

+ DST safety valveD0 = Downhole valve non mandatory with production stringHigh flow rate = flow rate 30 MMSCF/D gas and/or 8,000 BPD liquidRemark: The above valve configurations are understood as a minimumRecommended setup and may be upgraded at customers discretion.

In addition to the Schlumberger policy, safety and regulation requirements from customer and governmentinstitutions will be implemented.Example of advanced well test design and safety HAZOP analysis, as per API RP14C, are described at theend of this section.

An ESD system is recommended for all well-test operation and should include as minimum of two remotecontrol stations:

One at the separator

One in an area away from all pressurized equipment.

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- These control stations are necessary to ensure the well can be controlled from more than one place.

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1.1.13 General Rules for Pressure Testing Surface Equipment

1.1.13.1 General Safety Aspects of Pressure Testing

Never tighten pipes under pressure.

Bleed off pressure and keep at least one valve open before and during loosening or tightening anyconnections.

Always flush lines properly prior to applying any pressure. Bleed air of vessels and piping at the highestpoint to make sure no air gets trapped in the system.

For pressure testing vessels apply low pressure first (250 psi) and observe for leaks before applying higherpressures.

Have sufficient gauges mounted on equipment to be pressure tested to be able to monitor pressure in linesat all times.

Discuss pressure testing program with companyman and pump operator prior to start to avoid anyconfusion (hand out a copy of the pressure test sequence to companyman).

The maximum test pressure on site is the rated working pressure of the equipment. Under nocircumstances should that pressure be exceeded at the wellsite. API-pressure tests to the equipment testpressure are only to be carried out in the Base under special safety precautions for the annual inspection.

Vessels with relief valves and rupture disks (separator) are to be pressure tested to 80% of the vessel ratedworking pressure on site. Do not carry out tests of relief valves at the wellsite.

All ESD pressure pilots are to be isolated during the pressure testing sequence.

Connections which have been pressure tested already are not to be loosened or tightened unless thepressure test is repeated afterwards.

1.1.13.2 Communications and Sealing off Pressure Testing Area

Seal off well-test area with tape and signs indicating that high pressure testing is in progress.

Also indicate pressurized pipes outside well test area as- Chicksans from pump unit to choke manifold- Oil and gas lines to burner booms.

Ensure no lifting operation takes place over pressurized equipment.

Obtain a work permit for pressure testing and inform OIM and companyman about the operation.

For mounting / dismounting plugs on burner booms and switching valves obtain over the side work permitand wait until standby boat is in position. Have one watchpost ready at all times who is in radiocommunication with the captain of the standby boat.

Be in constant communication with the pump unit via hand held radio during the complete pressure testingsequence.

Prior to start of pressure testing carry out a safety announcement over the rig intercom. Repeat safetyannouncement every hour if pressure tests are still in progress or announce the end of pressure testing.

Only personnel absolutely essential to the operation are allowed to stay within sealed off areas.

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1.1.13.3 Fluids for Pressure Testing

If it is certain that hydrates will not be a problem, seawater can be used for pressure testing.

If hydrate formation may be a problem on the test, pressure testing should be performed with a mixture of50% glycol and 50% seawater.

For critical tests (high-pressure gas wells) a mixture of 75% glycol and 25% water has to be used. Thisshould be mixed at the cement unit, ready for pressure testing.

Never use diesel for pressure testing surface equipment.

The use of nitrogen for special applications as medium for pressure testing of surface equipment ispossible but has to be discussed in town since a hydrostatic test to 1.25 x WP has to be carried out priorto the nitrogen test and additional safety precautions are to be taken.

1.1.13.4 Environmental Aspects of Pressure Testing

In case of environmental restrictions to purge fluids over the side (glycol content) pressure testing fluids canbe pumped back to the tanks of the pump unit using our own lines and the transfer pump. In this case abypass valve to the check-valve at the separator inlet has to be provided, which stays rigged up for thewhole test.

Another option is to use rig hoses (fire hose type) and an air driven pump to recycle pressure testing fluidsfrom our tank to the pump unit. Do not keep the tank full or partially full after the pressure testingsequence. Before initial well opening all vessels and tanks have to be drained fully below lower sight glasslevel.

The method of recirculating fluids is also interesting for desert locations where water has only limitedavailability.

Especially for performing meter calibrations big volumes of fluid are used. Therefore after each calibrationrun, tank contents can be recirculated via transfer pump and used for the next calibration run. At the end ofall meter calibrations tank contents are recirculated back to the pump tank and therefore disposed volumesare minimized to the content of surface lines.

To recover contents of separator vessel connect rig air supply to the top of the vessel and displace fluid tothe tank which is emptied by the method described above.

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1.2 Danger to Equipment

1.2.1 Equipment Safety

a) Transportation and Storage. Our equipment suffers most of the time from mishandling during transportation or storage. Make sure that it is handled by competent crane operators. Perfect communication between crane

operator and crew, especially off-shore where rig floor and supply boat are out of sight of eachother, is a must.

Make sure that correct slings and shackles are used. Reject short or worn out slings. Always protect slings against sharp angles. Lift equipments using the lifting eyes provided on their frames. The maximum permissible load to be lifted with slings having a rating A is a function of angle

between these slings and is given by the following table :

SLING RATING MAXIMUM PERMISSIBLE LOADSling angle between 0 and 45 Sling Angle Between 45 and 90

Kg Lbs Kg Lbs Kg Lbs500 1100 1000 2200 700 1550

1000 2200 2000 4400 1400 31001500 3300 3000 6600 2100 46502500 5500 5000 11000 3500 77005000 11000 10000 22000 7000 1550010000 22000 20000 44000 14000 3100020000 44000 40000 80000 28000 62000

Notes :- Remember that the angle to be taken into account is the maximumangle between slings.- Do not install slings giving a lifting angle exceeding 90.

For long period of storage :- Clean thoroughly equipments with steam and/or watre added with

corrosion inhibitor.- Scrape and repaint where necessary.- Grease all the threads, Weco unions etc. and cover them with

grease adhesive tape is blanking plugs are not available.- Open all the Ball Valves and close the corresponding piping by means of plugs.- Close all the Valves other than the Ball Valves.- Place all the ancillary equipment and accessories in the corresponding storage cases.- Close the man-holes, grease the Nuts.- Oil the Controllers Mechanisms. Protect the Controllers with plastic bags.- Check that all the metal labels giving the dates of the official tests are provided. Clean and

grease them, if necessary.

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- Place a plastic cover over the Rupture Disc line.

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b) Basic Rules for Utilization.Normally after the well stream leaves the well Head, the pressure rating may be used.

The rule is that a pressure containing process component should :

- Either be designed to withstand the maximum internal pressure which can be exerted on it underany conditions,

- Or be protected by a pressure relieving device (Safety Relief Valve or Rupture disc).

To Determine the system design pressure ratings it is necessary to show pressure rating boundaries onmechanical flow sheets. Each section of flow line or process component has an assigned operating pressuree.g. :

- From the Flowhead down to the Floor Choke Manifold the working pressure must be higher thanthe shut-in tubing pressure. This will lead to the choice of the Floor Choke Manifold Assembly.

- FOR SUBSEQUENT SECTIONS THE WORKING PRESSURE IS DETERMINED TO SUITPIPING CONNECTIONS.

Pipings and/or equipments are colour coded to recognize their working pressure :

Orange means 3000 psi WP (6000 psi T.P.)Red 5000 psi WP (10000 psi T.P.)

Black 10000 psi WP (15000 psi T.P.)White 15000 psi WP (22500 psi T.P.)

The item with the lowest pressure rating within a section determines the pressure rating of this section.

Make sure the Well Head equipment down to Choke Manifold is able to withstand the maximum expected shut-in pressure.

All other components are protected by making sure that pressure will always remain lower the rated workingpressure.

For all components where working pressure is lower than the shut-in Well Head Pressure, this protection isprovided by a normally closed (N.C.) Surface Safety Valve (S.S.V.) located on the flow line and remotelycontrolled by pilots preferably located on each pressure section. These pilots are adjusted to respond wheneverpressure increases above the allowed WP of each of these sections.

On high pressure tests (5000 psi < WHP < 10000 psi) or in case of sour gas, the Surface Safety Valve mustbe installed upstream of the Floor Choke Manifold.

The Surface Safety Valve is actuated by flow line pressure sensors provided on each flow line segment ofdifferent working pressure down to the separator.

Additional Safety is insured by the use of an emergency shut-down system (E.S.D.) acting on the Flow LineValve of the Flowhead. Use of ESD is strongly recommended whenever WH pressure exceeds 5000 psi.

On very high pressure tests (10000 psi < WHP

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When no Surface Safety Valve is used, it is the operators responsibility to check and make sure that thepressure always remain lower than the working pressure assigned to each section.

The separator is provided with pressure relieving devices (Farris Safety Valve and Rupture Disc).

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c) Practical Hints.

Torques to make-up sub-assemblies together must be observed (see relevant chapters).

Use only recommended fittings and connections listed in other chapter.

Have enough Chicksans between Flowhead and floor on floating rigs to allow for maximum expected heavemotion.

In case of gas, if use of Chicksan cannot be avoided, grease the Ball Bearings of Chicksan Swivels andchange the packing before testing.

Chokes shall exclusively be used for flow control. NEVER USE THEM TO SHUT-IN THE FLOW. Any fluidflowing through a choke must arrive perpendicularly to the needle of the choke an leave it in the direction of theneedle tip.

Gauge tanks should be grounded by a cable allowing static electricity (generated by friction of flowing fluids) toflow and avoiding flashes. This cable should have a minimum section of 1 cm2. Off-shore, the ground shouldbe a iron stake at least 1 m long, driven into the earth and watered regularity (once a day).

IN NO CASE ALLOW GAS TO FLOW TO THE TANK.

Peculiar precautions must be taken in the testing wells producing sand or sediments since this may lead tofast erosion of the pipes and equipment, especially if velocity is more than 30 m/sec. In such cases constantmonitoring of sand production and use of sand traps is highly recommended. (See FOH IV SANDMEASUREMENTS).

CORROSION DETECTION IN W.T. EQUIPMENT PIPES.

In the FIT-TRIM procedures for :- Manifolds,- Heaters Steam Exchangers,- Separators,

It is recommended to perform a thickness measurement of the accessible pipe walls with an UltrasonicThickness Detector such as the Krautkrmer DM2 .

This detector is already included in the 2 channel portable SANDEC equipment under L 842 847.

Measurement should be made on inlet and outlet elbows, tees, .etc. where maximum erosion is to beexpected.

A record of the thickness measurement on fixed reference points chosen by the operator will help to tracecorrosion or erosion and avoid unexpected failures.

The Krautkrmer DM2 works in ambient temperatures ranging from 10 to 50C (15 to 125F).

With a special Sensor it can operate on hot surfaces up to 200C (400F).

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d) Pressure TestsPrior to any pressure test, make sure that all flow lines are safety anchored or chained down to the rig.

Pressure tests are conducted exclusively with water. Water may be added with corrosion inhibitors.

It is recommended to let water flow rapidly through the well testing system to sweep out air or gas that may betrapped in high spots.

Also one thing must be clear :If the API requires that for equipments rated at less than 1000 psi WP the test pressure is 200% of theWP and for equipments rated at 10000 psi WP and above the test pressure is 150% of the WP, it mustbe understood that these test pressures apply only for official tests, performed at shops with adequatefacilities.

IN NO CASE THE RULE SHOULD APPLY AT THE WELL SITE, WHERE A PRESSURE TEST ATMAXIMUM 100% OF WP IS ONLY AUTHORIZED.

Devices protected with bursting heads or rupture disc shall never be tested at 100% WP, unless the safetydevice is removed and replaced by a plug.

A safe limit for testing these devices is 90% of WP.

The record of the pressure tests should be included in the final test report. Use the Foxboro Recorder or theDowell Schlumberger or any other recorder available.

The following pressure testing sequence is mandatory prior to any well opening. The different sub-assembliesare supposed pressure tested individually according to the RITE PROGRAMME (See relevant Chapters).

Should the customer requires exhaustive testing of the Floor Choke Manifold and the Heaters coils, blankingPlugs must be instead of adjustable and/or fixed chokes.

Otherwise, always close the valves located IMMEDIATELY UPSTREAM of the Chokes.

Testing the lines

The different sections must be hydraulically tested at working pressure.(see table Pressure Sequence Diagram hereafter)Best is to use a Service Company pumping unit connected to the kill line of Flow Head.

Checking the Safety circuits

SSV and ESD operation should be checked during 1 Testing the Lines .Do not forget that CAC Actuator located on the Flow Line Valve of the Schlumberger Flow Head has aSafety Head fitted with a Bursting Disc (Reference BAKER WH - DBMF 800) shearing at 7500 psi (525bar).

DO NOT EXCEED AN HYDRAULIC PRESSURE OF 6500 PSI IN THIS CIRCUIT.

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1.2.2 Equipment Installation on Classified Zones.

Classified Zones.

The information in this topic describes why classified zones were established, defines the classified zones, andidentifies which pieces of surface testing equipment are associated with which zones.

A well site is classified into areas, zones, or divisions based upon the probability that flammable gases orvapors may be present around a specific piece of equipment. For safety purposes, both the API and FrenchAssociation of the Oil and Gas Explorers and Producers have defined such zones.

The following paragraphs rank classified zones from most to least hazardous and define each zone. Zonerestrictions don't dictate the placement of all well test equipment. For example, the ESD and the oil and gasmanifolds, although usually placed in zone 2, are not restricted to a specific zone. However, other well testequipment is restricted to certain zones as described below.Zone 0Area or enclosed space where any flammable or explosive substance (gas, vapor, or volatile liquid) iscontinuously present in a concentration that's within the flammable limits for the substance. The borehole or thewell below the wellhead is zone 0.

Zone 1Area where any flammable or explosive substance (gas, vapor, or volatile liquid) is processed, handled, orstored; and where, during normal operations, an explosive or ignitable concentration of the substance is likelyto occur in sufficient quantity to produce a hazard.

The gauge tank is placed in a zone 1 because the presence of flammable gases in the immediate vicinity of thegauge tank vent is normal. Most of the electric-driven transfer pumps are designed for use in zone 1, however,their use in this zone may be subject to geographical restrictions or client approvals.At the choke manifold samples of well effluent are taken, typically at the beginning of a test. Because samplingcauses some gas to be released to the atmosphere, the choke manifold is usually placed in zone 1.Because the Flowhead is used as a means of introducing tools into the well during a well test, the area aroundthe Flowhead is classified as zone 1, otherwise the area around the Flowhead is classified as zone 2.

Zone 2Area where any flammable or explosive substance (gas, vapor, or volatile liquid) is processed and stored undercontrolled conditions. The production of an explosive or ignitable concentration of such a substance in sufficientquantity to constitute a hazard is only likely to occur under abnormal conditions.

The separator is placed in zone 2 because the separator only releases flammable gases or vapors underabnormal conditions, such as a leak. Diesel-driven transfer pumps can be located in zone 2 if they areequipped with automatic shut down devices, spark arrestors, inertia starters or special electrical starters.The indirect heater must be located in zone 2 because it uses a naked flame to heat well effluent. Because itssurfaces can reach high temperatures, the steam exchanger is also restricted to zone 2.

Clean ZoneArea where no flammable or explosive substances are processed, handled, or stored. This zone is also referredto as a non-hazardous or safe area. An example of a clean zone is the living quarters of an offshore drilling rig.

Note: Schlumberger's safety procedures recommend not overlapping classified zones within a well testinglayout. The definitions and the zone classifications can be found in the publication API-64B.

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1.2.3 Safety Standards.

The following drawings identify, for both onshore and offshore surface testing layouts, which pieces of surfacetesting equipment are associated with which zones.

OnShore Safety Standards

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OffShore Safety Standards

This list summarizes the key points illustrated in the "Onshore Safety Standards" and the "Offshore SafetyStandards" drawings.

Onshore, the area around the Flowhead is classified as zone 2 within a radius of 15 m (45 ft) and offshoreit is classified as zone 2 within a radius of 10 m (30ft).

In the event the separator vessel is overpressurized, the rupture disk will burst releasing effluent to theatmosphere. Because of this risk, the area around the separator rupture disk pipe is classified as zone 1within a radius of 5 m (15 ft) and as zone 2 within a radius of 10 m (30 ft).

For both offshore and onshore layouts, the area (3 m or 15 ft) above the roof of the gauge tank is classifiedas zone 1.

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1.2.4 Recommended Distances.

The following drawings show how the recommended distances between different pieces of equipment affect theonshore and offshore surface testing layout.

OnShore Recommended Distances

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OffShore Recommended Distances

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This list summarizes the key points illustrated in the "Onshore Recommended Distances" and the "OffshoreRecommended Distances" drawings.

Onshore, the separator should be located 25 m (75 ft) away from the wellhead. Offshore this distance may be reduced to 13 m (40 ft).

Onshore, the heater / steam exchanger should be located 30 m (90 ft) away from the wellhead. Offshore this distance may be reduced to 10 m (30 ft).

Onshore, the gauge tank should be located 30 m (90 ft) from the wellhead. Offshore, this distance may be reduced to 25 m (75 ft).

Onshore, the distance between the separator and the heater should be 30 m (90 ft). Offshore, this distance can be reduced to 3 m (10 ft).

Onshore, the distance between the gauge tank and the separator should be 25 m (75 ft). Offshore, this distance can be reduced to 15 m (45 ft).

Onshore, the distance between the heater and the gauge tank should be 30 m (90 ft). Offshore, this distance can be reduced to 15 m (45 ft).

Safety Standards.

The following standards, whichever the most stringent, have excerpted either from the API RP 50 B or from theSafety Recommendations issued by the French Association of the Oil and Gas Explorers and Producers :

Although the spirit of both reglementations does not differ very much, the API RP 500 B is restricted to theclassification of areas for Electrical Installations at drilling rigs and production facilities on land off-shore,whereas the French Recommendations cover also disposition of open fires and engines.

There is also a Schlumberger Policy, based on experience, to recommend that classified areas within a welltesting set-up should not cross or overlap.

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Correspondences between U.S. and French Standards.Classified Areas

US FrenchClass I, Division 1 Type 1 ZoneClass I, Division 2 Type 2 Zone

Production FluidsUS French

Group AAtmospheres containing acetylene

Category AGas or liquid hydrocarbons

Group BAtmospheres containing butadiene, ethylene, oxide,hydrogen, propylene oxide, manufactured gasescontaining more than 30% hydrogen (by volume)

Category BLiquid hydrocarbons having a flash point < 55C

Group CAtmospheres containing acetaldehyde, cyclopropane,diethyl ether, ethylene, isoprene, UDMH1, 1-dimethylhydrazine.

Category CLiquid hydrocarbons having a flash point between 500and 100C.C.1. Liquids at a temperature equal or above theirflash point.C.2. Liquids at temperature below their flash point.

Group DAtmospheres containing acetone, acrylonitrile, Ammonia,Benzene, Butane, 1-Butanol (Butyl alcohol), 2-Butanol (secondary butyl alcohol), n-buty acetate, isobutylacetate, ethane, ethylene dichloride, gasoline, heptanes,hexanes, methane (natural gas), methanol (methylalcohol), 3-methyl-1-butanol (isoamyl alcohol), methylethyl ketone, methyl isobutyl ketone, 2-methyl-1-propanol(isobutyl alcohol), 2-methyl-2-propanol (tertiary butylalcohol), petroleum naphta, octanes, pentanes, 1-pentanol (amyl alcohol), propane, 1-propanol (propylalchohol), 2-propanol (isopropyl alcohol), propylene,styrene, toluene, vinyl acetate, vinyl chloride, xylenes.

Category DLiquid hydrocarbons having a flash point 100CD.1. Liquids at a temperature equal or above theirflash point.D.2. Liquids at a temperature below their flash point.

The area around a Well Head is a Class I Division 2 (or type 2 zone) within a radius of :- 15 m (45 ft) on-shore- 10 m (30 ft) off-shore

CAUTION : The same area becomes a Class I Division 1/or type 1 zone in case of an eruptive well and in caseof intervention of a service unit on the Well Head.The area around a Separator is a Class I Division 2 (Or type 2 zone) within a radius of :

- 10 m (30 ft) on-shore- 3 m (10 ft) off-shore

CAUTION : The area around the rupture disc pipe is a Class I Division 1 (Or type 1 zone) within a radius of 5 m(15 ft) and a Class I Division 2 (or type 2 zone) within a radius of 10 m (30 ft).The area around a Gauge Tank is a Class I Division 1 (or type 1 zone) within a radius of :

- 15 m (45 ft) on-shore- 15 m (45 ft) off-shore

In both cases, there is a Class I Division 1 ( or type 1 zone) 3 m (15 ft) above the roof.

The outlets of Flares, Safety Valves, Ventsetc. are classified as Class I Division 1 (or type 1 zone) within aradius of 5 m (15 ft) and as Class I Division 2 (or type 2 zone) within a radius of 10 m (30 ft).

Gas fired heaters shall never be installed in classified areas.

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Open fires shall never be used in classified areas. Are considered as Open fires all systems producing orable to produce flames or sparks in open air or having surfaces susceptible to raise at high temperature,especially :

- Oven, Boilers, Flares,- Heating or lighting systems,- Welding plants,- Thermic engines except the one listed hereafter,- Non intrunsically safe electric devices or lines, or electric materials not in conformity with the

explosive environment typeetc.,- Living quarters where there are ovens or permission to smoke.

Gasoline engine are not allowed in classified zones.

Diesel engines are allowed in classified area if they are fitted with automatic shut-down devices acting on theintake and exhaust (overspeeding), spark arrestors, exhaust pipe orifices out of zone 1, inertia starters orspecial electric starters.

1.2.5 Effect of H2S on the Equipment.

Hydrogen atoms (nascent state) are adsorbed in-between the grains of metal and fragilize it, (Hydrogenembrittlement or sulfide stress cracking). This has nothing to do with corrosion. It is almost independent of thepercentage of H2S, it is extremely rapid, a few minutes under high stress, slower under low stress, and isaggravated by the stress itself, finally it is reversible : when aerated, material loses its brittleness after a while.

Specification to modify H2S equipment if necessary must be requested from EQT Department.

Definition of H2S Service.Two cases have to be considered to determine if an environment is H2S proof or not :

Gas system onlyBelow 65 psia of total pressure : no H2S requirements.*Above 65 psia Pressure (psia) x H2S content (PPM) < 50000

Oil + Gas system

The 50000 rules applies except if :Total pressure is below 265 psia ANDTotal pressure of gas is below 10 psia AND

Percentage H2S in the gas is below 15%.

In this zone, no H2S requirements.

Generally, the 50000 rule applies everywhere upstream of the tanks, and this giving verylow H2S contents (50 PPM at 1000 psi) , it can be said that as soon as the presence of H2S issuspected, everything upstream of the tank should be H2S proof.

Practically only H2S rated equipment is to be used down the WT line.

Basic rules :

ANY EQUIPMENT WICH CANNOT BE POSITIVELY IDENTIFIED AS H2S PROOF , MUST BECONSIDERED AS NON H2S PROOF.

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ANY EQUIPMENT ON WHICH ANY WELDING OPERATION HAS BEEN PERFORMEDOUTSIDE OF THE PROPERLY EQUIPED AND QUALIFIED SHOP IS NOT H2S RATED ANYMORE.

ANY INSTALLATION ON WHICH ONE COMPONENT HAS BEEN TAMPERED WITH, IS NOTH2S RATED ANY MORE.

ANY EQUIPMENT ON WHICH MODIFICATIONS HAVE BEEN MADE SHOULD HAVE THE H2SIDENTIDFACTION REMOVED.

ANY PIPING HAVING THREADED WECO CONNECTIONS IS CERTAINLY NOT H2S PROOF.ALL SUCH H2S EQUIPMENT ARE WELDED TOGETHER.

* Total Pressure is read be Pressure Gauge, i.e. pressure of all components together, in opposition to partialpressure which is the pressure of each components.

Pratical Hints :

If H2S is suspected or expected :- Pilot Circuits of Well Head Separators.shall NEVER be supplied with separator gas. Only rig air pressure

or a special air compressor (with air intake located outside the danger area) has to be used.

Nitrogen or propane bottles if available can also be used.

- Heaters also shall never be fired separator gas if H2S concentration is 120000 PPM. In this case only,diesel oil burners must be used.

- Oil Flow Metering with Gauge tank is PROHIBITED. Should customer insists, a Surge Tank must be usedand separate low pressure flare be laid.

- Avoid using SPITFIRE Burners for H2S tests since their back pressure is far higher, for a given rate,than for a SEADRAGON .

- Liquid inhibitors like :PETROLITE Kontol 100,PECHINEY No-rust PA 23, etc..,Can be injected in the Flow Head at a rate of 20 liters/million m3 of gas.

- Grease Chicksans with PETROLITE Kontol 147.- A communication network (e.g. talkie-walkie) between all crew is recommended.- Pressure testing : when testing effluent with H2S, pressure testing is a must and no leak must be tolerated.- In case of H2S, do not use Kimray gravimeter, but a Ranarex with vent connected to a safe area.

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2. Emergency Shut Down Specific Rules.

2.1 Personnel SafetyEmergency Shut-Down must be operated by competent operators only.

2.2 Equipment SafetyBecause it improves safety, using an ESD system is recommended for all well test operations.When the well head pressure exceeds 5,000 psi or whenever H2S is present, an ESD must beused.

A minimum of two remote control stations shall be set up: one at the separator and one in anarea away from all pressurized equipment. These control stations are necessary to ensure thewell can be controlled from more than one place.

Be sure to open the air vessel inlet valve to ensure that the ESD is operational, even in theevent of air supply failure. Energy stored in the vessel supplies enough air for about 10 closures.

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3. Flowheads Specific Rules.

3.1 Personnel SafetyA Flowhead is a safety device. As such, they must be maintained in perfect condition andoperated by competent people.

Only Schlumberger employees are allowed to operate Flowhead controls.

Perfect collaboration with the Tool Pusher or Client Representative and strict observance of therig shut-in procedures must be observed.

Operating Flowhead requires often acrobatic manipulations far above the rig floor : wearingSAFETY HARNESS is a must.

Assembling and disassembling Flowheads must be effected by competent specialists.Pressurized fluids, strong spring forces can be released during these operations.

Use only special tools and make sure hoisting facilities are available to handle sub-assemblies.

While lifting Flowhead to the floor, make sure that lifting ropes, shackles are in perfectcondition.

Do not lift the Flowhead by the eye bolts that are fitted to some Flowheads. The eye bolts arenot designed to support the weight of the Flowhead.

3.2 Equipment SafetyOnly Schlumberger employees are allowed to operate Flowhead controls.

During testing, numerous hydraulic hoses overcrowd the rig floor. Make sure the Flowheadcontrol hoses are neatly laid down, located, and well marked.

Do not use steel hammers to tighten wing union connections. Brass or copper hammers mustbe used to prevent sparks. The brass or copper hammer must be in good condition to avoidinjuries from metal chips that can break off of these hammers.

Always open a well slowly using the master valve to avoid the shock from a large pressure kickwhich can occur due to the difference in pressure between the atmosphere and the well.

For all types of gate valves, count the number of turns to open and close each valve, then backup the valves one-quarter turn to make it easier to open and close valves and to preventsticking.

For wireline jobs, make sure that the wireline string is totally inside the lubricator before closingthe swab or the master valve. If these valves are closed on the wireline string, they could bedamaged or cause damage to other equipment.

Make sure there are always enough piping lengths on the wing valves to manipulate the toolstring and to compensate for up and down movement (heave) of the offshore rig so the Flowheadis never submitted to lateral forces. On o

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Chapter 1