1.1. Kill Procedure A – Lubricate, bullhead and circulate

1 KKiillll PPrroocceedduurree AA LLuubbrriiccaattee,, bbuullllhheeaadd aanndd cciirrccuullaattee Status: Well closed in at PFSV valve. Test string contains well effluent Cement pump lined up to pump 60/40 glycol/water Note: SLB DST supervisor to be on rig floor at all times Procedure : 1. Perform TBRA with all involved personnel 2. Start injecting methanol at subsea test tree, lubricator valves and choke manifold at full rate. 3. Close upper lubricator valve; open kill wing valve 4. With cement pump, flush surface lines with 60/40 glycol/water mix 5. Displace line from cement unit to flowhead with kill weight brine 6. Open upper lubricator valve. 7. bullhead kill weight brine into the well. 8. Maintain volume control and observe when brine hits the formation.

2 9. bullhead into the formation taking care not to exceed the maximum rating of the downhole gauges or other equipment ratings. bullhead a maximum of 2 m3 into the formation. Note: DO NOT EXCEED maximum pressure rating of downhole memory gauges -. 10. Using the rig pumps pressure up annulus to open the upper SHRV circulation valve and observe communication between tubing and annulus. 11. circulate well down tubing and up the annulus until brine properties are acceptable Note: control pressure at rig choke manifold to avoid influx of hydrocarbons in to the string and annulus in the event that the PFSV is not sealing 12. Spot and bullhead kill pill/LCM pill 13. Using the rig pumps pressure up annulus to open the lower SHRV circulation valve Note: It may not be possible to apply sufficient pressure to rupture the disc in the lower SHRV. 14. Flow check for 30 minutes via kill line.

3 At same time prepare subsea umbilicals and surface test tree control lines for lifting test string to un-sting from production packer. Note: A certain amount of back flow may be observed during the flow check due to temperature effects. The flow rate should be recorded and the trend established to distinguish between unstable well conditions and temperature effects. Ensure surface test tree hydraulic control lines are of sufficient length to allow pick-up of string out of production packer XXm Note: All involved personnel shall be aware of the following: Length of seal assembly stung into packer Length of SSTT assembly below datum Length from datum to top of lower annular 15. Clear rig floor, open middle pipe rams and flow check for 30 minutes 16. Lift test string to pull seal assembly out of production packer ___m 17. Close appropriate pipe ram or annular.

4 18. With cement pump, attempt to bullhead kill weight brine down choke line into formation (volume: x rathole volume from packer to top perforation) Note: Do not exceed the maximum working pressure of downhole memory gauges with kill weight fluid. 19. Using mud pumps, circulate kill weight brine down test string taking returns through rig choke line, choke manifold and poor boy degasser minimum circulation; one and a half well volumes or continue until gas readings are below 2%. 20. Open appropriate pipe ram or annular and ensure well stable. 21. circulate the long way through the riser - minimum circulation; one and a half well and riser volumes or continue until gas readings are below 2%. 22. Flow check well for 30 minutes, pump slug and commence POOH. Note: Ensure Kelly cocks / well control subs made up and available on rig floor 1 x kill hose to 3-1/2 PH-6 tubing 1 x kill hose connection to 4-1/2 PH-4 tubing Note: Care must be taken to ensure well is not swabbed whilst POOH Pull out slowly until the DST BHA is into the 9-7/8 Note: During POOH: Stop halfway and flow check for 30 minutes Stop before DST BHA enters the BOP and perform weather check and flow check for 30 mins KKiillll PPrroocceedduurree BB RReevveerrssee oouutt ssttrriinngg ccoonntteennttss;; bbuullllhheeaadd aanndd This Procedure shall be adopted if bullheading the string contents may pose a problem.

5 Status Well closed in at PFSV valve. Test string contains well effluent Cement pump lined up to pump brine Mud Pumps Lined up to pump brine Note: SLB DST supervisor to be on rig floor at all times Good communication between rig floor and test area will be important to ensure an efficient kill Procedure 1. Perform TBRA with all involved personnel 2. Well Testing Production Side: line up well testing lines and prepare to flow through test separator to burners follow pre-flare checklist. 3. Rig Kill Side: line up kill wing side of surface test tree to be ready to take brine and kill mud after all hydrocarbons have been reversed to well test unit. 4. Line up from the surface flow tree kill wing valve via the kill standpipe and rig choke manifold to poor boy degasser. Kill wing valve to remain closed.

6 5. Line up rig pumps to pump kill weight brine down annulus. 6. Commence injection of hydrate inhibitor (Methanol or MEG) at the subsea test tree, lubricator valves, surface test tree and choke manifold. Note: Injection inhibitor continuously whilst displacing hydrocarbons. 7. Bleed off approximately 1/3 of the tubing pressure at well testing choke manifold, close choke and monitor WHP for 10 minutes to confirm the PFSV is closed and holding pressure. Note: If PFSV does not hold pressure continue with kill taking additional care to avoid hydrocarbon influx 8. Pressure up on the annulus to open upper SHRV 9. Note the drop in annulus pump pressure as the circulating valves open. This should coincide with a tubing pressure (WHP) fluctuation. 10. Open well to burners whilst pumping brine Note: Pumping and flowing to be carefully controlled to ensure constant BHP 11.

7 With brine at surface, divert flow through rig choke and over poor boy degasser. Note: Take brine returns into pits according to Mud Engineer s instructions. 12. Continue circulating brine until gas is less than 2% and brine properties are acceptable 13. Close upper lubricator valve and flush well testing equipment to 60/40 glycol/water mix. Note: Surface Testing Supervisor to maintain contact with cement pump at all times and dictate operations as necessary to flush equipment. 14. When well testing system has been flushed, close surface test tree production wing valve and surface safety valve. 15. Spot a kill pill and bullhead below the PFSV 16. Pressure up annulus to shear open lower SHRV 17. Flow check for 30 minutes via kill line. At same time prepare subsea umbilicals and surface test tree control lines for lifting test string to un-sting from production packer.

8 Note: A certain amount of back flow may be observed during the flow check due to temperature effects. The flow rate should be recorded and the trend established to distinguish between unstable well conditions and temperature effects. Ensure surface test tree hydraulic control lines are of sufficient length to allow pick-up of string out of production packer XXm All involved personnel shall be aware of the following: Length of seal assembly stung into packer Length of SSTT assembly below datum Length from datum to top of lower annular Note: Ensure surface test tree hydraulic control lines are of sufficient length to allow pick-up of string out of production packer - XXm 18. Clear rig floor, open middle pipe rams and flow check for 30 minutes 19. Lift test string to pull seal assembly out of production packer XXm 20. Close appropriate pipe ram or annular.

9 21. With cement pump, attempt to bullhead kill weight brine down choke line into formation (volume: x rathole volume from packer to top perforation) Note: Do not exceed the maximum working pressure of downhole memory gauges with kill weight fluid. 22. Using mud pumps, circulate kill weight brine down test string taking returns through rig choke line, choke manifold and poor boy degasser minimum circulation; one and a half well volumes or continue until gas readings are below 2%. 23. Open pipe ram/annular and ensure well stable. 24. circulate the long way through the riser - minimum circulation; one and a half well and riser volumes or continue until gas readings are below 2%. 25. Flow check well for 30 minutes, pump slug and commence POOH. Note: For pulling the string refer to notes for method A above KKiillll PPrroocceedduurree CC BBlleeeedd ooffff pprreessssuurree,, lluubbrriiccaattee aanndd bbuullllhheeaadd pprriioorr ttoo cciirrccuullaattiioonn In the event that direct bullheading is not considered to be the preferred option this method will be adopted Status: Well closed in at PFSV valve.

10 PFSV holding pressure Test string contains well effluent Cement pump lined up to pump 60/40 glycol/water Note: SLB DST supervisor to be on rig floor at all times 1. Bleed off all tubing pressure through test spread and burners whilst injecting methanol at subsea test tree, lubricator valves and choke manifold at full rate. 2. Lubricate kill weight brine into string. 3. Stop pumping when pressure reaches approximately XXX bar and allow brine to settle above PFSV, note volume pumped. Observe for 20 minutes. 4. Bleed off all tubing pressure through testing choke manifold. 5. Lubricate kill weight brine into string. 6. Stop pumping when pressure reaches approximately XXX bar and allow brine to settle above PFSV, note cumulative volume pumped and returned. Observe for 20 minutes. 7. Bleed off all tubing pressure through testing choke manifold 8.