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Well SectionProcedures

Page : 1 of 54Rev No : 2Date : 12.03.99Doc No : DOP 203

Document No. Document Title

DOP 203 Well Section Procedures

TABLE OF CONTENTS

1.0 PURPOSE.................................................................................................... 22.0 SCOPE......................................................................................................... 23.0 RESPONSIBILITIES..................................................................................... 2

3.1 Senior Toolpusher.................................................................................................. 2

4.0 DEFINITIONS AND ABBREVIATIONS........................................................ 25.0 PROCEDURE............................................................................................... 2

5.1 Preparation Before Spud....................................................................................... 25.2 36" Hole Section.................................................................................................... 55.3 Installing 30" Hydraulic Connector, Marine Riser And Diverter............................ 125.4 26" Hole Section.................................................................................................. 135.5 Running 20" (or 185/8 ")......................................................................................... 195.6 BOP References.................................................................................................. 245.7 17" Hole Section............................................................................................... 245.8 12" Hole Section............................................................................................... 335.9 8" Hole Section................................................................................................. 415.10 6" Hole Section.................................................................................................... 495.11 Well Clean Up Prior To Testing/Completion........................................................ 525.12 Pulling BOP Stack................................................................................................ 54

6.0 REFERENCES........................................................................................... 547.0 ENCLOSURES............................................................................................ 54

RevNo

Date Preparedby:

Verified by: Approved by:QA and Safety

Managers

Reason for Revision

1 15.03.96 AMO WVE AMO As Per Request No.017 and 018

2 12.03.99 LVA / IMI ICO AJE / BNO As per ProceduralReview Scheme

G:\Management Library\ Drilling Operations Manual\DOP 200\DOP 203

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1.0 PURPOSE

The purpose of this procedure is to describe and give guidance on drilling the

various sections of a standard well.

2.0 SCOPE

This procedure applies to all Stena Drilling's Units.

3.0 RESPONSIBILITIES

3.1 Senior Toolpusher

The Senior Toolpusher is responsible for the implementation of this procedure.

4.0 DEFINITIONS AND ABBREVIATIONS

Ref. Procedure DOP 209.

5.0 PROCEDURE

5.1 Preparation Before Spud

The following hole section procedures do not include the weather limitations foreach operation undertaken, but these can be found in the Rig Specific WorkMethods and the Safety Case Manual for each rig.

5.1.1 General

Weather and deck-loading conditions will determine the scope of work that canbe carried out during rig move and positioning operations. The following areitems to attend to, if possible:

1. Clean all mud pits, shakers, flow-lines, sand traps and seal dump valves,as required, and prepare for mixing spud mud.

2. Slip and cut riser tensioner wires, if required.

3. Slip and cut guidelines as required, fit guideline connectors or splice eyes(Ref. Operators Well Programme and Rig Specific Work Methods).

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4. Move the guide base(s) to the moonpool area. The guide base to be usedwill be specified in Operators Well Programme. Install slope indicator tosuit location of rig sub sea TV camera system, paint guide posts with hoopsand check bolts and nuts on guide base(s) are tight and locked.Check dimensions between the guide posts to ensure that the guide is notbent (3.65 m) diagonal distance between post tops.

5. Carry out between wells inspection for sub sea and BOP equipment.

6. Check all equipment required for 36" hole section (where available on rig).

7. Pressure test standpipe and mud pump manifold valves as per Companytesting procedures and rig specific testing programmes contained in theRigSpecific Work Methods.

8. Check mud pump fluid ends as required, dress pumps with pistons andliners required by Well Programme. Reset and test high pressure reliefvalves for the liner safe working pressures as specified in ManufacturersManual.

9. Check cementing equipment: Standpipe, valves, chicksans and cementinghoses. Flush and pressure test as required.

10. Have Electrician check out sub sea TV system and if system is to be usedto monitor spud-in with no TGB, then check that clump weights are availableto run two guidelines.

11. The Electrician should ensure that Beacon has been recharged as long aspossible, minimum 24 hrs.

12. Check guide frame/bit guide.

5.1.2 Use Of TGB

5.1.2.1 When A TGB Is Used

A TGB is not normally run on the majority of the wells drilled. The use of a TGBmay be considered in the following cases:

1. High currents at the location (in excess of 2.5 knots).2. Well to be precisely positioned alongside another well.

3. Water depths greater than 650 ft.

The use of a TGB will be specified in the Well Programme.

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5.1.2.2 Considerations And Preparation Of TGB

There are several points to consider when preparing the TGB for running:

1. The sea bed must be firm enough to support the base whilst drilling the 36"hole. It must also be flat enough to avoid excessive tilting of the base.It may be necessary to inspect the seabed, carry out penetration tests andany remedial procedures. These will be specified in the Well Programme.

2. The base will require the addition of weighting material. This may be eitherin bulk form from a loading line or in sacks. If in sack form, punch holes inthe sacks after loading them into the base. This will make it easier to cleanout if the base is retrieved at the end of the well.

3. Place the TGB on the trolley. Install and secure the transponder in the

holder. Install a thin wire sling to the transponder for recovery by the ROV.

4. Install and check slope indicator reading before running the TGB (onfloating installations confirm with Control Room Operator that rig is levelwhilst doing this).

5. Make up and install the guide wires and SSTV guide lines. Use brass shearpins for SSTV guide lines - 45 kN (10,000 lbs) strength.

6. Check that all equipment and materials according to check list are onboard.

5.1.2.3 Running TGB

1. Make up TGB running tool and paint Engage/Disengage positions.

2. Attach the TGB-running tool to the Guide Base.

3. Pick-up the TGB and withdraw the trolley.

4. Orientate and run the TGB to the seabed with DDM locked, keeping thebase square to the rig, checking that the guide wires reel off steadily.

5. Land the TGB and check the slope indicator with the ROV/SSTV.Check positioning of beacons on the acoustic position control system.

6. If inclination is acceptable, release the TGB running tool. (Check the slopeindicator after the TGB is landed before and after releasing running toolwhich is commonly a J-Tool engaging in slots in the TGB.)

7. Measure setting string "out of the hole" when setting the Temporary GuideBase. Record the RT-seabed depth, and tide when TGB is set (check rigdraft).

8. Permanently mark four Guide Lines as a tide reference at the time the TGBis set on the seabed.

9. After the TGB is set and the setting tool retrieved, record the following:

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1) RT-sea level distance.2) Water depth.3) RT-seabed distance.

5.2 36" Hole Section

5.2.1 Introduction

Specific requirements will be issued in the Operators Well Programme.The following procedures are to assist in developing Rrig Specific WworkMmethods that might be required.

5.2.2 36 Hole Preparations

1. Check equipment checklist in Ref. Section 5.2.6.1.

2. Prepare BHA required as per Well Programme (Ref. Section 5.1).

3. In conjunction with Client measure 30" conductor pipe to determine correctfootage of 36" hole to be drilled. Inspect all joints, shoe joint, for debris andvisually check connectors for damage (ensure O-rings are fitted).The standard practice is to drill so that the PGB is located 5 - 6 ft above theseabed.

4. Inspect and service 30" running tool/installation tools. Make up 30" runningtool to stand of HWDP/5" S-135 and rack this in the derrick.

5. Make up cementing/circulating head to joint of HWDP/5" S-135 and lay outfor later use.

6. Check all handling equipment for 30" casing (Ref. Section 5.2.6.2).If casing is to be run using pad eyes then check slings and shackles of anadequate load rating are available and that there is sufficient oxygen andacetylene equipment ready for the job. If casing is to be run usingelevators, then cut any pad eyes fitted off and check that elevators will fit.

7. Using white paint, paint the float shoe, 30" conductor housing with singlestripes 2 foot apart for 10 ft below the housing.

8. Install posts and slope indicator on PGB, move same to moonpool areaready for moving to well centre.

9. Using white paint, paint the bit and bottom 8 - 10 ft of the BHA for bettervisibility sub sea.

10. Ensure that sufficient volume of spud mud is prepared to meet therequirements of the Well Programme.

11. Check with Cement Hand that his materials and equipment are prepared.12. Point 1 - 8 below may be done before spudding the hole:

1) Move the PGB to the trolley and move the trolley to centre ofmoonpool.

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2) Run 30" casing through the PGB.

3) With housing at rotary Run 5" drillpipe stringer inside the 30" casing.

4) Make up a running tool to the housing and land the housing in PGB.

5) Install lock down rings on the PGB and ensure that all bolts are tight.

6) Check the alignment between the 30" housing and the bullseye(s) areinstalled on the PGB. Install beacon holders.

7) Secure in cellar deck clear of well centre.

8) Keep casing filled up to water line when hung off in moonpool.

5.2.3 General Procedures

Hold Shallow Gas Drill.

Advise the standby vessel that 36" hole is being drilled and to stand off safedistance. If TGB has been run, permanently mark the guidelines at moonpoollevel to monitor same whilst drilling 36" hole.

Have a watchman in the moonpool area at all times whilst drilling in caseguidelines become tangled and for the possibility of shallow gas.

NOTE: It may be desirable to spud the well in at first light due to the possibility ofencountering shallow gas.

1. The 36" hole will be drilled with 36" fixed-arm hole opener and a 26" pilot bit.

2. Always spud with 5" HWDP on top of BHA.

3. Run 36" drilling assembly and tag seabed. Observe tagging with ROV orsub sea camera.

NOTE: Depth from rotary table to mudline and tide correction at the time theseabed was tagged.

4. Ensure that there is enough pipe left on the stand before drilling to preventany chances of the bit being pulled out of the seabed at the first connection.Approximately 30 ft should be adequate.

5. The ROV should always be kept on the seabed to monitor the spudding andas a reference to where the hole is.

6. To spud well the maximum WOB should be 22 kN (5,000 lbs), 600 gpmpump rate and bring in the top drive speed to between 20 - 30 rpm whenthe bit (and hole opener) has cleared the sea floor (Ref. Section 5.3.1 and5.3.2 in DOP 202).

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7. Gradually increase the WOB to optimum, 60 - 75 rpm for bit/hole openerand the pump output limited to 600 gpm for the first 30 - 40 ft to avoidwashing the hole. Continue to increase the pump rate to 1200 gpmapproximately as the hole gets deeper.

8. Drill 36" hole from seabed to casing point, taking returns to the seabed.Use sea water and sweep hole with 20 - 25 bbl hi-vis pills (minimum 100 -120 s/l marsh funnel) before connections. If hole cleaning is a problem,increase frequency and/or volume of the sweeps.

NOTE: Release the torque in the string slowly using the DDM prior to makingconnections. Fast torque release could result in the string backing off.

NOTE: These parameters are designed to maintain hole angle at less than 1throughout the Section.

9. Take directional surveys as required by Well Programme (Ref. Section 5.3.3in DOP 202).

If a TGB is run, drill approximately 2 m rathole.

If TGB is not run, extreme care must be exercised in order to drill the hole to theexact depth. Check the tide tables and with Control Room for the rig draft. Thedepth should be such that when the casing is landed the top of the housing willextend 1.5 m (5 ft) above sea bed.

At casing point, spot viscous mud in the hole. Make a wiper trip to 30 - 40 ft

below the sea bed and rest hole for approximately 1hr. If drag is experiencedon the trip out of the hole, make a second wiper trip and again displace the holewith high viscous mud. Repeat this process until drag, bridges and excessive fillare eliminated.

Before POOH to run casing, the complete hole volume should be filled withHi-Vis mud.

Strap pipe when POOH and stand back BHA and do not break off the bit.

If a TGB is run, great care must be exercised when POOH through the TGB.Have the compensator in an open position. Monitor the TGB with the subsea

camera and/or ROV.

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5.2.4 Running 30" Casing

1. Move PGB to well centre and attach/install guidelines. Check and noteslope indicator reading (confirm with CRO that rig is level when doing this).

2. Rig up as required to run 30" casing. Handle casing into the rig floor as perpicking up drill collars (Ref. Section 5.1.1 in DOP 202).

3. Run 30" casing as per Well Programme up to and including conductorhousing joint.

4. Run drillpipe stinger into casing using keyhole plate and 2 sets drillpipeelevators OR false rotary. Space out stinger to be approximately 40 ft from30" shoe once running tool is made up. Fit centraliser if required.

5. Make up 30" running tool to stinger and 30" Housing. Lower through rotarytable and latch same to PGB. Pick up and check proper engagement.Open purge valve(s) on running tool. Set guideline tensions as required tosupport minimum tension (estimated wire weight only).

6. Run 30" housing to sea level, make up DDM/Topdrive to string and fillcasing with sea water down running string and purge air from casing. Closepurge valve(s).

7. Continue running casing on 5" HWDP/S-135 drillpipe (take care not to turnstring whilst making up connections).

8. Fill pipe as it is run. Use ROV or subsea TV to assist stab-in to 36" hole. Ifit is necessary to move the installation or work the pipe to stab-in, mark thepipe to observe any twisting/turning effects. Prior to landing casing onbottom, make up joint with cementing head.

9. Land casing on bottom and adjust DSC to support landing string weight plus10%. Check measurements on casing and stick up above seabed (top ofPGB approximately 1.5 m above seabed). Check guidelines fortwisting/snagging. If possible, have ROV (if available) check orientation ofPGB to ensure that it has not turned. Check PGB inclination. If this isgreater than 1 it will be necessary to contact the Rig Manager.

NOTE: From the time when the 36" hole is completed until the 30" casing islanded, no off load or back loading operations should take place and thedraft should not be changed.

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5.2.5 Cementing 30" Casing

1. Cement casing as per Ref. Well Programme and Section 5.5.3 in DOP 202.

2. Lower the SSTV and check the Housing. Leave SSTV on bottom toobserve returns while cementing and check for possible leaks on thehousing running tool. The ROV may be used to monitor during theoperation and in addition should collect cement samples.

3. Make up cementing line to landing joint.

4. Break circulation slowly with rig pump using sea water. Observe 30" x 36"annulus with ROV or subsea camera to ensure that returns to seabed areachieved. Limit pump rate so that 30" x 36" annular velocity is equivalent toannular velocity used while drilling lower section of 36" hole. It is

recommended to pump a volume of sea water equivalent to 1.5 times thecombined capacity of the running string, cementing stinger and casingcapacity between end of stinger and 30" shoe.

5. Close valve on cement head and pressure test lines as required byWell Programme (normally to around 3000 psi).

6. If PGB inclination is less than 1 then proceed with cementing operations.

7. Lift the casing 0.5 m off bottom to mix and displace the cement. Use theDSC to hold the casing weight during cementing. After the cement hasbeen displaced, the casing is lowered, leaving the wellhead 1.5 m above

sea floor. If unable to lower the casing, the wellhead height above sea floorwill be max 2 m. Use the DSC to hold the weight of the casing until thecement has set up.

8. Mix and pump cement as per Well Programme, monitor returns at themudline throughout the job. Monitor the casing for settling while cementing.

9. Displace cement with sea water using cement unit. Watch out for thecasing floating while cement is being displaced. Take cement samples withROV if required.

10. Once cement in place, bleed off surface pressure on cement line and check

float is holding. If holding, set guidelines to working tension and releaserunning tool. If float is not holding, then pump volume bled back and holdshut-in pressure until cement takes initial set. Once cement takes initial set,release surface pressure and release running tool. Pull back and positionend of cementing stinger 3 m - 5 m inside top of wellhead and flushwellhead area with sea water at maximum rate. POOH and lay out 30"running tool.

NOTE: Observe for good returns while cementing and displacing. If not thefollowing should be done:

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11. Stab into the annulus between the 30" casing and the 36" hole with3" tubing and tag top of cement. If cement top is not tagged within 1 m ofthe seabed, grout the 30" casing to the seabed using tail in cement slurryand observe return on SSTV or ROV.

5.2.6 Equipment Requirements - 36" Hole

5.2.6.1 Drilling Tools

ITEM CONNECTIONSDOWN

CONNECTIONSUP

* 26" bit with nozzles 75/8" Reg Pin

* 36" hole opener 75/8" Reg Box 75/8" Reg Pin

Bit sub with float profile 75/8" Reg Box 75/8" Reg Box

9" steel drill collars 75/8" Reg Pin 75/8" Reg Box

* 36" string stabiliser(s) 75/8" Reg Pin 75/8" Reg Box

Crossover(s) 75/8" Reg Pin 65/8" Reg Box


Crossover(s) 65/8" Reg Pin 4" IF Box

5" HWDP 4" IF Pin 4" IF Box

* 65/8" HWDP 65/8" FH Pin 65/8" FH Box

* Crossover(s) 65/8" Reg Pin 65/8" FH Box

5" drillpipe 4" IF Pin 4" IF Box

Baker float valve

Totco ring

26" bit breaker

9" DC lifting subs 75/8" Reg Pin


9" DC elevators

* 65/8" DP elevators

5" DP elevators

9" DC slips

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8" DC slips

65/8" DP slips

5" DP slips

Drill collar and drillpipe dope

Drill collar and safety clamp(s)

Single shot survey equipment in sandline / slickline, sinker bars, overshotsetc.

* 9" TELEDRIFT tool 75/8" Reg Box 75/8" Reg Box

* Surface equipment for TELEDRIFT

* Gyro survey equipment (for directional or cluster well)

* Usually supplied by Operator

5.2.6.2 Casing Equipment

ITEM

* Permanent guide base assembly complete with guideposts

* Wellhead housing joint(s)

* Intermediate joints 30" casing shoe joint(s)

* Wellhead housing runningtool

* Remote guideline connectors to match PGB post tops

* Spares and tools for 30" connectors

* Guidebase slope indicators

* 30" handling equipment:

50 ton SWL pennants (matched set) complete with either 50 ton SWLshackles or 2 sets 30" elevators

350 ton long elevator links

Oxy/acetylene cutting equipment

Keyhole plate and 2 sets 5" drillpipe elevators for running stinger

Beacons for guidebase

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Fill up line for drillpipe running string

Cementing head complete with 4" IF pin connection

Cement hose/chiksans

Lo-torque valve(s)

Rags, light oil etc. for 30" connectors

* Cement and additives - mixwater required?

* Usually Supplied by Operator

5.3 Installing 30" Hydraulic Connector, Marine Riser And Diverter

If required by the Drilling Programme.

5.3.1 Operational Limitations

Weather conditions and forecast should be suitable so that running andinstalling the Hydraulic Connector and Marine Riser can be completed prior toarrival of any expected severe weather.

5.3.2 Preparations

1. Check that all equipment and materials according to the operators checklist

are onboard.

2. Visually inspect all seals, dogs and couplings on the riser and hydraulicconnector. Change the O-ring on the connector.

3. Inspect the bore of the flex joint and slip joint inner barrel shoe for wearprior to running.

5.3.3 Procedure

1. Pick up the hydraulic connector and place it on the trolley.

2. Run riser through the rotary table and install onto the hydraulic connector.Make up riser joints to the manufacturers recommended torque.

3. Install the guide lines and connect the hydraulic hose lines from the minihose reel to hydraulic connector open-close and to the dump valve.Function test same.

4. Run the SSTV or ROV to the wellhead to observe landing of the assembly.5. Pick up the slip joint and make up to last joint of riser. Land the slip joint on

rotary spider, release and extend inner barrel ready to land on wellhead.Open drill string compensator. Install booster hose.

6. Lower the hydraulic connector assembly using compensator and landassembly on wellhead and lock hydraulic connector.

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7. Make a pick-up test to 220 kN or 50,000 lbs.

8. Install the diverter module with the diverter handling tool landing and lockingsame into the diverter housing.

9. Circulate through all of the diverter lines and function all diverter valves.

10. Close the diverter bag and test the system.

5.4 26" Hole Section

5.4.1 Introduction

Specific requirements will be issued in the Operators Well Programme.

The following procedures are to assist in developing installation specificprocedures that might be required.

5.4.2 Operational Limitations

1. Drilling of the 26" hole can start and continue unless only when weatherconditions exceed the limits that are considered safe.

2. A maximum of 4 angular deflection full amplitude is allowed while drillingthrough the flex joint. This corresponds to an offset of 6.9% of the waterdepth.

3. In extreme cases, drillpipe may be tripped with a flex joint angle up to 6.

Consideration should be given to drilling an 8" or 12" pilot hole.

5.4.3 Preparations

1. Check equipment as per checklists. Drilling Tools (Ref. Section 5.5.2.1 andCasing, Casing List Equipment, Ref. Section 5.5.2.2).

2. Prepare BHA required as per Well Programme, also Ref. Section 5.1 inDOP202. (The BHA should be fitted with a non ported float valve.)

3. Prepare Casing required as per Well Programme, also Ref. Section 5.5 inDOP 202.

4. Measure, tally and number the casing as it is brought onboard the rig and inconjunction with client measure 20" casing to determine footage of 26"hole to be drilled, allowing for rathole required below 20" casing shoe(usually around 5 m).

5. Inspect and service 20" running tool/installation tools. Make up drillpipejoint/pup joint to the bottom of this. Length of drillpipe required to extend+/- 1.5 m below the bottom of the wellhead housing, once running tool ismade up, orspace out to suit sub sea launch plug.

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6. Make this assembly up to the wellhead housing. Check tool release andthen set to running position. Mark tool and housing to observe anyinadvertent back-off. Lay out the housing and running tool assembly.Take care to support the weight of the housing to prevent any bending ofthe running tool taking place.

or

The housing joint with running tool and sub sea cement plug could be stoodback in derrick prior to the 26" wiper trip before the casing job if required.

7. Make up cement head with dart/circulating head to stand of 5" HWDP andrack back for later use.

8. Drift landing strings.

9. Check the weight of the casing versus the capacity of the hoistingequipment. Always have a 250T 20" casing elevator available.

10. Paint 20" casing shoe and 18" wellhead housing with white paint toimprove visibility subsea. Highlight connector overlap indicator.

11. Make up guidance ropes for 20" casing if required. It is recommended todesign and fit a sleeve to allow for any inadvertent rotation of the casingduring running (especially in deep water). This will prevent ropes beingsnapped before the casing is stabbed into the well.

12. Mix initial volume of mud as required by Well Programme.

13. Ensure that sufficient mud materials are available to drill the 26" hole.

14. Check with Cement Hand that his materials and equipment areprepared.

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5.4.4 Open Water Drilling

This is the preferred method for drilling the 26" hole section as it greatlyenhances installation safety. In the event of a shallow gas risk, considerationshould be given to drilling a pilot hole (Ref. Section 5.7 in DOP 204).

5.4.4.1 General Procedures

Continue with shallow gas precautions as for 36" hole.

Advise the standby vessel that 26" hole is being drilled and to stand off a safedistance.

Run 26" drilling assembly to 30" wellhead. Observe stabbing of bit into wellheadwith subsea TV or ROV (if fitted). Use guide ropes/bit guide as required to

facilitate stab-in.

RIH to 15 - 20 ft above predicted top of cement in the 30" casing. (Checksurface cement samples for firmness. If cement is still soft then it may benecessary to wait on cement.) Break circulation, tag cement and check forfirmness. Report depth of top of cement.

Drill out cement and float shoe. Guideline parameters are: 10000 lbs. W.OB,40 - 50 rpm rotary speed , torque limit set to minimum required, and 1100 -1200 gpm flow rate using sea water with viscous sweeps as required to cleanthe hole (15 - 20 bbl sweeps prior to connections should be sufficient). If holecleaning becomes a problem, then increase volume and/or frequency of

sweeps. Drill to 20" casing point plus rat hole required. Once any stabilisers inthe string are past the shoe and in new hole then rotary speed may beincreased.

Take directional surveys as required by Well Programme(Ref. Section 5.3.3 inDOP 202).

At casing point, displace hole with Hi-Vis mud, then make wiper trip to 30"casing shoe. If excessive hole bridging or fill is seen then repeat wiper trips untilhole condition is good.

Displace well to viscous mud and POOH to run 20" casing. If necessary to keep

hole open, displace with weighted viscous mud. Wash 30" housing on trip outwith sea water.

Strap pipe on final POOH.

NOTE: Flow check and observe the well for flow at each connection and whendrilling sections to TD and at any other time you deem necessary by useof ROV or SSTV camera.

5.4.4.2 Shallow Gas - Riserless

Ref. Section 5.7 in DOP 204.

1. Well Control Manual WCO 200.

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2. Rig Emergency Preparedness Manual REM 300.

When drilling riserless, the main consideration is to move the rig clear of the wellin the event of shallow gas. Points to consider in preparing rig specificcontingency plans are:

1. Position windsocks/flags so that they can be sighted from all angles of theinstallation.

2. Position standby boat upwind and maintain regular contact with updates onactivities in progress.

3. Set up power distribution to switch power to anchor winches quickly.

4. Set up plan for personnel to go to winches (24 hour cover of these posts willbe required). Ensure that adequate training is given and tested by drills.

5. Have subsea TV on guidelines ready to run at all times. If ROV fitted thenhave this on standby ready to observe the well. Observe the wellheadduring tripping operations. Consider pumping out of the hole to maintain anadequate hydrostatic overbalance. Pump at all times when moving stringupwards.

6. Personnel to pay out guidelines will be required. Ensure that adequatetraining is given and tested by drills.

7. Prepare and rig up equipment and procedures to release and drop drillstring to enable rig to be winched clear. These will be required for thefollowing cases:

1) Bit on bottom and drilling.

2) Tripping.

Ensure that drill floor personnel are given adequate training and tested by drills.

8. Maintain good communications between on duty Barge Master, Toolpusher,Driller, Designated Winch Operators, Crane Operator and Deck Crew at all

times.

5.4.5 Drilling with Riser Installed

5.4.5.1 Introduction

It may be decided to drill out below 30" casing with riser installed. Commonreasons for this are:

1. To minimise build up of drilled cuttings on subsea templates.Cuttings are dispersed further from surface by wave action.

2. To enable mud-logging and any open hole electric logs to be run.

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3. If hole stability will require mud to be used.

5.4.6 Procedure

1. Recommended BHA according to the drilling program. A drillpipe float shallbe used (preferably non-ported).

2. Weight on bit - pilot hole. A maximum of 45 kN (10,000 lbs) should be usedwhen drilling out the cement in the 30" casing. This weight should be useduntil the upper stabiliser is below the casing shoe. The weight on bit shouldthen gradually be increased to optimum weight.

3. Rotary/DDM speed - pilot hole. To be as outlined in the drilling program.A maximum speed of 200 rpm shall be used to avoid drilling in the criticalrotary speed ranges.

4. Pump speed - pilot hole. A minimum circulation rate should be used whendrilling 17" pilot hole. Use the booster line to clean the riser if fitted.

5. Mud properties. Marsh Funnel viscosity should be in the 60/100 s/l range.All available solids removal equipment should be in operation. The mudweight in should not be allowed to exceed 9 ppg. At casing depth theMarsh Funnel viscosity should be raised to a uniform 100 s/l and the yieldpoint to minimum prior to pulling out of the hole for the wiper trip. Furtherdetails in the drilling program.

6. Wiper trips. After the viscous mud has been spotted, a wiper trip to the

30" casing shoe will be made. If any drag or bridges are encountered,the hole should be circulated again with the viscous mud and a secondwiper trip made. Controlling mud weight to 9 ppg or less is very important.Continue wiper trips and viscosity changes until the wiper trip can be madewithout problems.

7. Deviation control. Run directional surveys (magnetic single shots) at theend of each bit run and at casing depth. Run a multi-shot at casing depth.

8. Flow checking - 17" hole. Having drilled the pilot hole to casing depth,and after a satisfactory wiper trip has been completed, observe the well forflow. If the hole is stable, displace the riser with sea water through booster

line with bit at bottom and observe the well for 15 mins.

Open riser dump valve, lowering the water level in the riser to sea level.Observe the well with the SSTV for 30 mins. to ensure the well is stable.Close dump valve. Circulate bottoms up while monitoring for gas.

9. POOH with pilot bit to run logs (if required). If a gas reservoir is seenon the logs, plug back and set casing.

10. RIH with under-reaming assembly. Be sure to under-ream thecement inside-the 30" properly.

11. Weight on bit - 26" hole. A maximum of 45 kN (10,000 lbs) should beused when under-reaming with the 26" under-reamer assembly.

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12. Rotary/DDM speed - 26" hole. Under-reaming operations shouldcommence with a rotor speed of 50 rpm and should be increased to amaximum of 100 rpm.

13. Pump speed - 26" hole. A circulation rate of 270 m3/hr (29 bbl/min)will be required when under-reaming with the 26" assembly. Checkmaximum recommended pressure drop for the under-reamer in use.

14. Flow checking - 26" hole. After the 17" pilot hole is opened to 26"displace the high viscosity mud in the hold with a density equivalent to whatwas used when drilling/under-reaming. With the bit on bottom displace themud in the riser with sea water using the booster line and observe the wellfor 15 mins. Open dump valve and observe the well for 15 mins with SSTV.Should there be any question about the stability of the well, increase the

mud weight. Pull out of the hole slowly leaving the dump valve open andobserve the well. Watch carefully when pulling UR through hydraulicconnector to ensure that UR arms are closed. Have DSC in the openposition.

15. Pull the diverter and marine riser. Observe wellhead with SSTV whendisconnecting riser.

Make wiper trip with the 26" bit. Displace the hole with highvisc. mud prior to POOH. Volume used to be 100% in excess of holevolume. Measure pipe length when POOH.

5.4.6.1 Shallow Gas - Riser Installed

(Ref. Section 5.7 of DOP 204, Well Control Manual WCO 200 and RigEmergency Preparedness Manual REM 300.)

Considering the following additional points will assist in preparing rig specificcontingency plans:

1. Evaluate condition of diverter equipment and overboard l ines - howlong will they stand up to the battering they will take during a shallow gasblowout? Are there many bends and areas where excessive erosion willoccur? It may be prudent to develop procedures to drop the drill string,

unlatch the riser and pull the rig off the well.

2. Maintain all spare mud pits full of sea water. In the event of shallowgas, it is important to pump mud/sea water as fast as possible. Ensure thatDerrickmen are trained to line up rig pumps to sea water as quickly aspossible on hearing the general alarm. Sufficient pump rate required tomaintain gas wet. Maximum rate will increase erosion rate of diverter.

3. Open riser dump valves if fitted to maintain gas wet.

5.5 Running 20" (Or 18 5/8") Casing

NOTE:Safety

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If it is possible for the Compensator hoses to foul the stabbing board, the ontour Toolpusher shall lock out the Drill String Compensator and DDM carriagecontrol button to prevent retraction of the Travelling Block.

1. The 20" casing will not be run until such time as the drilling fluid andwel lbsore conditions are considered to be stable.

2. Pick up 20" casing as per picking up drill collars (Ref. Section 5.1.31inDOP 202).

3. Run 20" casing as per running casing (Ref. Section 5.5.2 in DOP 202).

4. Always have 250t 20"elevators and circulating swedge on drill floor when

running casing.

5. With threaded type float equipment, connections on bottom two casingjoints will be thread locked to prevent back off or connection failures whiledrilling out cement and float equipment.

6. Check float equipment for correct operation.

7. Run 20" casing as per Well Programme. Install guide ropes. Fill casingwith sea water/mud whilst running using DDM or dedicated fill up line.

8. Observe stab-in of 20" into 30" housing with subsea TV or ROV (if fitted)

and check guide ropes parted properly.

9. Run 20" casing up to and including last joint before wellhead housing.

10. If required run drillpipe stinger into casing using keyhole plate and 2 setsdrillpipe elevators. Space out stinger to be approximately 90 ft from 20"float equipment once wellhead housing and running tool are installed or ifusing subsea launch system check plugs are installed.

11. Pick up 18" wellhead housing and running tool. (Take care to support theweight of the housing to prevent any bending of the running tool.). Make upto 20" casing (connect stinger if in use).

12. Run 20" casing on 5" HWDP/S-135 drillpipe. Prior to landing off in20" housing, pick up and make up joint with cementing/circulating head.(May have already been stood back in derrick.)

13. Observe landing with subsea TV or ROV and take an overpull to ensure18" wellhead is latched in the 30" housing.

5.5.1 Cement 20" Casing

1. Cement casing as per Clients cement programme and Ref. Section 5.5.3 inDOP 202.

2. Make up cementing line to landing joint and pressure test lines as perWell Programme (normally to around 3000 psi).

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3. Break circulation slowly with mud pump using sea water. Monitor for returnsat the wellhead using subsea TV or ROV. Pump a minimum volume at leastequal to the capacity of the running string, cementing stinger and the casingcapacity between the end of the stinger and the 20" shoe. Limit the pumprate such that the 20" x 26" annular velocity is the same as that used to drillthe 26" hole.

4. Mix and pump cement as pre Well Programme. Monitor returns at thewellhead with subsea TV or ROV throughout the job. Displace cement withsea water using cement unit.

5. Once cement in place, bleed off surface pressure on cement line and checkfloat is holding. If float is holding then release running tool. Observe samewith subsea TV or ROV. If float is not holding then hold shut-in pressure

until cement takes initial set, bleed off and then release running tool.

6. POOH and position end of stinger 3 - 5 m inside top of the wellhead andflush wellhead area with sea water at maximum rate. POOH and lay outrunning tool. Strap landing string on POOH and measure distance fromrotary table to top of 18" housing. Apply any tide correction applicableand report this depth on the IADC report.

7. Inspect 18" wellhead and guide base area with subsea TV or ROV prior tostarting preparations to run the BOPS.

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5.5.2 Equipment Checklist for 26" hole

5.5.2.1 Drilling Tools


CONNECTIONSUP



9" Steel Drill Collars 75/8" Reg Pin 75/8" Reg Box

* 26" String Stabiliser(s) 75/8" Reg Pin 75/8" Reg Box

Crossover(s) 7

5

/8" Reg Pin 6

5

/8" Reg Box

8" Steel Drill Collars 65/8" Reg Pin 65/8" Reg Box

Crossover(s) 65/8" Reg Pin 4 " IF Box


Full opening safety valves 4" IF Pin 4" IF Box

(TIW / Kellyguard)

* Crossover(s) 65

/8" Reg Pin 65

/8" FH Box

* 65/8" HWDP 65/8" FH Pin 65/8" FH Box

* Surface equipment for TELEDRIFT

* Gyro survey equipment (for directional or cluster well)

Fishing tools for 26" hole


* 26"Under-reamer 75

/8" Reg Box 75

/8" Reg Pin

* 17" bit breaker

* 65/8" Drill Pipe 65/8" FH Pin 65/8" FH Box

* Crossover (s) 65/8" FH Pin 4" IF Box

5" Drill Pipe 4" IF Pin 4" IF Box

Baker float valve

Totco ring

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26" bit breaker



9" DC elevators


5" DP elevators

9" DC slips

8" DC slips

65/8 DP slips

5" DP slips


Drill collar and safety clamp(s)

Single shot survey equipment inc. sandline / slickline, sinker bars,overshots etc.

9" TELEDRIFT tool 75

/8" Reg Box 75

/8 " Reg Box

* Usually Supplied By Operator


ITEM

* 18" wellhead housing(s) complete with 20" casing joint

* 18" wellhead housing running tool complete with spares

20" casing crossover joint(s) - required if wellhead joint(s) has latch typeconnector(s)

* 20" casing joints

* 20" casing shoe joint(s)

* Spares and tools for 20" connectors - latch type

Guide ropes and shackles* 20" casing power tongs

* Hydraulic power unit

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20" casing manual tongs

20" casing single joint pick-up elevators

20" casing 150 ton side door elevators

350 ton long elevator links

20" casing slips

20" casing rotary bushings

20" casing safety clampWire slings for handling casing onto rig floor

Tailing-in rope for V-door

Fill up line for DDM/Topdrive or dedicated casing fill up line

Circulating swedge for 20" casing

Circulating / cementing head complete with 4" IF pin connection

Cement hose / chiksans

Lo-torque valve(s)

Lubricant for 20" casing connectors

* BOP test tool

* 18" nominal seat protector(s)

* 18" nominal seat protector(s) running / pulling tool

Emergency drillpipe hang-off tool assembly

18" wellhead gasket


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5.6 BOP References

Due to the specific nature of the operations, preparation and running of the

BOP stack is covered in the Rig Specif ic Information / Procedures WorkMethods Manual RSI 300.

5.7 17 " Hole Section

5.7.1 Introduction

Specific requirements will be issued in the Operators Well Programme.The following procedures are to assist in developing installation specificprocedures that might be required.

5.7.2 Preparations

3.1.1.1.1.1.1.1.1Run 18" BOP stack and marine riser (Ref. Rig SpecificInstruction Manual (RSI 300) andWork Methods and Well Programme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Test BOP on seabed (Ref. Subsea Well Control Procedures,Rig Specific Work Methods Instruction Manual (RSI 300) andand WellProgramme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Test choke and kill manifold valves, and standpipe manifoldvalves etc. (Ref. Subsea Well Control Procedures, Rig Specific Work MethodsInstruction Manual (RSI 300) andand Well Programme).3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Check that drill floor equipment for kick-control is available.Inside BOP, spare Kelly valve, BOP kick joint and inside BOP dart to be readyfor use (Ref. Rig Specific Instruction Manual (RSI 300) andWork Methods andWell Programme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Install 18" nominal bore protector in wellhead.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up emergency drill string hang-off tool assembly andstand same back in derrick.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Prepare BHA required as per Well Programme, also Ref.Section 5.1 in DOP 202).

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check equipment as in lists (Ref. Under Section 5.7.6).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Lay out 26" drilling assembly, prepare and make up 17" (or16") BHA required as per Well Programme (Ref. Section 5.1 in DOP 202). 3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Prepare 133/8" casing as per Well Programme and Section 5.5

in DOP 202.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Remove lock ring from cement hanger on exploration wells.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check the weight of the casing versus the capacity of the

hoisting equipment.

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3.1.1.1.1.1.1.1.1Run 17" (or 16") BHA to approximately 20 ft above predictedtop of cement inside 20" casing. Break circulation with sea water, tag cementand check for firmness. Report depth to top of cement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill out cement and 20" float equipment. Guideline parametersare: 10000 lbs max WOB, 40 - 50 rpm, torque limit set to minimum required, and1100 - 1200 gpm flow-rate using sea water.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1After drilling out cement and cleaning to bottom of rat hole, drill3 m (10 ft) of new formation. Circulate and condition mud and perform leak-offtest. Take care to avoid cement contamination of same.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill to 133/8" casing point plus rat hole required. Once

stabilisers are into new hole then rotary speed may be increased. Adjust WOBand rpm to achieve best rate of penetration.

NOTE: DDM speed. To be specified in the drilling program. A maximum speedof 200 rpm shall be used to avoid drilling in the critical rotary speedranges. The proper use of the rotary brake, maintaining constant bitweight and rotary speed are important factors in the prevention oftwist offs and back offs when drilling with heavy BHA. Proper make upof drillpipe and drill collar connections are another essentialconsideration in the prevention of drill string failures.

3.1.1.1.1.1.1.1.1Pressure tests of the BOP should be conducted after

installation, after setting casing, and before drilling into any known or suspectedhigh pressure zones. Otherwise, these tests should be conducted at regularintervals but not more than once every week. On installation each componentshould be individually tested to a low pressure (around 200 psi) and to thegreater of 70% of rated working pressure or the maximum pressure expected inthe upper part of the casing. An exception is the annular preventer which maybe tested to 50% of its rated working pressure to minimise pack off elementwear or damage.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Take directional surveys as required by Well Programme (Ref.Section 5.3.3 in DOP 202).3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1The mud properties and control will be dictated by the WellProgramme - General Ref. Section DOP 205 Drilling Fluids.6.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1At section TD circ until shakers are clean, then POOH to runlogs. Should any drag, bridges or fill be encountered make a wiper trip tobottom. Once hole conditions are good, POOH to run open hole electric logs.Recommended treatment to the mud must be based upon whether the problemis of rheological, chemical or pressure character.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Rig up and run open hole logs as per Well Programme. Rigdown loggers (Ref. Section 5.4 in DOP 202). If the logs are not going tobottom due to the same problems in (8), further treatment shall be done during

the wiper trip to follow.3.1.1.1.1.1.1.1.1

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3.1.1.1.1.1.1.1.1After logging the well, it is recommended to make a wiper tripprior to running casing. Measure pipe length when POOH after final wipertrip, ifnot already done on trip out before logging. Wash wellhead with bit whilePOOH - to retrieve wear bushing (only if wellhead tools do not have dedicatedjetting system).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Prior to the wiper trip before running casing, pick up the 13 3/8"casing hanger and make up the running tool with subsea plug launchingassembly attached. Stand back running string in derrick which should be driftedfor 133/8 casing jobs. If to be run on 133/8 csg. lay hanger assembly out again.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up cementing and dart launching head to a stand of 5"HWDP and rack in derrick.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1On trips, while out of the hole, the shear rams will remain in an

open position. The trip tank shall be monitored while the drill string is out of thehole.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Abnormal pressure zones may be penetrated while drilling thissection of the hole. Drilling breaks will be flow checked after a maximum of 3 m(10 ft) formation has been drilled.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1RIH with drilling assembly for clean-up trip if required. Circulate

and condition hole ready to run 13 3/8" casing. Wash wellhead area onPOOH to run casing (only if tools have no jetting facility). Retrieve 18"nominal bore protector.

3.1.1.1.1.1.1.1.1

5.7.4 Running 133

/8" Casing

NOTE:Safety

If it is possible for the Compensator hoses to foul the stabbing board, the ontour Toolpusher shall lock out the Drill String Compensator and DDM carriagecontrol button to prevent retraction of the Travelling Block.

3.1.1.1.1.1.1.1.1Rig up and run 133/8" casing as per Well Programme and Ref.Section 5.5.2 in DOP 202.

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check float equipment for proper operation.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Fill casing with mud as it is run using the fill line/DDM. Ensurecasing completely full every five joints.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Monitor well on trip tank while running casing.3.1.1.1.1.1.1.1.1Run surge pressure program to check maximum allowablerunning speed.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Ensure circulating swedge/water bushing and crossover to 4"

IF should be on the rig floor ready for use.

3.1.1.1.1.1.1.1.1

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3.1.1.1.1.1.1.1.1Make-up 133/8" casing hanger assembly to casing string. Checkrunning tool etc. as required by Well Programme and Service Engineer.

3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Do not exceed 90% of DSC capacity when landing casing. Forheavier casing, if weather permits, land without using DSC, and fill entire casingstring with mud during running. Avoid floating casing strings as much aspossible due to well control problems.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Run 133/8" casing on landing string (5" HWDP/S-135 or 133/8"

casing), pick up landing joint with cementing head and land out casing inwellhead. Confirm depth.

5.7.5 Cement 133/8"

3.1.1.1.1.1.1.1.1Cement casing as per Clients Cement Programme and Ref.

Section 5.5.3 in DOP 202.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up cementing line to cement head and pressure test linesas per Well Programme (normally around 3000 psi).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Break circulation slowly with rig pumps using drilling mud.Circulate at least the volume of casing and landing string. Limit pump rate suchthat 17" x 133/8" annular velocity is the same as that used to drill the 17" hole.Observe for mud losses while circulating.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pump spacer ahead as required by Well Programme.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Mix and pump cement as per Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Release plug launching dart, displace same to top subsea plugwith cement/spacer. Shear out plug.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Switch to mud pumps and displace plug to float collar withdrilling mud.

NOTE: Max allowable over displacement is half the volume between float collarand shoe.

3.1.1.1.1.1.1.1.1When plug has bumped, pressure up casing to test pressure

required by Well Programme. Hold pressure for time required by WellProgramme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Bleed off casing pressure and check float is holding. If float isholding then release casing hanger running tool. If float is not holding maintainfinal displacement pressure on casing until cement takes initial set. If anypossibility of cement at the wellhead, flush through choke and kill lines andcirculate riser contents whilst waiting on cement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Set casing hanger seal assembly as per Well Programme andService Engineer.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Pressure test seal assembly/BOP as per service engineersinstructions/ Well Programme.

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3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1POOH and lay out running tools. Apply any tide correction

applicable and report the depth of the hanger in IADC Report.

5.7.6 Equipment Checklist - 17" Hole

3.1.1.1.1.1.1.1.1 Drilling Tools

Vertical Well


CONNECTIONSUP

* 17" bits with nozzles - 75/8" Reg Pin

* 17" near bit stabiliser(s) 7

5

/8" Reg Box 7

5

/8" Reg Box

* Bit sub with float profile 75/8" Reg Box 75/8" Reg Box


17" string stabilisers 75/8" Reg Pin 75/8" Reg Box

X/O 75/8" Reg Pin 65/8" Reg Box


8" drilling jars (up/down) 65

/8" Reg Pin 65

/8" Reg Box

Crossover(s)




* 65/8" HWDP 65/8" FH Pin 65/8" FH Box

* 65

/8" drillpipe 65

/8" FH Pin 65

/8" FH Box

* Crossover(s) 65/8" FH Pin 4" IF Box

Hydril drop-in sub c/w dartand retrieving tool

4" IF Pin 4" IF Box


Full opening safety valve(s) 4" IF Pin 4" IF Box

(TIW/Kellyguard)

Baker float valve

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Totco ring

17" bit breaker

17" gauge ring



9" DC elevators

8" DC elevators

6

5

/8" DP elevators

5" DP elevators

9" DC slips

8" DC slips

65/8" DP slips

5" Slips


Drill collar safety clamp(s)

Single shot survey equipmentinc. sandline / slickline, sinkerbars, overshots etc.

9" TELEDRIFT tool 75/8" Reg Box 75/8" Reg Box

Surface equipment for TELEDRIFT


Gyro survey equipment

* Usually Supplied By OperatorFor 16" hole, tool requirements are the same. Substitute 16" for 17" asrequired.

Deviated Well

The following is a list of additional drilling tools which could be required fordrilling a deviated well.

ITEM CONNECTIONS CONNECTIONS

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DOWN UP

* 9" non mag. drill collars 75/8" Reg Pin 75/8" Reg Box

* 9" non mag. pony collars 75/8" Reg Pin 75/8" Reg Box

* Near bit stabilisers 75/8" Reg Box 75/8" Reg Box

* Non mag. string stabilisers 75/8" Reg Pin 75/8" Reg Box

* Stabiliser sleeves (17", 17"and 17")

* Stabilisers sleeve breaker

* 11" mud motor(s) 7

5

/8" Reg Pin 7

5

/8" Reg Box

* 11" steerable motor assy 75/8" Reg Pin 75/8" Reg Box

* Bent subs/UBHO subs 75/8" Reg Pin 75/8" Reg Box

* 9" MWD 75/8" Reg Pin 75/8" Reg Box

* Surface equipment for MWD

* SRO Gyro/steering tools and wireline unit



ITEM

* 133/8" casing hanger(s) complete with 133/8" casing pup joint

* 133/8" float shoe joint(s)

* 133/8" float collar joint(s)

* 133

/8" casing joints

* 133/8" x 18" casing hanger pack-off assembly(s)* 133/8" casing hanger and pack-off running tool with drillpipe adaptor

* BOP test tool(s)

* 133/8" wear bushing(s)

* 133/8" wear bushing running/pulling tool

* 133/8" centralisers and nails

* 133/8" stop collars and nails

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* 133/8" casing drift(s)

* 133/8" casing power tongs


133/8" manual casing tongs

133/8" casing single joint pick-up elevators

Wire bridle and swivel for pick-up elevators

133/8" casing x 150 ton side door elevators

13

3

/8" casing slips

133/8" casing bushing inserts

350 / 500 ton slip type spider dressed for 13 3/8" casing

350 / 500 ton slip type elevator dressed for 133/8" casing

350 / 500 ton long elevator links

Work stands for use with 350/500 ton equipment

* 133

/8" clampon or Klepo quick release thread protectors

* Casing dope and brush(es)

* Tins of threadlocking compound complete with applicators

Buckets of diesel, barite, wire brush and rags for cleaning and dryingconnections prior to threadlocking

133/8" casing safety clamp

Wire slings for handling casing into V-door


Fill-up line for DDM/Topdrive or dedicated casing fill up line

* Timber for stacking casing

* 133/8" casing thread x Fig 1502 circulating swedge

* 133/8" casing thread x 4" IF box crossover (waterbushing)

* Subsea plug launching equipment complete with darts, subsea plugs, and

4" IF connection

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Cement hose/chiksans

Lo-torque valve(s)

* Emergency drillpipe hang-off assembly


If casing is run full bore to surface, the following items will substitute for itemslisted previously:

3.1.1.1.1.1.1.1.1Double Plug Cementing Head c/w Conventional Plugs.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Casing Hanger Running Tool c/w Pup Joint of 133/8" Casing.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Casing Landing String.

If a Two Stage cement job is required, the following items will substitute foritems listed previously:

3.1.1.1.1.1.1.1.1Stage cementing collar(s).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Casing by-pass baffle.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Casing shut-off baffle.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1First stage by-pass plug.

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1First stage shut-off plug.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Stage collar opening bomb.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Stage collar closing plug.

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5.8 12 "Hole Section

5.8.1 Introduction

Specific requirements will be issued in the Operators Well Programme.The following procedures are to assist in developing rig specific procedures thatmight be required.

5.8.2 Preparation

3.1.1.1.1.1.1.1.1Test BOPs (Ref. Rig Specific Work Methods and WellProgramme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Install 133/8" wear bushing in wellhead.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Check emergency drill string hang-off tool assembly space outis correct, adjust if necessary.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Test choke and kill manifold valves, standpipe manifold valves,inside BOP Valves etc. (Ref. Rig Specific Work Methods and Well Programme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check that drillfloor equipment for kick-control is available,inside BOP, spare Kelly valve, kick joint and inside BOP dart to be ready foruse.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure test 133/8" casing as required by Well Programme (ifnot done when bumping plug).

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check equipment as per checklists (Ref. Section 5.7.6 .1 and5.7.6.2).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Prepare 95/8" casing (Ref. Well Programme and Section 5.5.1 inDOP 202).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Lay out 17" drilling assembly, prepare and make up 12"BHA required (Ref. Well Programme and Section 5.1 in DOP 202). 3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up 95/8" casing hanger and pup joint assembly to pack-offassembly, running tool etc. as required by Well Programme. This may be done

before RIH with clean-out assembly prior to running 95

/8" casing.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check with Cement Hand that his materials and equipment are

prepared.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Remove lock ring from casing hanger on exploration wells.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check the weight of the casing versus the capacity of the

hoisting equipment.


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3.1.1.1.1.1.1.1.1Run 12" BHA to approximately 20 ft above predicted top ofcement. Break circulation and tag top of cement. Report depth to top ofcement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill out cement, plug(s), float collar, shoe track and float shoe.Restrict rpm, and keep torque limit set to minimum required whilst drilling insidethe casing. The WOB should be restricted to a maximum of 10000 lbs untiloutside the shoe then increased to the optimum weight.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Clean out rathole below 133/8" casing shoe. Take SCP (Ref.Well Control Manual WCO 200). Drill 1.5 - 3 m of new formation circulate holeclean and condition mud, pull back inside casing shoe.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Carry out formation pressure test (leak-off or integrity test) asrequired by Well Programme (Ref. WCO 200 Section 4.10).

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill 12" hole as required by Well Programme. Once allstabilisers are in new hole then rpm may be increased. Adjust WOB and rotaryspeed to achieve best rate of penetration.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Take directional surveys as required by Well Programme (Ref.Section 5.3.3 in DOP 202).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Inspect wear bushing and test BOPs at intervals specified inWell Programme and the Company Well Control Equipment Procedures.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure tests of the BOP should be conducted after

installation, after setting casing, and before drilling into any known or suspectedhigh pressure zones. Otherwise, these tests should be conducted at regularintervals but not more than once every week. On installation each componentshould be individually tested to a low pressure (around 200 psi) and to thegreater of 70% of rated working pressure or the maximum pressure expectedin the upper part of the casing. An exception is the annular preventer whichmay be tested to 50% of its rated working pressure to minimise pack off elementwear or damage.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1At 95/8" casing point, circ. until shakers are clean, then POOH torun logs. Should any drag, bridges or fill be encountered make a wiper trip tobottom. Once hole conditions are good, POOH to run open hole electric logs.

Recommended treatment to the mud must be based upon whether the problemis of rheological, chemical or pressure character.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Rig up and run open hole logs as per Well Programme. Rigdown loggers (Ref. Section 5.4 in DOP 202, Ref. Section 4). If the logs are notgoing to bottom due to the same problems in (9), further treatment shall be doneduring the wiper trip to follow.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1After logging the well, it is recommended to make a wiper tripprior to running casing. Measure pipe length when POOH after final wiper trip, ifnot already done on trip out before logging. If required wash wellhead with bit,while POOH to retrieve wear bushing.

3.1.1.1.1.1.1.1.1

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3.1.1.1.1.1.1.1.1Prior to wiper trip make up 95/8" casing hanger assembly, andplug launcher to a stand of HWDP as per Well Programme.

or

3.1.1.1.1.1.1.1.1If to be run on 95/8"casing lay hanger assembly out again.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1On trips, while out of the hole, the shear rams will remain in anopen position. The trip tank shall be monitored while the drill string is out of thehole.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Abnormal pressure zones may be penetrated while drilling thissection of the hole. Drilling breaks will be flow checked after a maximum of 3 m(10 ft) formation has been drilled.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1RIH with drilling assembly for clean-up trip if required. Circulateand condition hole ready to run 95/8" casing. Wash wellhead area on POOH torun casing (only if wear bushing retrieval tool has no jetting facility).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Retrieve 133/8" wear bushing.

5.8.4 Running 95/8" Casing

NOTE:Safety

If it is possible for the Compensator hoses to foul the stabbing board, the on

tour Toolpusher shall lock out the Drill String Compensator and DDM carriagecontrol button to prevent retraction of the Travelling Block.

3.1.1.1.1.1.1.1.1Rig up and run 95/8" Casing (Ref. Well Programme and Section5.5.2 in DOP 202).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check float equipment for proper operation.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Run surge pressure program to check maximum allowablerunning speed.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Ensure circulating swedge and crossover to 4" IF should beon the rig floor ready for use.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Fill casing with mud as it is run using the fill line/DDM. Ensure

casing completely full every five joints.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Make up 95/8" casing hanger to casing string. Check runningtool etc. as required by Well Programme and Service Engineer.

3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Do not exceed 90% of DSC capacity when landing casing. Forheavier casing, if weather permits, land without using DSC, and fill entirecasing string with mud during running. Avoid floating casing strings as

much as possible due to well control problems.3.1.1.1.1.1.1.1.1

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3.1.1.1.1.1.1.1.1Run 95/8" casing on landing string (5" HWDP/S-135 or 95/8"casing), pick up landing joint/stand with cementing head and land out casing inwellhead - confirm depth.

5.8.5 Cement 95/8" Casing

3.1.1.1.1.1.1.1.1Cement casing as per Clients cement programme and Ref.Section 5.5.3 in DOP 202.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up cementing line to cement head and pressure test linesas per Well Programme (normally 3000 psi).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Break circulation slowly with rig pumps using drilling mud.Circulate at least the volume of casing and landing string.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Break circulation slowly with rig pumps using drilling mud.Circulate at least the volume of casing and landing string. Limit pump rate suchthat 12" x 95/8" annular velocity is the same as that used to drill the 12" hole.Observe for mud losses while circulating.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pump spacer ahead as per Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Mix and pump cement as per Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Release plug and displace cement to float collar with drillingmud.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Switch to mud pumps and displace plug to float collar withdrilling mud.

NOTE: Max allowable over displacement is half the volume between float collarand shoe.

3.1.1.1.1.1.1.1.1When plug has bumped, pressure up casing to test pressure asrequired by Well Programme. Hold pressure for time required by WellProgramme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Bleed off casing pressure and check float is holding. If float isholding then release casing hanger running tool. If float is not holding, maintain

final displacement pressure on casing until cement takes initial set. If there isany possibility of cement at the wellhead, flush through choke and kill lines andcirculate riser contents whilst waiting on cement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Set casing hanger seal assembly as per Well Programme andService Engineer.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure test seal assembly / BOP according to ServiceEngineer instructions / Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1POOH and lay out running tools.

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5.8.6 Equipment Requirements - 12" Hole

3.1.1.1.1.1.1.1.1 Drilling Tools

Vertical Well


CONNECTIONSUP

* 12" bits with nozzles - 65/8" Reg Pin

* 12" near bit stabiliser(s) 65/8" Reg Box 65/8" Reg Box


8" steel drill collars 6

5

/8" Reg Pin 6

5

/8" Reg Box

* 12" string stabiliser(s) 65/8" Reg Pin 65/8" Reg Box

* 8" drilling jars (up / down) 65/8" Reg Pin 65/8" Reg Box




* 65

/8" HWDP 65

/8" FH Pin 65

/8" FH Box

* 65/8" drillpipe 65/8" FH Pin 65/8" FH Box

* Crossover(s) 65/8" FH Pin 4" IF Box

* Hydril drop-in sub with dartand retrieving tool

4" IF Pin 4" IF Box


Full opening safety

valve(s)

4" IF Pin 4" IF Box

(TIW / Kellyguard)

Baker float valve

Totco ring

12" bit breaker(s)

12" gauge ring

8" DC lifting subs 65/8" Reg Pin8" DC elevators

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5" DP elevators

8" DC slips

* 65/8" DP Slips

5" DP Slips

Drill collar and drillpipedope

Drill collar safety clamp(s)

Single shot survey equipment inc. sandline/slickline, sinker bars, overshotsetc.

* Magnetic single shot survey

Equipment


Gyro survey equipment

Coring tools (if required)


Deviated Well

The following is a list of additional Drilling Tools which might be required fordrilling a deviated well.


CONNECTIONSUP

* 8" non mag. drill collars 65

/8" Reg Pin 65

/8" Reg Box

* 8" non mag pony collars 65/8" Reg Pin 65/8" Reg Box* Near bit stabiliser(s) 65/8" Reg Box 65/8" Reg Box

* Non mag string stabiliser(s) 65/8" Reg Pin 65/8" Reg Box

* Stabiliser sleeves (11",12", 121/8" and 12")

* Stabiliser sleeve breaker* Mud motor(s) 65/8" Reg Box 65/8" Reg Box

* Steerable motor assembly 65/8" Reg Box 65/8" Reg Box

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* Bent subs / UBHO subs 65/8" Reg Pin 65/8" Reg Box

* 8" MDW 65/8" Reg Pin 65/8" Reg Box

* Surface equipment for MWD



ITEM

* 95/8" casing hanger(s) with 95/8" casing pup joint

* 95/8" float shoe joint(s)

* 95/8" float collar joint(s)

* 95/8" casing joint(s)

* 95/8" x 18" casing hanger pack-off assembly(s)

* 95/8" casing hanger and pack-off running tool

* BOP test tool(s)

* 95/8" wear bushing(s)

* 95/8" wear bushing running / pulling tool

* 95/8" centralisers and nails

* 95/8" stop collars and nails

* 95/8" casing drift(s)

* 95/8" casing power tongs


95/8" manual casing tongs

95/8 " casing single joint pick-up elevators

Wire bridle and swivel for pick-up elevators

95/8" casing x 150 ton side door elevators

95/8" casing slips

95/8" casing bushing inserts

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350 / 500 ton slip type spider dressed for 95/8" casing

350 / 500 ton slip type elevator dressed for 95/8" casing

350 / 500 ton long elevator links

Work stands for use with 350 / 500 ton equipment

* 95/8" clampon or Klepo quick release thread protectors

* Casing dope and brush(es)

* Tins of threadlocking compound with applicators

Buckets of diesel, barite, wire brush and rags for cleaning and dryingconnections prior to threadlocking

95/8" casing safety clamp

Wire slings for handling casing into V-door


Fill-up line for DDM/Top drive or dedicated casing fill up line

* Timber for stacking casing

* 95/8" casing thread x Fig 1502 circulating swedge

* 95/8" casing thread x 4" IF box crossover (waterbushing)

Landing string as required by Well Programme

* Plug launching equipment with plugs, darts etc. as required byWell Programme

Cement hose / chicksans

Lo-torque valve(s)

* Emergency drillpipe hang-off assembly

Check casing stabbing board and drillers CCTV (if fitted)


5.9 8" Hole Section

5.9.1 Introduction

Specific requirements will be issued in the Operators Well Programme.

The following procedures are to assist in developing installation specificprocedures that might be required.

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5.9.2 Preparation

3.1.1.1.1.1.1.1.1Test BOPs (Ref. Rig Specific Work Methods Specific InstructionManual (RSI 300) and Well Programme).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Install 95/8" wear bushing.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check emergency drill string hang-off tool assembly space outis correct, adjust if necessary.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Test choke and kill manifold valves, standpipe manifold valves,inside BOP valves etc. (Ref. Rig Specific Instruction Manual (RSI 300), WorkMethods and Well Programme).3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Check that drillfloor equipment for kick-control is available.Inside BOP, spare Kelly valve, kick joint and inside BOP dart to be ready foruse.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure test 95/8" casing as required by Well Programme. Ifnot done when plug bumped.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check equipment as per checklist, Ref. under Section 5.8.6.1and 5.8.6.2..3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Prepare 7" liner/casing (Ref. Well Programme and Section 5.5.1in DOP 202).

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Lay out 12" drilling assembly, prepare and make up 8" BHArequired (Ref. Well Programme and Section 5.1 in DOP 202). 3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check with Cement Hand that his materials and equipment are

prepared.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Remove lock ring from casing hanger on exploration wells.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check the weight of the casing versus the capacity of thehoisting equipment.

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3.1.1.1.1.1.1.1.1Run 8" BHA to approximately 20 ft above predicted top ofcement. Break circulation and tag top of cement. Report depth to top ofcement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill out cement, plug(s), float collar, shoe track and float shoe.Restrict rotary speed, and keep torque limit to the minimum required whilstdrilling inside the casing.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Clean out rat hole below 95/8" casing shoe. Take SCP (Ref.Well Control Manual WCO 200) drill 5 -10 ft of new formation. Circulate holeclean and condition mud as required, pull back inside casing shoe.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Carry out formation pressure test (leak-off or integrity test) as

required by Well Programme (Ref. WCO 200 Section 4).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill 8" hole as required by Well Programme. Once allstabilisers are in new hole then rotary speed may be increased. Adjust WOBand rotary speed to achieve best rate of penetration.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Drill to casing point as required by Well Programme. At casingpoint, circulate hole clean, condition mud and make wiper trip to 9 5/8" casingshoe as required. POOH to run electric open hole logs.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Take directional surveys as required by Well Programme (Ref.Section 5.3.3 in DOP 202).

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Inspect wear bushing and test BOPs at intervals specified inWell Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure tests of the BOP should be conducted afterinstallation, after setting casing, and before drilling into any known or suspectedhigh pressure zones. Otherwise, these tests should be conducted at regularintervals but not more than once every week. On installation each componentshould be individually tested to a low pressure (around 200 psi) and to thegreater of 70% of rated working pressure orthe maximum pressure expected inthe upper part of the casing. An exception is the annular preventer which maybe tested to 50% of its rated working pressure to minimise pack off element

wear or damage.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Core well as required by Well Programme, Wellsite Geologist.Ensure that pipe is strapped on POOH to pick up core barrel. Report anydifference in drilled depth. Ensure that any tide corrections are applied to drillingdepth figures (Ref. Section 5.6 in DOP 202).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1At section TD circulate until shakers are clean, then POOH torun logs. Should any drag, bridges or fill be encountered make a wiper trip tobottom. Once hole conditions are good, POOH to run open hole electric logs.Recommended treatment to the mud must be based upon whether the problemis of rheological, chemical or pressure character.

3.1.1.1.1.1.1.1.1

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3.1.1.1.1.1.1.1.1Rig up and run open hole logs as per Well Programme (Ref.Section 5.4 in DOP 202). Rig down loggers. If the logs are not going to bottomdue to the same problems as in (11), further treatment shall be done during thewiper trip to follow.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1If 7" liner is to be run then rabbit pipe in derrick whilst logging.OD of drift will be determined by maximum OD of dart to be used (Ref. LinerHanger Service Engineer) (usually 2" OD required).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1If 7" casing is to be run, then make up 7" casing hanger

assembly and running equipment as per Well Programme before RIH forfinal wiper trip before running casing.

or

3.1.1.1.1.1.1.1.1Pick up the cement Kelly and check service breaks install dartand ball in the cement head. Pick up 7" liner hanger and make up to therunning tool with subsea plug launching assembly attached. Remove lock ringon exploration wells. Stand back in derrick.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1A wiper trip may be required prior to running casing. Measurepipe length when POOH after final wiper trip, if not already done on trip outbefore logging. Wash wellhead with bit while POOH (if required to retrieve wearbushing).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1On trips, while out of the hole, the shear rams will remain in anopen position. The trip tank shall be monitored while the drill string is out of the

hole.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Abnormal pressure zones may be penetrated while drilling this

section of the hole. Drilling breaks will be flow checked after a maximum of5 ft of formation has been drilled.

5.9.4 Running And Cementing 7" Liner/Casing (General)

NOTE:Safety

If it is possible for the Compensator hoses to foul the stabbing board, the on

tour Toolpusher shall lock out the Drill String Compensator and DDM carriagecontrol button to prevent retraction of the Travelling Block.

3.1.1.1.1.1.1.1.1Run and Cement casing/liner as per Clients Cement Programme(Ref.Section 5.5.2 and 5.5.3 in DOP 202).3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1If 7" casing is to be run and hung-off in the wellhead. Retrievethe 95/8" wear bushing.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Check float equipment for proper operation.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Run 7" casing. Fill casing with mud as it is run using the fillline/DDM. Ensure casing completely full every five joints.

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3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Make up 7" hanger to casing string. Check running tool etc. as

required by Well Programme and Service Engineer.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Prepare a surge/swab program for running the 7" casing.Establish the maximum running speed.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1A 7" circulation swedge and crossover to 4" IF should be on

the rig floor ready for use when running casing to wellhead.

5.9.5 Running And Cementing 7" Casing

3.1.1.1.1.1.1.1.1Run 7" casing on landing string, pick up landing joint withcementing head and land out casing in wellhead. Check Depth.

3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Do not exceed 90% of DSC capacity when landing casing. Forheavier casing, if weather permits, land without using DSC, and fill entirecasing string with mud during running. Avoid floating casing strings asmuch as possible due to well control problems.

3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Make up cementing line to cement head and pressure test linesas per Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Break circulation slowly with mud pump using drilling mud.Circulate at least the volume of casing and landing string.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pump spacer ahead as per Well Programme.

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Mix and pump cement as per Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Release plug and displace cement to float collar with drillingmud.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1When plug has bumped, pressure up casing to test pressure asrequired by Well Programme. Hold pressure for time required by WellProgramme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Bleed off casing pressure and check floats are holding. Ifholding, release casing hanger running tool. If not holding, maintain final

displacement pressure on casing until cement takes initial set. If any possibilityof cement at wellhead, flush through choke and kill lines and circulate risercontents whilst waiting on cement.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Set casing hanger seal assembly as per Well Programme andService Engineer.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pressure test seal assembly/BOP as per Service Engineersinstructions/ Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1POOH and lay out running tools. Apply any tide correctionapplicable and report the depth of the 7" hanger on the IADC Report.

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5.9.6 Running And Cementing 7" Liner

3.1.1.1.1.1.1.1.1After last joint of 7" liner is made up, completely fill the liner withmud.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Pick up and make up liner hanger assembly as per WellProgramme and liner hanger Service Engineer. Pick up with slips in rotary tocheck running tool/liner hanger make-up. Pick up off slips and record weight ofliner and running tool assembly.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Run 7" Liner on drillpipe running string, filling pipe to the topusing fill-up hose. Control running speed as directed by Service Engineer.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Break circulation as required by Well Programme and ServiceEngineer. Break circulation slowly and observe for mud losses.

3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1At +/- 30 ft from bottom, space out with pup joints if requiredand pick up Cement Kelly and dart launching head/swivel (made up and laid outbefore final wiper trip) and make up to running string. Hook up cementing lineand pressure test as required by Well Programme.3.1.1.1.1.1.1.1.13.1.1.1.1.1.1.1.1Break circulation slowly with rig pump using drilling mud.Circulate at least liner and running string volume OR the annulus volume(liner/8" hole) whichever is the greater. Monitor for mud losses. Record pick-up and slack-off weights. Work pipe as required by Well Programme andService Engineer.3.1.1.1.1.1.1.1.1

3.1.1.1.1.1.1.1.1Pump pills, spacers etc. as required by Well Programme andset liner hanger as required by Well Programme and Service Engineer.Release running tool as required. Check weights and check tool is free. Recordneutral weight, number of turns and number of back turns obtained when torqueis released to release running tool.3.1.1.1.1.1.

dop 203 - rev 2

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