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Home My WebLink About204-162By James Brooks at 3:18 pm, Apr 25, 2023 Abandoned 4/14/2023 JSB RBDMS JSB 051723 xGDSR-5/22/23MGR08AUG2023 4.25.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.04.25 12:40:31 -08'00' Monty M Myers ACTIVITYDATE SUMMARY 9/13/2022 ***WELL S/I ON ARRIVAL*** (CTD) MISU POLLARD #60 FOR PRE CTD DRIFT & TAG. CURRENTLY ON WEATHER HOLD DUE TO HIGH WINDS. ***JOB IN PROGRESS, CONTINUED ON 9/14/22 WSR*** 9/14/2022 ***CONTINUED FROM 9/13/22 WSR*** (CTD) POLLARD #60 WEATHER HOLD DUE TO HIGH WINDS. ***JOB IN PROGRESS, CONTINUED ON 9/15/22 WSR*** 9/15/2022 T/I/O= Assist SL with B&F (CTD). Pumped 180 bbls of 180*F diesel into the TBG. Final T/I/O= 1500/1500/30. 9/15/2022 ***CONTINUED FROM 9/14/22 WSR*** (CTD) UNABLE TO PASS 2,145' SLM W/ 4-1/2" XN LOCATOR, S-BLR (Hydrates in bailer). BRUSH & FLUSH (Hot) FROM SURFACE TO XN NIPPLE AT 15,698' MD W/ 3.805" G-RING, 4-1/2" BRUSH. TAG HARD BOTTOM AT 15,876' MD W/ 4-1/2" XN LOCATOR, S-BLR (No issues or sample). SET 4-1/2" WHIDDON CATCHER SUB AT 15,670' SLM / 15,698' MD. PULL BK-OGLV FROM ST #1 (15,519' MD), BK-LGLV FROM ST #3 (12,913' MD), & ST #4 (7,728' MD). ***JOB IN PROGRESS, CONTINUED ON 9/16/22 WSR*** 9/16/2022 T/I/O= 1700/1700/0 Temp= S/I (TFS Unit 4 assist SL with load and test) Pumped 2 bbls 60/40 followed by 303 bbls of 2%KCL down IA. Further pumped 45 bbls of DSL down IA for Freeze Protect. Pumped 2 bbls of 60/40 followed by 310 bbls of 2%KCL down TBG. Further pumped 63 bbls of DSL down TBG for Freeze Protect . Lubed and Bled IA with 70 bbls DSL to fluid pack IA. ***Job continued on 09/17/2022*** 9/16/2022 ***CONTINUED FROM 9/15/22 WSR*** (CTD) SET BK-DGLV'S AT ST #4 (7,728' MD) & ST #4 (12,913' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 15,698' MD. TB LOADED IA W/ 303 BBLS OF 2% KCL & 45 BBL DIESEL FREEZE PROTECT. TB LOADED TUBING W/ 310 BBLS OF 2% KCL & 63 BBL DIESEL FREEZE PROTECT. SET 4-1/2" CAT STANDING VALVE AT 15,670' SLM / 15,698' MD. THUNDERBIRD TOPPED OFF TUBING & IA W/ 65 BBLS OF DIESEL. ***JOB IN PROGRESS, CONTINUED ON 9/17/22 WSR*** 9/17/2022 ***Job Continued from 09/16/2022*** TFS unit #4 Assist Slickline (Load & Test) MIT-T ***PASSED*** to 4600 psi. Pumped a total of 2 bbls DSL to Reach Max applied psi of 4750 psi With a target psi of 4500. 1st 15 min TBG lost 75 psi. 2nd 15 min TBG lost 25 psi. A total loss of 100 psi in 30 min. Bled back 3 bbls DSL. MIT-IA **** PASSED**** Target pressue= 4500 psi. Max applied pressure= 4750 psi. 1st 15 min IA lost 40 psi. 2nd 15 Min IA lost 10 psi. IA lost a total of 50 psi in 30 min test. Bled back 3.6 bbls. Final whps=900/900/0 SL in control of well upon departure. Daily Report of Well Operations PBU S-119 Daily Report of Well Operations PBU S-119 9/17/2022 ***CONTINUED FROM 9/16/22 WSR*** (CTD) SET BK-DGLV AT ST #1 (15,519'MD). THUNDERBIRD PERFORMED SUCCESSFUL MIT-T TO 4600 PSI (Held ~2100 psi on ia for test). TB PERFORMED SUCCESSFUL MIT-IA TO 4640 PSI (Held ~2200 psi on tbg for test). PULL 4-1/2" CAT STANDING VALVE FROM 15,670' SLM / 15,698' MD. TAG HARD BOTTOM W/ 3.70" x 24'10" DUMMY WHIPSTOCK AT 15,876' MD. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** DRIFT TO 4,100' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE SURVEILLANCE. 9/26/2022 Assist Eline, Pump as directed, PT lubricator 9/26/2022 ***WELL SHUT IN ON ARRIVAL*** RIH TO SET BKR WHIPSTOCK, TOWS SET DEPTH WAS SUPPOSED TO BE 15878' BUT TAG HIGH AT 15886' (-18' OF WHIPSTOCK OAL) PUTTING TOP OF WHIPSTOCK AT 15868' CONFIR W/ TOWN ON 2ND SETTING OPTION BUT DECISION WAS MADE TO POOH AND LET COIL CLEAN OUT ***WELL LEFT SHUT IN ON DEPARTURE*** 10/1/2022 T/I/O= 750/100/0 TEMP=SI (CTD) Assist Sline as directed Pumped 2 bbls down Tbg to bring Tbg psi up to assist Sline to set valve. Bleed TBG psi down to 1000 psi ***Job cont to 10-02-22 WSR*** 10/1/2022 ***WELL S/I ON ARRIVAL*** ATTEMPT TO SET 4 1/2" CAT STANDING VALVE IN XN NIPPLE @ 15,698' MD; UNABLE TO SHEAR GS. ***WSR CONTINUED ON 10-2-22*** 10/2/2022 ***Job cont. from 10-01-22 WSR*** Pumped 11 bbls crude down Tbg to pump Sline down hole. Pumped 4.1 bbls crude down TBG to reach test pressure of 4700 psi Initial pressures 1250/ 75/ 0 Starting pressures 4700/ 80/ 0 1st 15 min pressures 4590/ 80/ 0 TBG lost 110 psi 2nd 15 min pressures 4550/ 80/ 0 TBG lost 40 psi *** MIT T PASS *** Tags Hung Well left in SL control upon departure FWHP= 1200/80/0 All CV's= OTG 10/2/2022 ***WSR CONTINUED FROM 10-1-22*** SET 4 1/2" STANDING VALVE IN XN NIPPLE @ 15,698' MD THUNDERBIRD PERFORMED A PASSING MIT-T TO 4,500 PSI PULLED 4 1/2" STANDING VALVE ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 10/2/2022 Travel to location,,, Stand by for pump contingency, Released from job. 10/2/2022 YELLOW JACKET E-LINE JOB OBJECTIVE: MILL NIPPLE AT 15698" MU MIRU WITH 9/32 LINE AND WELLTEC TRACTOR ANDF MILL WITH 3.802 CUTTING HEAD MADE CONTACT WITH NIPPLE BUT AFTER SEVERAL ATTEMPTS WELLTEC WAS UNABLE TO MILL THE NIPPLE WELL CORRELATED TO TUBING TALLY INSTRUCTED TO STOP OPERATIONS POOH AND RIG DOWN COIL IS SUPPOSED TO MILL XN AND FCO AT LATER DATE WELL SHUT IN UPON COMPLETION, HANDED BACK TO WSS Daily Report of Well Operations PBU S-119 10/5/2022 CTU #9 - 2.0" CT. Job Objective: Mill XN & FCO MIRU CTU #9. NU BOPs and 2' Spool. RU Lub. MU Nozzle. Pump 1-3/16" drift ball. MU LH 3.80" milling assembly RIH ***Job Continued on WSR 10/6/22*** 10/6/2022 CTU #9 - 2.0" CT. Job Objective: Mill XN & FCO MIRU CTU #9. NU BOPs and 2' Spool. RU Lub. MU Nozzle. Pump 1-3/16" drift ball. MU LH 3.80" milling assembly RIH mill out XN to 3.80". RIH tag @ 15,880'. POOH, BD BOT LH milling assembly. MU BOT RH milling assembley and 3.70" bi- center bit. RIH. RIH dry tag @ 15,885'. PUH start fluff & stuff taking 20' bites each time. 15,970' coming back thru btm perf WHP Increase and pull heavy. PUH and stop pumping to let WHP decrease. RIH dry tag @ 15,947' (whipstock setting depth 15,878' so 69' deeper / worked across setting depth). RIH to 15,981' PUH btm perf stuck. bleed off WHP and PUH. OE approved depth. Wait hour - RIH dry tag @ 15,855'. POOH FP CT and well w/62bbls diesel. RDMO CTU #9. ***Job Complete*** 10/8/2022 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(whipstock) PT 300L/3000H. SET BAKER HUGHES TOW AT 15878', 0 DEG ROHS. CCL TO TOW OFFSET: 21.3'. CCL STOP DEPTH: 15856.7'. TIE INTO PDS COIL FLAG/JEWELRY LOG DATED 26-DEC-2004. ***JOB COMPLETE, WELL SECURED AND TURNED OVER TO DSO*** 10/26/2022 T/I/O=300/175/0. Pre CDR. RU lub and set 4" H TWC. LTT against TWC(pass). RD 4" Uppermost tree. RD 4" M-60 SSV. RU CDR Tree assembly. torque to spec. RU Kill line to flow cross. torque to spec. PT tree assembly 500 low 5000 high (pass). Pull 4" H TWC. RD 4" tree cap. install 4" 5K tapped blind. torque to spec. PT blind against SV 500 low 5000 high (pass). FWPs=1000/175/0. ***RDMO*** SET BAKER HUGHES TOW AT 15878 Activity Date Ops Summary 11/30/2022 Spot rig over S-119. Rig spotted, start MIRU Ops. Rig accepted at 10:00. Open master & swab valves to tree cap, 0 psi WHP. Close Master & Swab and PT through the MP Line to 3500 psi. Good PT, remove tree cap and NU MP Line and BOPE. Test gas alarms, good. Continue M/U BOPs and MPD line. Need to install another 90 deg flange on MPD line to get it to line up. Get RKBs. Grease valves. Finish secure BOP stack. Change out packoffs. Flush and fluid pack surface lines. Test BOPs as per AOGCC and Hilcorp regulations. All tests to 250 / 3500 psi. Test witness waived by AOGCC Inspector Guy Cook. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind / Shears, R2, BL2, C15 - Pass. Test 3: Annular (2-3/8"), TIW1, B2, B4. 12/1/2022 Continue testing BOPs as per AOGCC and Hilcorp regulations to 250/3500 psi. Test witness waived by AOGCC Inspector Guy Cook. Test 4: Upper 2-3/8" Pipe / Slips, TIW2, B2, B3 - Pass. Test 5: Lower 2-3/8" Pipe / Slips, C5, C6, C8, TV2 - Pass. Test 6: Choke A, Choke C - Pass. Drawdown Test. Test 7: C1, C4, TV1 - Pass. Test 8: 3" Pipe / Slips, C2, C3 - Pass. BOP Test completed. 0 failures. RD test equipment & swap out risers. PT PDL's and risers and calibrate In Micro- Motion. Install BHI Floats and test. Good PT on floats. RU to pump 15 bbls of Neat Meth in the coil followed by 1% Slick KCl for pumping slack forward while we RIH. Online at 3.5 bpm. Gauge window & string mills. Pressure deploy Window milling BHA, 910 psi WHP. Bleed off pressure to TT, diesel returns to TT, blow down TT line with air. MU injector to BHA and stab on. RIH with Window Milling BHA pumping at 1.5 bpm taking all returns to the TT holding 100 psi over WHP, IAP = 178 psi. Slowly reduce WHP as RIH keep returns < 1:1. Up wt at 15500' is 69k. Log tie-in from 15500' correct -17'. Shut down, shut in vac out tiger tank. Continue logging down, no further correction. Close EDC. Light dry tag whipstock at 15919' around 36' deeper than expected. Open EDC and swap well to KCl. Pick up and repeat tie-in. Correct +1'. Continue swap well to KCl 2.5 / 2.1 bpm. Purge CT riser when clean KCl at surface. Clean KCl at surface, bleed off small increments of fluid from well to find formation pressure, about 9.77 ppg equivalent. Continue circulating mud around. Shut down again to vac out tiger tank then continue circulating. Purge CT riser with mud at surface, then bring returns to pits. Close EDC at 15900'. Bring pumps 2.75 / 2.5 bpm up wt 50k. Ease down to engage casing. Nothing seen up to 15926'. Pick up for dry tag, tag at 15930'. Pick up to tie-in depth again, no correction. RIH, dry tag 15930'. Whipstock is moving downhole. Discuss with ODE, POOH. Keep 10.2# ECD. 12/2/2022 Continue POOH from Whipstock Failure at 500'. Hold a PJSM to pressure undeploy the milling BHA. Maintain 450 psi WHP / 10.2 ECD at the window. Tag up and RIH 1.3' to space out for ram closure. Pressure Undeploy BHA, WO HES Mem Logger to bring tools to the rig. BHA OOH, WO HES to bring Caliper Logging tools to the rig. Well is currently taking ~2 bph @ 450psi WHP maintaining 10.2 ECD at the window. HES logger having vehicle issues but is on the way. HES logger on location, Program tool then load tools on the rig. Meme Tool = 40 Arm Caliper, CCL, Gamma, Temperature and pressure. Tool on at 11:14, fingers set to open at 17:25. Pressure deploy BHA. RIH with Caliper Logging BHA. Log tie in, correct depth -20'. RIH to Logging Depth. On depth to start logging up at 17:35 when the caliper fingers open. POOH logging up at 50 fpm. 18:00 Fingers will close, continue POOH. Maintain 10.2# ECD at window. Tag up, space out 1.3'. Undeploy BHA #2. Download and interpret data from caliper tool. Continue breaking down BHA #2, load whipstock onto rig. Deploy BHA #3 whipstock. Tool isn't testing, no communications. Strip injector up to expose UQC for troubleshooting. Wire and UQC test good. Undeploy BHA #3. L/D BHA #3. M/U BHA #4 and deploy. RIH BHA #4. Keep 10.2# ECD at window. 12/3/2022 Continue RIH with Whipstock BHA at 4400'. Log tie in at 15,715', correct depth -16'. RIH to 15920' (TOWS at 15,902'). PU WT = 54k, on depth at 15920' 0 HS, PU to 50k, close EDC and set WS. Tool sheared at 4100psi, set down 5k WOB, no movement, PU and open the EDC. EDC open online at 2.8 bpm to check for loss rate then POOH ~0.5 bpm. POOH for build BHA. OOH, pressure undeploy WS setting BHA. 465 psi WHP @ 10.26 ECD at the window. End NPT for failed WS set. BHA OOH, 3" Ram Autolock sequencing Valve is leaking. Sent notification to state to test 3" Ram, witness waived by Guy Cook. Replace valve swap out lubricators, function test ram and PT to 250 and 3500 psi. Good test, swap back to drilling lubricators, change packoffs and PT. Test completed, PU the milling BHA and pressure deploy. Mill and reamer 3.79" NoGo 3.80" Go. RIH BHA #5 keep 10.2# ECD at window. Tie-in depth from 15700' correct -12.5'. Up wt 51k. Closed EDC. Light dry tag (0.84k DWOB) find whipstock pinch point 15908.8'. Up wt 55k clean. Ease down to engage 7" casing. No DWOB or motor diff seen to 15911.86'. Pick up for dry tag. 50k up wt clean.. Dry tag 15913.2' this time. Pick up to tie-in depth again, correct +1.5'. Dry tag whipstock 15915.2'. From depths it appears this whipstock has moved down on top of the first one. Discuss forward plan with ODE. Tie-in depth and flag pipe for subsequent nozzle run. Flag pipe 15773.12' bit depth (15700' EOP). POOH keep 10.2# ECD at window. Undeploy BHA #5. L/D BHA. 12/4/2022 At surface after 2nd WS failure. WO decision from asset team to continue Ops here or RDMO. Decision made to RDMO swap to 2" and move. Make calls for fluids swap and prep a BHA to RIH and displace mud from well to 1% Slick KCl. MU a Nozzle BHA. RIH with Nozzle BHA to displace mud from well with KCl. Stop at 15744.62' MD EOP depth = 15700'. 15700 + 24.62' = 15724.62. -20' correction, correct depth and RIH. Tag, PU to 15900, WO fluids to swap well to KCl. Online with 1% Slick KCl at 4.2 bpm. POOH. Stop at 4000' at FP with 70 bbl diesel + 5 bbls 60/40 MeOH. Get 3 bbls diesel out POOH lay in fluid 1:1. At 200' MeOH at surface, shut in well POOH dry. Tag up, close MV w/ 580 psi on well. Bleed off then close SV. Pump 30 bbls corrosion inhibitor followed by 10 bbls MeOH. Cool down N2 purge reel with 2000 scfm for 26 min until N2 breaks through at nozzle. Bleed off pressure to tiger tank. L/D BHA #5. Service tree valves. Cut off CT connector, dress CT for grapple. Prep to unstab CT. Continue emptying pits. Install grapple and pull test. Pull CT out of injector and back to shipping spool, secure it there. 12/5/2022 Continue with reel swap. Trucks scheduled to be on location at 06:30 to swap reels. PJSM with Nabors & NES to swap reels. Swap reels, reels swapped. Start converting the Injector to 2". Swap out Stripper Brass & change riser. Swap out Goosenecks. Change gripper blocks. Install grapple and pull test. Pull CT off shipping spool and into injector. M/U UQC with no checks, anchor only. M/U injector to well. Roll reel back and install XO and hose inside reel to pump slack back. Fill reel backwards with 10 bbls MeOH followed by fresh water. Pump slack back, recover about 10' of cable enough to install the bulkhead. Break off circ hose, Install inner reel iron. Prep to install 2" rams in BOPs. Rig released 06:00 4/19/2023Spud Date: Well Name: Field: County/State: PBW S-119A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 50-029-23222-01-00API #: ACTIVITYDATE SUMMARY 12/8/2022 RD target 90, RU 5K blind w/ needle valve to FC, torqued to API specs, Installed tree cap to SV, Torqued to API specs, PT'd against SV 5000 PSI (Pass). RDMO 2/5/2023 ***WELL S/I ON ARRIVAL*** RAN 3.73" SWAGE, 4-1/2" TEL, 1-3/4" S-BAILER (MSFB), 80-170 FPM S/D @ 15,929' SLM /15,915' (4-1/2" x 7' BKR WS)( LOCATE 4-1/2" WLEG @ 15,722' SLM / 15,711' MD -11 CORRECTION RAN 4-1/2" GR, 3.70" x 20' DMY WHIPSTOCK TO 15,925' SLM / 15,914' MD -11 CORRECTION w/ NO ISSUES ***JOB COMPLETE, WELL LEFT S/I*** 2/16/2023 **WELL S/I ON ARRIVAL, DSO NOTIFIED*** (GYRO SURVEY) PT 300L/3000H RUN W/CH/X2 1 11/16'' WB/ GYRO TOOL MAX OAL 28' MAX OD 1.8'' RECORD DOWN WITH MULTIPLE STOPS FROM SURFACE TO 15825' PULL SURVEY DATA WITH MULTIPLE STOPS FROM 15825' TO SURFACE JOB COMPLETE ***WELL S/I ON DEPARTURE*** 3/26/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 1-11/16" SWIVEL, 2-1/8" ANTI-ROT CENT, 2-1/8" ANTI-ROT CENT, 3-1/8" CCL, 1-3/4" DCMOT, 2" BRT, 2-3/4" DPU, 3.625" NS MEW (41' OAL) SET NORTHERN SOLUTIONS MEDIUM EXPANSION WEDGE LOG CORRELATED TO PDS COIL FLAG DATED 26-DEC-2004 TOW SET DEPTH=15,883' CCL OFFSET=21.8' CCL STOP DEPTH=15,861.2' ***WELL LEFT S/I*** 4/1/2023 T/I/O=620/218/0 (INJECTIVITY/STEP RATE TEST) Pumped 5 bbls 60/40 down TBG. Punped 250 bbl 125* Fresh Water (Load TBG). Started Step Rate Test 1,2,3,4,5 bbls bpm for 5 min. each. FP TBG 67 bbls Crude. Upon Departure Wellhead secure SV,WV=Closed MV,IA,OA=Open FWHP=1960/243/389. Turn Well over to Dso. 4/11/2023 CTU #9 1.75" 0.156" CT. Job Scope: Cmt Whipstock & Mill Window MIRU CTU 9. MU Slb Slim Cmt BHA w/ 1.7" BDJSN. RIH. MIRU HES Cmt. Tag Whip Stock Pinch Point @ 15,905.3' CTM / 15,929'. Corr Depth 15,885.5' MD. PUH 10' Paint Flag @ 15,875.5' MD / 15,912' Mech. Kill well with 200bbls KCL, 60 bbls diesel. performed injectivity test. Pumped 29 bbls cement, Squeezed away 17 bbls, 500psi bump and laid in 12 bbls. Cleaned and contaminated down to whipstock ***Job in Progress*** 4/11/2023 (Assist CTU) TFS unit #3, Pumped 22 bbls 60/40, 231 bbls 1% KCL, 63 bbls of DSL, and 20 bbls Power Vis assisting CTU. ***Job Continued on 4-12-23*** Daily Report of Well Operations PBU S-119 Daily Report of Well Operations PBU S-119 4/12/2023 CTU #9 1.75" 0.156" CT. Job Scope: Cmt Whipstock & Mill Window Contaminate cement and clean out down to whipstock. Chase OOH. swap to diesel to freeze protect CT. Lay in 41 bbls diesel, down to 2000' TVD. Close swab. L/D SLB slim BHA Rig down Injector for well support to swap out for window milling equipment. Start picking up BOPs an prep for testing. ***Job continued on 4/13*** 4/12/2023 ***Job Continued from 4-11-23*** (Assist CTU) TFS U-3, Pumped 33 BBLS Powervis, 351 BBLS 1% KCL, 86 BBLS DSL. 4/13/2023 CTU #9 1.75" 0.0156" CT. Job Scope Cmt Whipstock & Mill Wndow Job Continued prep for BOP test. Finished getting equipment rigged up for milling. Rig up scaffolding, BOP test Completed BOP test Picking up Lubricator. Swap back to CTU Pump. """" Job Continued """"" 4/13/2023 (Assist CTU#9) TFS U-3, Pumped 29 bbls DSL assisting Coil with BOP and surface valves, and Check valve Tests. ***Job Continued on 4-14-23*** 4/14/2023 CTU #9 1.75" 0.0156" CT Job Scope Cmt Whipstock Mill Window Job Continued from 4/13/23 Swap back to CTU pump MU YJ MHA & NS milling BHA. Tag whipstock, pick up 3 ft above up weight and RIH to 2 ft prior to whipstock and start time milling. Finish milling window to 15897' Mill rathole to 15907' Backream & wash across window. ***Job Continued*** 4/14/2023 ***Job Continued from 4-13-23*** (Assist Coil) TFS U-3, SB for Coil until released.. 4/15/2023 CTU #9 1.75" 0.0156" CT Job Scope Cmt Whipstock Mill Window Job Continued from 4/14/23' Backream & wash across window Dry drifted in & out of the window clean. POOH freeze protect coil and well ***Job complete*** 4/16/2023 T/I/O = 0/250/0 Pre CDR2. RU Target 90 to flow cross, torqued to spec. RU 4" to 7" Crossover with 7" tapped blind and needle valve on a 90, Torqued to spec. Installed CDR platform. PT target 90 to 350 low 3500 high, Passed. PT Blind against Master 500 low 5000 High, passed. FWP = 0/250/0 4/16/2023 T/I/O = 0/250/0 Pre CDR2. RU Target 90 to flow cross, torqued to spec. RU 4" to 7" Crossover with 7" tapped blind and needle valve on a 90, Torqued to spec. Installed CDR platform. PT target 90 to 350 low 3500 high, Passed. PT Blind against Master 500 low 5000 High, passed. FWP = 0/250/0 Activity Date Ops Summary 4/17/2023 Remove jeeps and spot both modules over well. Set down and accept rig at 19:30. Connect Putz and begin warming up rig. LTT tree valves and remove tree cap and flange. R/U cellar. Shim and torque reel and saddle clamps. Spot tiger tank and return line. N/U BOPE. N/U MPD. N/U TV. Prep reel for inner reel iron. M/U Inner reel iron. 4/18/2023 Continue with reel swap Ops. Install reel iron. Swap out injector stripper brass. MU Pressure Bulkhead. Pull test grapple, good pull test. Stab coil. Pipe stabbed, MU CTC and BHI UQC. Test Eline/UQC, good test. Fill Coil - Pump 10 bbls of neat meth in coil followed by 140 Fresh Water. Pump additional coil volume of rig water. Continue circulating rig water through coil to get temperature down. Pressure test coil inner reel iron and CTC to 6700 psi. Good test. Grease remaining valves for BOPE test. Fluid pack BOPE and all surface lines for BOPE test. Shell test BOP's. Test BOPE per Hilcorp and AOGCC. Test witness waived by Kam StJohn. Test 1: IRV, Pack off, C7, C9, C10, C11. Test 2: Blind/Shear rams, R2, B2, C15. Test 3: Annular (2 3/8"), TIW #1, B#1, B#4 Bravo 4 fail. Grease all HCR's and manual valves. Still failing test. Continued failing test. Suspect air in hydraulic fluid from double ram swap. Circulate hydraulic fluid through closed loop to condition. Retest Test 3: Annular (2 3/8"), TIW #1, B#1, B#4 Bravo 4 - Pass. 4/19/2023 Continue Testing BOPE per Hilcorp and AOGCC. Test waived by Kam StJohn. Test 4: Upper 2-3/8" Pipe/Slips, TIW #2, B3, B3 - Pass. Test 5: Lower 2-3/8" Pipe/Slips, C5, C6, C8, TV2 - Pass 5k high PT. Test 6: Choke A, Choke C - Pass. Test 7: C1, C4, TV1 - Pass. Test 8: 3" Pipe/Slips, C2, C3 - Pass 5k High PT. Draw Down Test - Pass. 5k Full Body test for new lower double Gate and Rams 3 & 4. BOP Test Completed, test time 11-hrs from 23:30 to 10:30. RD test equipment and prep to test PDL's. Stab injector on the well and reverse 10 bbls of meth into the coil. Install BHI Floats and PT. Good PT, PU injector and MU the build BHA. PD the BHA, open up to the well, WHP = 520 psi. Deploy BHA and purge PDL to evacuate gas. Gas purged, MU coil to the BHA and stab on. RIH pumping at 2.5 bpm taking all returns to the TT holding 600psi WHP. Getting gas cut fluid back. Increase WHP to keep returns < 1:1. Stop at 4400' check torque on reel clamp bolts. Continue RIH slow past sliding sleeve nothing seen. Log GR from 15710' correct -6.5'. Circ well to KCl then mud from 15860'. Keep 10.8# ECD at window while circ mud to surface. Shut down and vac out tiger tank. Burp riser. Bring returns inside, out density solid. Close EDC, ease down tag 15907'. Bring pumps up 2.8 bpm. Drill from 15907'. 2.80 / 2.79 bpm In / Out. MW 8.73 / 8.79 ppg. Window ECD = 10.8 ppg w/ 70 psi WHP. 15990' 5 bbls lo/hi vis. Drill to TD of build. POOH keep 10.8# ECD at window. 4/19/2023Spud Date: Well Name: Field: County/State: PBW S-119A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 50-029-23222-01-00API #: Kyle Wiseman Hilcorp North Slope, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: kyle.wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Hilcorp North Slope, LLC Date: 02/03/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-119 -PTD 204-162 -API 50-029-23222-00-00 Definitive Directional Survey (Gyro + MWD Composited) Gyrodata Survey 02/16/2023 MWD 10/15/2004 Main Folder Contents: Please include current contact information if different from above. 1 Regg, James B (OGC) From:Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent:Saturday, December 3, 2022 4:43 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - CTD DSM Subject:Nabors CDR2AC BOP Test on S-119 Attachments:Nabors CDR2AC 12-1-22.xlsx Revised test form removing the “A” from the well name Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670‐3097 Cell (907) 268‐9140 Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com Alternate: John Perl Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU S-119PTD 2041620 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:12/1/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041620 Sundry #322-323 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250 /3500 Annular:250 /3500 Valves:250 /3500 MASP:2744 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank P P Annular Preventer 1 7-1/16" GK P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector P P #3 Rams 1 3.0" Pipe / Slip P H2S Gas Detector P P #4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2250 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)52 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1034 psi P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 & 1885 psi P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 4 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 1 P #3 Rams 4 P #4 Rams 4 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/29/22 19:53 Waived By Test Start Date/Time:12/1/2022 3:30 (date)(time)Witness Test Finish Date/Time:12/1/2022 7:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test all Rams & Valves to 250 psi low and 3500 psi high, no failures R.Coyne / W. Williams Hilcorp Alaska LLC M.Igtanloc / T. Kavanagh PBU S-119 Test Pressure (psi): robert.coyne@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2022-1201_BOP_Nabors_CDR2AC_PBU_S-119 =========North Slope LLC        ======= Bottle precharge 1034 psi jbr   J. Regg; 12/28/2022 1 Regg, James B (OGC) From:Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent:Saturday, December 3, 2022 4:40 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - CTD DSM Subject:Nabors CDR2AC 3" Ram Test Attachments:Nabors CDR2 3 inch Combi Ram Test.xlsx Attached is the test form to test our 3” Ram that had a hydraulic leak on the sequencing valve. The valve was replaced and the ram was functioned and pressure tested. Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670‐3097 Cell (907) 268‐9140 Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com Alternate: John Perl Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU_s-119PTD 2041620 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:12/3/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041620 Sundry #322-323 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:Bi-Weekly:Other:X Rams:250 /3500 Annular:N/A Valves:N/A MASP:2744 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 NA Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"NA Trip Tank P NA Annular Preventer 1 7-1/16" GK NA Pit Level Indicators P NA #1 Rams 1 Blind / Shear NA Flow Indicator P NA #2 Rams 1 2-3/8" Pipe / Slip NA Meth Gas Detector P NA #3 Rams 1 3.0" Pipe / Slip P H2S Gas Detector P NA #4 Rams 1 2-3/8" Pipe / Slip NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"NA Time/Pressure Test Result HCR Valves 2 2-1/16"NA System Pressure (psi)NA Kill Line Valves 1 2-1/16"NA Pressure After Closure (psi)NA Check Valve 0 NA 200 psi Attained (sec)NA BOP Misc 2 2.0" Piper NA Full Pressure Attained (sec)NA Blind Switch Covers:All stations NA CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 12 NA ACC Misc 0 NA Manual Chokes 1 NA Hydraulic Chokes 1 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer NA #1 Rams NA Coiled Tubing Only:#2 Rams NA Inside Reel valves 1 NA #3 Rams 4 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:0.3 HCR Choke NA Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/3/22 15:35 Waived By Test Start Date/Time:12/3/2022 15:45 (date)(time)Witness Test Finish Date/Time:12/3/2022 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors 3" Combi Ram Sequencing Valve hydraulic leak. Replaced valve, function test ram and pressure test to 250 low and 3500 high R.Coyne / W. Williams Hilcorp Alaska LLC M.Igtanloc / T. Kavanagh PBU S-119 Test Pressure (psi): robert.coyne@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2022-1203_BOP_Nabors_CDR2AC_combi-ram_PBU_S-119 =========North Slope LLC           J. Regg; 12/28/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Nabors CDR2AC (12-1 and 12-3) Date:Wednesday, December 28, 2022 2:54:30 PM Attachments:2022-1201_BOP_Nabors_CDR2AC_PBU_S-119.pdf 2022-1203_BOP_Nabors_CDR2AC_combi-ram_PBU_S-119.pdf PBU S-119 (PTD 2041620) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 3%86 +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. $'/ 1RQH1RQH / %DNHU3UHPLHU3DFNHU 1R6669,QVWDOOHG 1R6669,QVWDOOHG 0RQW\0\HUV 'ULOOLQJ0DQDJHU 7UHYRU+\DWW WUHYRUK\DWW#KLOFRUSFRP 358'+2(%$<$8525$2,/ -XO\ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& 5.25.2022 By Samantha Carlisle at 2:33 pm, May 25, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV %23(WHVWWRSVL 9DULDQFHUHTXHVWWR$$&F&$SSURYHGWRDOORZSULPDU\FRQWUROVIRU%23(WREHORFDWHGLQWKH2SHUDWLRQV &DELQRIWKH&7XQLWDQGWKHDFFXPXODWRUVWREHORFDWHGRQWKHEDFNVLGHRIWKH2SHUDWLRQV&DELQ '650*5-81 6)' -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.07 10:28:57 -08'00' RBDMS JSB 062922 7R $ODVND2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ )URP 7UHYRU+\DWW 'ULOOLQJ(QJLQHHU 'DWH 0D\ 5H 3%866XQGU\5HTXHVW 6XQGU\DSSURYDOLVUHTXHVWHGWRVHWDZKLSVWRFNDQGPLOOWKHZLQGRZLQ6DVSDUWRIWKH SUHULJIRUGULOOLQJDQGFRPSOHWLQJRIWKHSURSRVHG6$&7'ODWHUDO 3URSRVHGSODQIRU6$3URGXFHU 3ULRUWRGULOOLQJDFWLYLWLHVVFUHHQLQJZLOOEHFRQGXFWHGWR0,7DQGGULIWIRUZKLSVWRFN(OLQHZLOOWKHQVHWD[ IORZWKURXJKZKLSVWRFNLIQRWSRVVLEOHZLOOVHWZLWKULJ6HUYLFH&RLOZLOOPLOOWKH;1QLSSOHDQGWKHZLQGRZ 6HH6$37'UHTXHVWIRUFRPSOHWHGULOOLQJGHWDLOV$FRLOWXELQJGULOOLQJVLGHWUDFNZLOOEHGULOOHGZLWKWKH 1DERUV&'5ULJ7KHULJZLOOPRYHLQWHVW%23(DQGNLOOWKHZHOO,IXQDEOHWRVHWRUPLOOSUHULJWKHULJZLOOVHWD [IORZWKURXJKZKLSVWRFNDQGPLOODVLQJOHVWULQJZLQGRZ RIIRUPDWLRQ7KHZHOOZLOONLFNRII GULOOLQJDQGODQGLQWKH.XSDUXN7KHODWHUDOZLOOFRQWLQXHLQWKH.XSDUXNWR7'7KHSURSRVHGVLGHWUDFNZLOOEH FRPSOHWHGZLWKD[[´/VROLGOLQHUDQGFHPHQWHG7KLVFRPSOHWLRQ:,//DEDQGRQWKHSDUHQW .XSDUXNSHUIV7KHZHOOZLOOEHSHUIRUDWHGDQGIUDFNHGSRVWULJVHHIXWXUHSHUIIUDFVXQGU\ 7KLV6XQGU\FRYHUVSOXJJLQJWKHH[LVWLQJ.XSDUXNSHUIRUDWLRQVYLDWKHOLQHUFHPHQWMRERUOLQHUWRSSDFNHULIWKH OLQHUODSSUHVVXUHWHVWIDLOVDOWHUQDWHSOXJSODFHPHQWSHU$$&L 3UH5LJ:RUN(VWLPDWHGWRVWDUWHQGRI-XO\ 6OLFNOLQH'XPP\:6GULIW D 'ULIWSDVWZKLSVWRFNVHWWLQJORFDWLRQ )XOOERUH0,7,$DQG0,77WRSVL (OLQH6HW´[´ZKLSVWRFN D 7RSRIZKLSVWRFNVHWDW¶0'WRSRIZLQGRZDW¶0'SLQFKSRLQW E 2ULHQWHG/2+6 6HUYLFH&RLO0LOO1LSSOHDQG:LQGRZ D 0LOOWKH;1QLSSOHWR´DWa¶0' E 0LOO:LQGRZ , 0,586HUYLFH&RLO:LQGRZ0LOOLQJ6XUIDFH.LW ,, *LYH$2*&&KUQRWLFHSULRUWR%23(WHVW ,,, 7HVW%23(WRSVL0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL ,9 0LOO´ZLQGRZSOXV¶RIUDWKROH 9 6LQJOHVWULQJZLQGRZH[LWRXWRI´OLQHU 9DOYH6KRS3UH&7'7UHH:RUNDVQHFHVVDU\ 5LJ:RUN x 5HIHUHQFH3%86$37'VXEPLWWHGLQFRQFHUWZLWKWKLVUHTXHVWIRUIXOOGHWDLOV x *HQHUDOZRUNVFRSHRI5LJZRUN 0,58DQG7HVW%23(0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL D *LYH$2*&&KUQRWLFHSULRUWR%23(WHVW 6HW:KLSVWRFNRQO\LIQRWGRQHSUHULJ 0LOO:LQGRZRQO\LIQRWGRQHSUHULJ 'ULOO%XLOGDQG/DWHUDO 5XQDQG&HPHQW/LQHU 3HUIRUDWHRQO\LIQRWGRQHSRVWULJ )UHH]H3URWHFWDQG5'02 6HW/73 LIQHHGHGDQGSHUIRUDWHSRVWULJ 3RVWULJIUDF $SSURYHGDOWHUQDWHSOXJSODFHPHQWSHU$$&L 6XQGU\ SS FRPSOHWLRQ:,//DEDQGRQWKHSDUHQWS .XSDUXNSHUIV 37';; 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Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5; Regg,James B (DOA);Youngmun,Alex Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: OPERABLE: Producer S-119 (PTD#2041620)Warm TIFL Passed All, Producer S-119 (PTD#2041620)was made under evaluation on 06/23/17 for exceeding NOL on the inner annulus and failing a subsequent cold TIFL. The well was recently brought online and passed a warm TIFL on 07/11/17. The passing test confirms two competent well barriers. The well is now reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCAMS JUL2 02U1? VVO From: AK, GWO We egrity Engineer Sent: Friday, June 23, 201 • 8 AM To: AK, OPS GC2 OSM; AK, OPS Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK,OPS EOC Specialists; Cis` _- i, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; R- a James B (DOA) (jim.regg@alaska.gov); Youngmun, Alex Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT ' ntegrity; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Ob ',-witch, Beau; Sternicki, Oliver R; Worthington, Aras J; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer S-119 (PTD#2041620) Inne nulus over NOL- Failed TIFL All, Gas lifted Producer 5-119 (PTD#2041620)exceeded NOL on the inner annulus and failing a •sequent TIFL on 06/22/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The curre -stimate for S pad to 1 O • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,June 23, 2017 5:18 AM To: AK, OPS GC2 OSM;AK,OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Regg,James B (DOA);Youngmun,Alex Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer S-119 (PTD#2041620) Inner Annulus over NOL- Failed TIFL All, Gas lifted Producer S-119 (PTD#2041620)exceeded NOL on the inner annulus and failing a subsequent TIFL on 06/22/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The current estimate for S pad to come back online is 06/30/17. At this time the well is classified as Under Evaluation,and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations-POP well 2. Down Hole Diagnostics: Perform Warm TIFL 3. Well Integrity Engineer: Additional Diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SCANNED JUL 1 42011 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, June 18, 2017 2:43 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity Subject: Producer S-119 (PTD#2041620) High Inner Annulus Pressure Over NOL after pad shutdown. Mr. Regg, Gas lifted producer S-119 (PTD#2041620), were reported over NOL on 6/16/17. The pressures were reported to be T/I/O = 20/2028/50psi . The high pressure event was discovered after a pad shut down and appears to be caused by a spike in the gas lift supply header pressure. The plan forward is to bleed the IA and perform follow up monitors to ensure this is not an integrity issue; if we see any repressurization the well will be made under evaluation at that time. Please reply with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED JUN 2 3 2017, Office 907-659-8110 Cell 907-980-0552 Harmony 4530 4,000- 3,500 - 3.000 - 2,500 - 2.000 1.50dt • a.f ++ . a —• + +� + + s 1.000 - 500 - 03118/'17 03125/17 04/01117 04!08:' 04115/11 04122117 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, March 22, 2016 7:39 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5;Zoesch, Eric; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA) Subject: OPERABLE: Producer S-119 (PTD #2041620) TIFL Passed All, Producer S-119 (PTD#2041620) passed a TIFL on March 22, 2016. The passing TIFL confirms two competent downhole barriers. The well is reclassified as Operable. • Well status is Operable • A SSSV is not required Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus; SCANNED APR 1 $ 2016 BP Alaska-Well Integrity Coordinator GA/ Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent Friday, March 18, 2016 4:34 PM To: AIZ,'OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; 'Regg, James B (DOA) (jim.reqg@alaska.gov)' Subject: UNDER EVALUATION: Producer S-119 (PTD #2041620) Sustained Inner Annulus Casing Pressure Above MOASP All, Producer S-119 (PTD#2041620)was reported to have sustained inner annulus casing pressure above MOASP on March 16, 2016. The pressures were reported to be tubing/inner annulus/outer annulus 2130/2130/vac. A cold TIFL failed on 1 S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, March 18, 2016 4:34 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5;Zoesch, Eric; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg,James B (DOA) Subject: UNDER EVALUATION: Producer S-119 (PTD #2041620) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer S-119 (PTD#2041620) TIO Plot.docx All, Producer S-119 (PTD#2041620)was reported to have sustained inner annulus casing pressure above MOASP on March 16, 2016. The pressures were reported to be tubing/inner annulus/outer annulus 2130/2130/vac. A cold TIFL failed on March 18, 2016. The failing TIFL indicates a lack of two competent downhole barriers.The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. Operations: Place well on production 2. DHD: Re-TIFL 3. Slickline: Change out orifice gas lift valve (if necessary) A copy of the TIO plot is included for reference. Thank you, MAR 2 120116 Kevin Parks Port, BP Alaska-Well Integrity Coordinator GINI Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK— ,Z5&C Well Integrity Coordinator Sent: Wednesday, September 30, 2015.1:23 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field-O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Bergene, Matthew Subject: OPERABLE: Producer S-119 (PTD #2041620)TIFL Passed post valve changeout 1 • • • Producer S-119(PTD#2041620)TIO Plot 19 II on coon • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, September 23, 2015 5:44 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5;Zoesch, Eric; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer S-119 (PTD #2041620) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer S-119 (PTD #2041620) TIO Plot.docx All, Producer S-119 (PTD#2041620)was reported to have sustained inner annulus casing pressure above MOASP on September 20, 2015. The pressures were reported to be tubing/inner annulus/outer annulus 2010/2090/vac. A TIFL failed on September 23, 2015. The failing TIFL indicates a lack of two competent downhole barriers.The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. Slickline: caliper/change out screen orifice 2. DHD: Re-TIFL A copy of the TIO plot is included for reference. 2016 Thank you, Kevin Parks (AItevnote Whitney Pettus; BP Alaska-Well Integrity Coordinator GZ V Global Wells Y Y Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 • • Producer S-119(PTD#2041620)TIO Plot Wel it9 —0-- -4— ~ ~ June 25, 2009 ~'~~~- ~~ e~ ~~~~~~~~:1 Mr. Tom Maunder ~~L ~ ~, 2009 Alaska Oil and Gas Conservation Commission ~na~~~~ ~,~ ~, ~~,~ ~~r~ee ~a~m~~s~~a~ 333 West 7th Avenue ~r~r~+~r~~~~~ Anchorage, Alaska 99501 o2a~`~ ~~ ~'' Subject: Corrosion Inhibitor Treatments of S-Pad s- ~~ I g Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~, v n Y !* 4~ ~ J,., k^P ~~~ '+* "~ u'~'s ~,.~~ ~~.;~~'~'~.~: Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) &pad ~ne., r/25/2009 Well Name PTD N Initial top of cement Vol. of cement um ed Final top of cement Cement top otf date Corrosion inhibitor Corcosion inhibitod sealant date ft bbls it na al S-Ot8 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-o3 1811900 1325 NA 1325 NA 92.65 5/20/2009 S-Oa 1830790 0 NA 0 NA O,s 5/25/2009 S-o5A 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26J2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 S-o9 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-11B 1990530 0.25 NA 025 NA 1.7 SM27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/1I2009 5-13 1821350 8 NA 8 NA 55.3 6/7I2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-77C 2020070 025 NA 025 NA 2.6 6/1I2009 S-1BA 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-79 1861160 0.75 NA 0.75 NA 2.2 5/19/2009 S-20A 2070450 025 NA 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 1970510 OJS NA 0.75 NA 3 5/19/2009 5-23 1901270 0.25 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA S.t 5/31/2009 S-37A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 7901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1927360 0.5 NA 0.5 NA 3.4 5/37/2009 S35 1921480 0 NA 0 NA .85 in 5/31/2009 S-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 S-37 1920990 125 NA 125 NA 17.9 5/27/2009 5-38 19212~0 025 NA 025 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/26/2009 S-44 1970070 025 NA 025 NA 1.7 5/2&2009 S-io0 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29l2009 5-702L~ 2031560 125 NA 725 NA tt.t 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-706 2010120 1625 NA 16.25 NA ~74.3 6/2/2009 S-107 2011130 225 NA 225 NA 2a.9 5/18/2009 S-t08 2011000 3.5 NA 3.5 NA 40 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 1175 NA 11.75 NA 98.6 5/30/2009 5-11 t 2050510 2 NA 2 NA 19.6 5/30/2009 5-1~2 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-714A 2021980 1.25 NA 125 NA 102 5l30I2009 S-7t5 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 7.5 NA t3.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-118 S-179 S-720 2032000 2047620 2037980 5 1 5.5 NA NA NA 5 1 5.5 NA NA NA 76.5 52 672 5/2B/2009 5/30/2009 5/29/2009 S-121 2060470 4.5 NA 4.5 NA 53.8 5/28/2009 S-722 2050810 3 NA 3 NA 21.3 5/29/2009 S-72s 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA 71.9 5/26/2009 5-125 2070830 225 NA 2.25 NA 20.4 5/28J2009 5-126 20710970 125 NA 1.25 NA 15.3 6/1/2009 S-20o 1972390 125 NA 1.25 NA 14.5 5/28/2009 S-207 2001840 0 NA 0 NA 0.85 6/19/2009 S413A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 0.25 NA 025 NA 7.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/2&2009 S-407 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 ~ • ~ r ~:;-~ MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc ;),. 7 J,-~., DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2041620 Well Name/No, PRUDHOE BAY UN AURO S-119 Operator BP EXPLORATION (ALASKA) INC MD 16536 .-r TVD 7237 ~ Completion Date 12/27/2004 Completion Status 1-01L -~--_.- -- - - --""~--------"------"---------'----------'-- ----------.----..---- REQUIRED INFORMATION Mud Log No Samples No --~-,-_.,. ------._-- DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / PWD / RES / DEN / NEU Well Log Information: Log/ 7' Digital Ty Med/Frmt , 0 0 Rpt G"og "~ Electr Dataset Number Log Log Run Scale Media No Name Directional Survey Directional Survey 14196 Induction/Resistivity 25 Slu ¡JI D 14196 Induction/Resistivity 25 Blu ¡V j) ~/ i I C Lis 14196 LIS Verification Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ "- - --~----_._---_._---_._- --.,--- _·__________·m"'~·__·_n_·_". . Comments: Current Status 1-01L API No. 50-029-23222-00-00 UIC N Directional Survey Yes ~-,_._--~~~-~~ (data taken from Logs Portion of Master Well Data Maint Interval OH I Start Stop CH o 16536 o 16536 11 0 16536 Open Received 1 0/25/2004 1 0/25/2004 1 0/25/2006 110 16536 Open 10/25/2006 110 16536 Open 10/25/2006 Sample Set Number Comments ~: Comments . TVD Composite Vision Density Neutron COR 11- Oct-2004 w/Graphics MD Composite Vision Density Neutron COR 11- Oct-2004 w/Graphics FET, ROP, GR, DRHO, NPHI . Permit to Drill 2041620 MD 16536 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. PRUDHOE BAY UN AURO S-119 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23222-00-00 7237 a,J",,,,_tion Date .12/27/2004 Completion Status 1-01L Current Status 1-¡ILrJ. J UIC N ý:J--o . Date: '1 ~ ~7 . . Sclllulllberger SchlumOOrger-DCS 2525 Gamoon St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Wen Job# r,.), (',-'-r "" t ". /.;) l006 &, Log Description S-123 S-119 L-216 40010951 OH EDIT OF MWD/LWD 40010957 OH EDIT OF MWD/LWD 40010478 OH EOIT OF MWD/LWD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered" dÓL1- /~~ ~ lL.£JCj0 09/19/04 10/11/04 05/07/04 10/24/06 NO. 4013 Company: Alaska Oil & Gas Cons Comm Altn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Oate CD BL Color 2 2 2 . Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: . - (ñ)![ Æ'n ~~! /Æ UlJ lJ Lrl.~ Lb ut1 ~ I \.\ Lfîj · 4~ ,~& AI/ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Young Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-119 Sundry Number: 305-045 Dear Mr. Young: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior unless rehearing has been requested. DATED thist day of February, 2005 Enc!. e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 J .. 1, Type of Request: Abandon 0 o D Suspend 0 RepairWell 0 Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD / Waiver 0 Stimulate]] Time Extension 0 Re-enter Suspended Well D 5, Permit to Drill Number: 204-1620 / Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. / Development ]] Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD Service D 9. Well Name and Number: S-119 " 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 16370 7057.5 S~ MD WD 7. KB Elevation (ft): 61.90 KB 8. Property Designation: ADL-028256 11, Present Total Depth MD (ft): 16536 Casing I Total Depth TVD (ft): 7236.7 Length V-' 4Ar 't /'- 2. {2.00<; D 75 z/ z2-/.s "" ~ Other 0 6, API Number /" 50-029-23222-00-00 Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom Conductor 80 20" 91.5# H-40 29 109 29.0 109.0 1490 470 Production 16489 7" 26# L-80 25 16514 25.0 7221.1 5210 2480 Sur1ace 6672 10-3/4" 45.5# L-80 28 6700 28.0 3416.0 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 15857 - 15882 6778 - 6795.0 4-1/2 " 12.6 # L·80 22 15711 Packers and SSSV Type: 4-1/2" Baker Premier Packer Packers and SSSV MD (ft): 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal ŒI Detailed Operations ProQram D BOP Sketch D 14. Estimated Date for CommencinQ Operation: 15650 / Exploratory D DevelopmentOO ServiceD 15. Well Status after proposed work: Oil ]] GasD PluggedD AbandonedD February 25, 2005 16. Verbal Approval: Date: WAG 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJD Contact Printed Name Signature Jim vofn ~ 7 Title Phone Petroleum Engineer 564-5754 2/15/05 I Sundry Number: JDS -.. t'$A; - Location Clearance D Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D Other: Subse I 0 .- 4-0 4-. BY ORDER OF THE COMMISSION Date fzl f( WINJD WDSPLD Prepared by Garry Catron 564-4657. Jim Young RBDMS 8Ft MAR 0 'i 2005 Form 10-403 Revised 11/2004 SUBMIT IN DUPLICATE Aurora Field bp .,. .._t.~". ......~ ~~. .~~ ~. .,~,~~\\.. ". e e Memorandum To: G ANC Wellwork Program Date: 15/02/2005 From: Jim Young 564-5754, hm: 248-0133, cell: 440-8007 PE, GPB WF PECT: lOR: Est. Cost: AUD5M0082 2000 $650,000 Distribution: JPV /SlopelWellfile Subject: S-119 Frac For diagnostics, the frac operation will consist of a DataFRAC and the main frac will have proppant traced with radioactive materials that are approved for Class II disposal. The frac will consist of pumping ±183 Mlb of 16/20 and 26Mlb of 12/18 C0/9.. o-lite proppant, resulting in a 120 foot propped length with an average prop concentration of ± 5 Ib/~ S-119 Max Deviation: Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Well bore Fluids: 71 ° at 9205' MD 50° @ 15800' MD 3.725" XN Nipple @ 15700' / PTBD at 16370' (SL tag 10/15/04) CTC Perfs Not tested (new well, <10ppm in reservoir). Crude in tubing, gas-lift in IA. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007 or Steve Deckert W:564-4128, H:338- 1476) if there are any questions. cc: Well File Charlie Mitchell Jim Young S. Rossberg Steve Deckert GPB Wells Aide TREE'¡: .. _~ËLL~EAD= ACTUATOR = , .,.~ KB. ELEV = BF. EtEV = KOP= ~.~,« =.= Max Angle = u UUUMU~ Datum MD = -~ -««-~~~ Datum1VD= 4-1/16" CrN FMC NA 64.3' e 339 fl_~ ,~< 71 @ 9300' . MMUU~U.^_U_ ~ 15832' ,fl= . m"" 6700' SS 110-3/4" CSG, 45.5#, L-80, 10 = 9.950" H 6700' r----JI Minimum ID = 3.725" @ 15698' 4-1/2" HES XN NIPPLE 8-119 I S.NOTES: - - =-1 980' H 10-314" TAM PORT COLLAR I I 2213' 1-14-1/2" HES X NIP, 10 = 3.813" I ~ GAS LIFT MANDRB...5 ST MD 1VD DEV TYÆ VLV LATCH PORT DATE L 5 5517 3005 69 KBG-2-1R DMY BK 0 11/09/05 4 7728 3790 70 KBG-2-1R DOME BK 16 11/09/04 3 12913 5598 70 KBG-2-1R DOME BK 16 11/09/04 2 15199 6404 66 KBG-2-1 R DMY BK 0 10/18/04 1 15519 6562 54 KBG-2-1 R SO BK 24 11/09/04 - I I - I 15588' 114-1/2"BKRCMDSLlDINGSLV, 10=3.813" w / BX PROFILE :8': z-----i 15650' -f7" x 4-1/2" BKR PREMIER PKR, ID = 3.875" 15678' -f4-1/2" HES x NIP, 10 = 3.813" I ! 15698' 1-14-1/2" HES XN NIP, ID = 3.725" 1 !4-1/2"TBG,12.6#,L-80TC11, .0152bpf,ID=3.958" H 15711' ~ ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: 49@ 15882' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 15882 - 15857 0 12/27/04 I PBTD H 16430' IT' CSG, 26#, L-80, 10 = 6.276" -f 16514' DATE 10/19/04 02/08/05 02/08/05 DATE REV BY ITLP BMcNlTLH JAFITLH COMMENTS ORIGINAL COM PLETION ÆRFS (12/27/04) CORRECTIONS & GL V C/O \ 15711' -f 4-1/2" WLEG, 10 = 3.958" 1 -f ELMO TT NOT LOGGED I ~ 15856' -f T' MARKER JOINT 1 ~ REV BY AURORA UNIT WELL: S-119 ÆRMIT No: 2041620 API No: 50-029-23222-00 SEe 35, T12N, R12E, 449T NSL & 4498' WEL COMMENTS BP Exploration (Alaska) a STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: !HI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD / GR, MWD / GR / PWD / RES / DEN / NEU CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE lOP BoTTOM lOP BoTTOM SIZE Surface 110' Surface 110' 42" 28' 6700' 28' 3416' 13-1/2" 25' 16514' 25' 7221' 9-7/8" o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P,O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4497' NSL, 4498' WEL, SEC, 35, T12N, R12E, UM Top of Productive Horizon: 4154' NSL, 2902' WEL, SEC. 21, T12N, R12E, UM Total Depth: 4554' NSL, 3208' WEL, SEC. 21, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 y- _ 5980700 _ Zone-__~l'i___ TPI: x- 609791 y- 5990778 Zone- ASP4 Total Depth: x- 609479 y- 5991174 Zone- ASP4 -----~-----~---- --------~---------- --~----~-- 18. Directional Survey !HI Yes 0 No 22. CASING SIZE 20" 10-3/4" 7" WT.PER FT. 91.5# 45.5# 26# GRADE H-40 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 15857' - 15882' 6778' - 6795' 26. Date First Production: December 30, 2004 Date of Test Hours Tested PRODUCTION FOR 1/13/2005 4 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 241 717 24-HoUR RATE One Other 5. Date Camp., Susp., or Aband. 12/27/2004 6. Date Spudded 9/27/2004 7. Date TD, Reached 10/11/2004 8, KB Elevation (ft): 61,9' 9, Plug Back Depth (MD+ TVD) 16370 + 7119 10, Total Depth (MD+TVD) 16536 + 7237 11. Depth where SSSV set (Nipple) 2213' MD 19. Water depth, if offshore N/ A MSL 24. SIZE 4-1/2", 12,6#, L-80 1b. Well Class: !HI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-162 13. API Number 50- 029-23222-00-00 14. Well Name and Number: PBU $-119 15. Field / Pool(s): Prudhoe Bay Field / Aurora Pool Ft Ft 16. Property Designation: ADL 028256 17, Land Use Permit: 20. Thickness of Permafrost REcrtfiËÜ JANl 8 2005 AI',k.flil IlL roo.. ,.. ... .AMoUNt CEMENTìF.Jê'?li!!COR60ns. Cnl1Jr.ritfMñLED 260 sx Arctic Set (AriJIo~àr;::f1 1049 sx AS Lite, 326 sx Clasš¥G' 468 sx Class 'G' TUBING RECÖRD DEPTH SET (MD) 15711 ' PACKER SET (MD) 15650' 25. ACID, FRActURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 120 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-BBl GAs-McF WATER-BBl 89 204 -0- Oll-BBl 536 27, GAs-McF 1,226 WATER-BBl -0- CHOKE SIZE I GAS-Oil RATIO 1760 2,286 Oil GRAVITy-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none", 7(ih:',.:'i^~~'r~:"';,"":::;<:<:"'/f None i/~;~ i >'·...TV~~" ~ t " L;tí :-,1...:'" ! ..., -:t::__ ¡ .~~"",.-........,............-.i Form 1 0-407 Revised 12/2003 RBDMS 8Ft JAN 24 2005 CONTINUED ON REVERSE SIDE (o::J:: 28. GEOLOGIC MARK. NAME MD TVD Ugnu 7236' 3611' Ugnu M Sands 1041' 4723' Schrader Bluff N Sands 11155' 4980' Schrader Bluff 0 Sands 11476' 5090' BAse Schrader Bluff I Top Colville 12249' 5361' HRZ 15718' 6686' Kalubik 15798' 6739' Kuparuk C 15852' 6775' Kuparuk B 16202' 7005' Kuparuk A 16437' 7166' 29. . FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None'. None 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed Terrie Hubble ~ ~ ~ Title Technical Assistant Date 0/../ A, OS PBU S-119 204-162 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jim Smith, 564-5773 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 18: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval), ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None'. ITEM 29: List all test information, If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 6,700.0 (ft) Name $-11 9 IC 10/4/2004 LOT . . 0/18/2004 9:58:26 AM (ppg) 2.41 Printed: 2,202 (psi 490 (psi Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 9/24/2004 03:00 - 00:00 21.00 MOB P PRE Move rig to S-119. Rig went through road while moving to the North pad extension, The rig was jacked up on timbers and the rear booster wheel was installed, the rig then proceeded with the move, 9/25/2004 00:00 - 02:00 2,00 MOB P PRE Continue moving rig on to North pad. 02:00 - 10:30 8,50 RIGU P PRE Lay mats around S-119, Lay herculite , Set diverter and wellhead equipment in place behind rig. Make changes in rig cellar necessary for 15' well centers 10:30 - 13:00 2.50 RIGU P PRE Spot rig over S-119, shim and level 13:00 - 22:00 9.00 RIGU P PRE Nipple up diverter,diverter line, annular preventer, riser and flowline. Spot pit and pump modules. RIG ACCEPT @ 18:00 hrs 22:00 - 00:00 2.00 RIGU P PRE Spot service modules and barrel warming shack. Calibrate gas alarms. Inspect derrick. Enclose rig cellar with tarps. 9/26/2004 00:00 - 02:00 2.00 RIGU P PRE Take on Spud mud. 02:00 - 03:00 1.00 BOPSUP P PRE Function test diverter. Verify the closing of the Annular preventer acuates the opening of the knife valve. Witness of diverter test waived by Jeff Jones with AOGCC. Hold diverter and rig abandonment drills 03:00 - 03:30 0.50 RIGU P PRE Rig service, service all equipment prior to spud. 04:00 - 07:00 3.00 RIGU P PRE Pick up bit to clean out conductor. Fill stack with fresh water, annular and knife valve leaking, all fluids captured in secondary containment. Tighten flanges. 07:00 - 08:00 1.00 RIGU P PRE Fill stack and cleanout to bottom of conductor 08:00 - 09:00 1.00 RIGU P PRE Berm in pit complex and cellar box. 09:00 - 19:00 10,00 RIGU P PRE PU 207 joints of 5" DP, standing back stands 19:00 - 21 :00 2.00 RIGU P PRE PU jars, HWDP, Monel DC's stand back in derrick 21 :00 - 23:30 2.50 RIGU P PRE PU and orient BHA #1,13-1/2" HTC MX-C1 with 9-5/8" 1.21 degree motor. 23:30 - 00:00 0.50 RIGU P PRE RIH and tag up @ 99.4' 9/27/2004 00:00 - 00:30 0.50 RIGU P PRE Circulate to fill mud lines, test mud lines to 3200 psi. 00:30 - 03:00 2.50 DRILL P SURF Drill from 99' to 265' WOB = 5-8 klbs RPM Surf= 20-40, DH = 100 GPM = 450 @ 750 psi on Btm, 660 psi off Btm P/U 65k 8/0 65k ROT 65k 03:00 - 03:30 0,50 DRILL P SURF Stand back 2 stands of HWDP 03:30 - 04:30 1,00 DRILL P SURF MU and RIH with a stand of DC's and the jar stand. 04:30 - 05:00 0.50 DRILL P SURF Run gyro survey 05:00 - 00:00 19.00 DRILL P SURF Directional drill from 265' to 1394', sliding as required to build angle. Run gyro survey every other stand to 641'. Inclination 37,2, Azimuth 293.6 @ 1406' WOB = 30-35 klbs RPM Surf= 20, DH = 110 GPM = 500 @ 1050 psi on Btm, 740 psi off Btm P/U 85k SIO 80k ROT 83k 30' wipe on each stand with no rotation on the down stroke. Printed: 10118/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 9/27/2004 05:00 - 00:00 19.00 DRILL P SURF ART last 24 hrs. =1.15 hrs. AST last 24 hrs. = 13.5 hrs, Total drilling hours = 14.65 hrs 9/28/2004 00:00 - 20:00 20.00 DRILL P SURF Directional drill from 1394' to 2619', sliding as required to build angle. WOB = 15-40 klbs RPM Surf= 50, DH = 174 GPM = 560 @ 1530 psi on Btm, 1150 psi off Btm T q on bottom 1 OK, T q off 7K P/U 95K S/O 75K ROT 88K AST 14.15 hrs, ART 2.15 hrs, ADT 16.30 hrs. 20:00 - 21 :00 1.00 DRILL P SURF - CBU x 1.5 until shakers cleaned up 21 :00 - 00:00 3.00 DRILL P SURF - POH to HWDP - Dry wipe 2 stands w/ tight spots @ 1642' & 1520' w/ max overpull of 25K. Hole in good condition wlo pumping out· no swab. 9/29/2004 00:00 - 01 :00 1.00 DRILL P SURF - POH & stand back BHA. UD orienting sub & bit. Reconfigure motor to 1.15 deg bent housing. M/U new bit & orient tools. 01 :00 - 02:00 1.00 DRILL N SFAL SURF - Replace Anadrill SPT sensor & cable on standpipe & hook load sensor on deadline. 02:00 . 02:30 0.50 DRILL P SURF - Clear & clean rig floor. 02:30 . 05:00 2.50 DRILL P SURF - RIH & wash down last stand from 2530' to 2619'. 05:00 - 00:00 19.00 DRILL P SURF - Drill ahead in 131/2" surface hole from 2619' to 5546' MD. · WOB 18K - 45K. - Pump rate 650 GPM - pressure on bottom 2300 psi - off bottom 1980 psi. - Surface RPM - 100, DH RPM 244. - T q on bottom 16K - off bottom 1 OK. - P/U wt 138K, SIO wt 75K, Rot wt 97K, - AST 5.33 hrs, ART 6,97 hrs, ADT 12.3 hrs, - SV 6 top @ 1834' MD - 1620' TVD - SV 5 top @ 3296' MD - 2227' TVD · SV 4 top @ 3780' MD - 2398' TVD · SV 3 top @ 5146' MD - 2876' TVD 9/30/2004 00:00 - 13:30 13,50 DRILL P SURF - Drill 13 1/2" hole from 5546' to 6713', - WOB 10K - 45K · 700 GPM - pump pressure on bottom 2450 psi, off bottom 2180 psi. - Surface RPM 100, DH RPM 255. - Tq on bottom 16K, Tq off bottom 10K - P/U wt 155K, S/O wt 75K, Rot wt 112K. - AST 3.48 hrs, ART 4.9 hrs, ADT 8.38 hrs. 13:30 - 14:30 1,00 DRILL P SURF - CBU @ 700 GPM 2180 psi, reciprocating & rotating @ 110 RPM, Rack back 3 stands while doing this. 14:30 - 20:30 6.00 DRILL P SURF - POH to 6000'. Work one tight spot at 6050'. No further progress above 6000' - tight. Backream from 6000' to 2521' @ 100 RPM, 670 GPM, 1700 psi. 20:30 - 21 :30 1.00 DRILL P SURF - CBU x 1.5 @ 670 GPM, 1400 psi. - POH slowly & rack back 2 stands while CBU, 21 :30 - 23:00 1.50 DRILL P SURF - Pump out of hole from 2313' to 1934' @ 4 BPM, 200 psi. Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 9/30/2004 21 :30 - 23:00 1.50 DRILL P SURF - POH from 1934' to HWDP wI no overpulls. 23:00 - 00:00 1.00 DRILL P SURF - Continue POH wI BHA & clean up clay build-up on stab sleeves. 10/1/2004 00:00 - 00:30 0.50 DRILL P SURF - Clean rig floor. 00:30 - 04:30 4.00 DRILL P SURF - M/U BHA & RIH to 6686', PIU single & wash down to TO @ 6713'. 04:30 - 05:30 1.00 DRILL P SURF - CBU @ 700 GPM 2300 psi, reciprocating 30' & rotating @ 100 RPM. 05:30 - 09:00 3.50 DRILL P SURF - POH from 6713' to 5264'. - Pump dry job & BID TO. - POH from 5264' to BHA. 09:00 - 11 :30 2.50 DRILL P SURF - POH & UD BHA. 11 :30 - 13:00 1.50 DRILL P SURF - Clear rig floor of tools & clean rig floor. 13:00 - 15:00 2.00 CASE P SURF - R/U casing tools. 15:00 - 15:30 0.50 CASE P SURF - PJSM for running 103/4" casing. 15:30 - 20:00 4.50 CASE P SURF - RIH w/52 jts 103/4" BTC L-80 45,5# casing to 2155'. Break circ every 20 jts & pump additional 50 bbls to condition mud, - M/U Tq - 8250 ft/lbs. - S/O wt 90K to 100K 20:00 - 23:30 3.50 CASE P SURF - Pipe stacking up wi S/O wt 45K to 50K. - Wash down from 2155' to 2983' @ 4 BPM 300 psi. - Attained 2 BU while washing down jts 53 - 71. 23:30 - 00:00 0.50 CASE P SURF - Continue RIH wi 103/4" BTC L-80 45.5# casing from 2983' to 3230'. S/O wts improving from 65K to 75K. 10/212004 00:00 - 02:00 2.00 CASE P SURF - Continue RIH wi 103/4" BTC L-80 45,5# casing from 3230' to 4555'. 02:00 - 03:00 1.00 CASE P SURF - CBU to cond mud while working pipe @ 5 BPM - ICP 400 psi, FCP 280 psi. P/U wt 210K, SIO wt 70K to 80K. No losses, 03:00 - 06:30 3.50 CASE P SURF - Continue running casing. MU TAM port collar on jt #138 with centralizer 20' above & 20' below port collar, Run a total of 161 jts 103/4" casing. MU hanger and landing jt. Circ casing down and land on hanger with shoe at 6700' MD. 06:30 - 07:30 1.00 CASE P SURF - RD Franks fill-up tool. Install XO nipple in top of landing jt and MU cement head and hose, 07:30 - 13:30 6.00 CEMT P SURF - Break circ at 4 BPM and stage up by 1 bpm every 10 minutes to 12 bpm while reducing rheology of mud prior to cement job. Attempt to reciprocate casing to PU wt of 375 klbs - no success. Will cement without pipe movement. - Repair washout on mud manifold while circulating. - PJSM for cement job while circulating. 13:30 - 16:30 3.00 CEMT P SURF - Switch to cementers. Pump 3 bbls fresh water & pressure test lines to 3000 psi. - Pump 10 bbls CW 100 followed by 72 bbls 10.5 ppg Mud Push with red dye in first tub. - Drop bottom plug. - Mix & pump 800 bbls (1010 sx) 10.7 ppg lead Arctic Set Lite followed by 68 bbls (326 sx) 15.8 ppg Class G tail cement. Pump rate 5 BPM to 8 BPM, 200 to 300 psi. Release top plug and kick out with 10 bbl water from OS, 16:30 - 18:00 1.50 CEMT P SURF - Switch to rig pump & displace cement @ 8,7 BPM 900 psi start. Adjust displacement rate between 5-8 bpm as needed for Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/2/2004 16:30 - 18:00 1.50 CEMT P SURF truck logistics. Saw red dye at 280 bbl displaced. Continue displacing and seeing clabbered mud until 600 bbl displaced. Getting 11.0 ppg cmt back. Bump plug as calculated and pressure up tp 3000 psi - OK. Got 20 bbls cement back to surface. CIP at 17:50 hrs. 18:00 - 19:30 1.50 CEMT P SURF - Check floats - holding. RID cement head, landing jt, & casing equip't. 19:30 - 20:30 1.00 CEMT P SURF - Remove long bails, R/U flushing tool & flush riser & annular preventer wI fresh water. R/D & B/D TO, 20:30 - 00:00 3.50 BOPSUF P SURF - N/D diverter line & riser. 1 0/3/2004 00:00 - 02:00 2.00 BOPSUF P SURF - N/D annular preventer & diverter spool. Remove diverter spool from cellar. 02:00 - 02:30 0.50 WHSUR P SURF - Install FMC split speed head. 02:30 - 14:30 12.00 BOPSUF P SURF - N/U BOPE, riser, flow line, & drain lines. Install turn buckles & function test BOP. - Test seal area between hanger & starting head to 1000 psi for 10 min. 14:30 - 19:00 4.50 BOPSUP P SURF - R/U test equip't & test BOPE to BP & AOGCC Regs. 250 psi / 4000 psi for 5 min per test. Witness of BOP test waived by AOGCC Rep Chuck Scheve. 19:00 - 20:00 1.00 BOPSUPP SURF - RID test equip't & install bowl protector. 20:00 - 21 :00 1.00 CASE P SURF - Install bails, clear rig floor, & install auto stripper, 21 :00 - 22:00 1,00 CASE P SURF - M/U BHA # 3 - 9 7/8" MXC-1, bit sub wi float, 1 stand NM spiral DC's, saver sub, jars, & 8 jts HWDP, 22:00 - 00:00 2.00 CASE P SURF - RIH to 975' & rotate through Tam port collar. Tag port collar w/ 5K. Rotate through port collar for 5' wi 3K to 5K WOB, P/U & repeat x 3. 10/4/2004 00:00 - 07:00 7.00 CASE P SURF - Pressure test below Tam port collar to 1500 psi & hold for 5 min. - RIH wI BHA # 3 picking up 102 5" DP singles out of pipeshed followed by 20 stands out of derrick. - Calibrate drilling & M/U torque on TO, 07:00 - 08:00 1.00 CASE P SURF - Wash down from 6581' to 6604'. - CBU & B/D TO. 08:00 - 09:30 1.50 CASE P SURF - Rack back 1 std DP - RIU & test 10 3/4" casing to 3500 psi & hold for 30 min. 09:30 - 11 :30 2.00 P PROD1 - Drill out shoe track & clean out 13' rathole. 11 :30 - 15:00 3.50 P PROD1 - Displace to 9.7 ppg LSND drilling fluid & drill 20' of new hole from 6713' to 6733'. 15:00 - 16:00 1,00 P PROD1 - RIU & conduct LOT to 12.4 ppg EMW. 16:00 - 17:00 1.00 P PROD1 - Circulate & condition mud, - Monitor well - pump dry job - BID TO. 17:00 - 20:00 3.00 P PROD1 - POH from 6733' to BHA. 20:00 - 20:30 0,50 P PROD1 - Handle BHA. 20:30 - 00:00 3.50 P PROD1 - Adjust riser & install elbow in flow line to new pits, 10/5/2004 00:00 - 00:30 0.50 P PROD1 - Finish installation of flow line elbow to new pits, 00:30 - 05:00 4.50 P PROD1 - P/U BHA # 4 - RSX191 PDC bit, bias unit, control collar, NM Rec stab, COR, MWD, ADN, NM spiral DC, NM stab, NM spiral DC, saver sub, 6 1/4" jars, & 8jts HWDP, - Shallow test bias unit & MWD. - PJSM - Load radioactive source in ADN, Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/5/2004 00:30 - 05:00 4.50 P PROD1 05:00 - 14:30 9.50 P PROD1 - RIH while P/U 5" DP singles from pipeshed to 6637'. 14:30 - 16:30 2.00 P PROD1 - Slip & cut drilling line. - Service TO & drawworks. 16:30 - 18:00 1.50 P PROD1 - Circulate & condition mud and pumped 40 bbl EP mud lube pill @ 13.5 BPM 1450 psi. Tq 16K before pill pumped - 7K after pill pumped. 18:00 - 00:00 6.00 P PROD1 - Drill directional in 9 7/8" hole w/ rotary steerable from 6733' to 7390' MD backreaming 30' each stand at full drilling rate & 75% drilling rate on down stroke. - Established clean hole ECD @ 10.19 ppg. - Drilling parameters @ 7390' - 630 GPM 1950 psi, WOB 11 K , 140 RPM, Tq on bottom 9K ftllbs, Tq off bottom 7K ft/lbs. P/U wt 135K, S/O wt 95K, Rot wt 113K. ADT 2.95 hrs. - RSS responding to down links. - Top of UG4 @ 7238' MD - Began backreaming full stands as actual ECD's increased ,5 ppg to.6 ppg over calculated. - Address drill string harmonics as needed with WOB I RPM adjustments. 1016/2004 00:00 - 13:30 13,50 DRILL P PROD1 - Drill ahead in 9 7/8" hole wI RSS from 7390' to 9171' backreaming full stands. - Pump 40 bbl hi-vis sweeps alternating w/ hi vis weighted sweeps every 500' to help manage ECD. - Drilling parameters: 630 GPM 2200 psi, WOB 7K to 17K, 140 RPM, off bottom Tq 9K ft/lbs, on bottom Tq 11 K ft/lbs, - RSS responding to downlinks. - Address drill string harmonics as needed wI WOB I RPM adjustments. - P/U wt 150K, S/O wt 95K, Rot wt 115K. 13:30 - 14:30 1.00 DRILL P PROD1 - Pump 2.0 ppg over MW sweep & circulate surface to surface @ 630 GPM 2300 psi, 140 RPM to manage ECD which were approaching .7 ppg over calculated. After circulation ECD .4 ppg over calculated. 14:30 - 18:00 3.50 DRILL P PROD1 - Drill ahead in 9 7/8" hole w/ RSS from 9171' to 9500" backreamin9 full stands.- - Drilling parameters: 630 GPM 2280 psi, WOB 10K to 15K, Tq on bottom 12K ft Ibs, Tq off bottom 10K ft/lbs. 18:00 - 21 :30 3.50 DRILL P PROD1 - Mix & pump 3.0 ppg over MW low-vis soap sweep & circulate surface to surface & 1 additional B/U @ 630 GPM 2150 psi 200 RPM. Sweep brought back 25% excess cuttings. ECD dropped from 11.3 ppg to 10.8 ppg. 21 :30 - 00:00 2.50 DRILL P PROD1 - Control drill directional to less than 250 FPH for ECD in 9 7/8" hole wI RSS from 9500' to 9734' backreamin9 full stands. - ECD .5 to .6 ppg over calculated. . Drilling parameters: 630 GPM 2280 psi, WOB 10K to 15K, Tq on bottom 12K ft Ibs, Tq off bottom 10K ft/lbs, - Formation tops: UG4A 7362' MD, UG3 8128' MD, UG1 9601' MD, 10/7/2004 00:00 - 02:00 2.00 DRILL P PROD1 - Directionally Drill 97/8" hole w/ RSS Assembly from 9,734' to Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-119 S-119 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/7/2004 00:00 - 02:00 2.00 DRILL P PROD1 10,004' - Control Drilled at 250 fph Maximum ROP - Drilling parameters: 600 GPM 2,250 psi, WOB 7K to 15K, 140 - 150 RPM, Tq on bottom 15K ft Ibs, Tq off bottom 13K ftllbs. 02:00 - 04:00 2.00 DRILL N RREP PROD1 - M/U headpin & circulate hole @ 630 GPM 2900 psi while removing & replacing wash pipe packing on TO. 04:00 - 12:00 8.00 DRILL P PROD1 - Directionally Drill 97/8" hole w/ RSS Assembly from 10,004' to 10,795' - Control Drilled at 250 fph Maximum ROP - ECD .5 to .6 ppg over calculated. - Drilling parameters: 600 GPM 2,280 psi, WOB 7K to 15K, 140 - 150 RPM, Tq on bottom 15K ft Ibs, Tq off bottom 13K ftllbs. - Pumped sweeps every 500' - alternating high-vis & low-vis weighted (2.0 ppg over MW). - P/U wt 170K, SIO wt 105K, Rot wt. 132K. 12:00 - 22:00 10.00 DRILL P PROD1 - Directionally Drill 97/8" hole wi RSS Assembly from 10,795' to 11,996' - Control Drilled at 250 fph Maximum ROP. - Pumped sweeps every 500' alternating high-vis & low vis weighted (2.0 ppg over MW). ECD consistently @ .8 ppg over calculated ECD while drilling from 11,902' to 11,996' wI no sweeps in hole. - Drilling parameters: 630 GPM 2650 psi, WOB 15K to 20K, 130 - 150 RPM, Tq on bottom 19K ftllbs, off bottom 16K ftllbs. - P/U wt 190K, SIO wt 105K, Rot wt. 135K. - Decision made to wiper trip. 22:00 - 00:00 2.00 DRILL P PROD1 - Pumped lo-vis weighted sweep (2.0 ppg over MW) followed by hi-vis sweep & pump surface to surface & 1 additional B/U. 10/8/2004 00:00 - 00:30 0.50 DRILL P PROD1 - Complete circulation for wiper trip @ 620 GPM 2740 psi. Sweeps brought back 10 % excess cuttings. 00:30 - 11 :00 10.50 DRILL P PROD1 - POH wI 2 stands to 11804' wi no drag - POH to 11709' - 45K drag & swabbing. - M/U TO & back ream to point above where ghost reamer has wiped, Ghost reamer 971' behind bit - Back reamed to 10955' @ 4 BPM, 650 to 750 psi @ 80 RPM, - POH from 10955' to 10108'. All stands required wiping at least once wi 25K to 35K drag before wiping. No swabbing. Could not clean up area between 10203' & 10108' by wiping. - M/U TO & back ream to shoe @ 6700'.80 RPM 600 GPM 2300 psi @ 9600' - 80 RPM 620 GPM 1900 psi @ 6700'. Circulated Ugnu cuttings & large pieces of coal while back reaming. 11 :00 - 13:00 2.00 DRILL P PROD1 - CBU @ shoe x 2 - 630 GPM 1250 psi 120 RPM 10.5K ftllbs Tq. reciprocating 30'. - Calculated ECD 10.65 ppg - actual ECD 10.75 ppg after B/U. 13:00 - 14:00 1.00 DRILL P PROD1 - Service rig & TO, 14:00 - 16:30 2.50 DRILL P PROD1 - RI H from shoe to 11809' - hole slick. 16:30 - 19:00 2.50 DRILL P PROD1 - PJSM - Pump low vis 2.0 ppg over MW sweep followed by hi-vis sweep, - Dumped & replaced 580 bbls mud. Printed: 10/18/2004 9:58:32 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-119 DRlll+COMPlETE DOYON DRilLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/812004 16:30 - 19:00 19:00 - 00:00 2.50 DRILL P 5.00 DRILL P PROD1 PROD1 10/9/2004 00:00 - 12:00 12.00 DRILL P PROD1 12:00 - 21 :30 9.50 DRILL P PROD1 21 :30 - 23:30 23:30 - 00:00 10/10/2004 00:00 - 05:30 2.00 DRILL P 0.50 DRILL P 5,50 DRILL P PROD1 PROD1 PROD1 05:30 - 07:00 1.50 DRILL P PROD1 07:00 - 07:30 0,50 DRILL P PROD1 07:30 - 09:00 1,50 DRILL P PROD1 09:00 - 14:00 5.00 DRILL P PROD1 - Wash down from 11809' to 11996' & resume drilling directionally in 9 7/8" hole wI RSS from 11996' to 12472' adding lubricants for torque, - Drilling parameters: WOB 15-20K, 630 GPM 2460 psi, 140 RPM, Tq on bottom 22K ft/lbs, Tq off bottom 18K ft/lbs. PIU wt 210K, S/O wt 100K, Rot wt 140K. - ECD running .4 to ,55 ppg over calculated. Began back reaming full stands as ECD began climbing upward. Control drill to 180 FPH to help manage ECD. - Drill directionally in 97/8" hole wI RSS from 12472' to 13512'. - Drilling parameters: WOB 13 - 15K, 625 GPM 2630 psi, 140- 160 RPM on bottom Tq 21K, off bottom Tq 19K, P/U wt 230K, S/O wt 110K, Rot wt 150K. - ECD running .4 ppg to .55 ppg over calculated. - Alternating low-vis 2.0 ppg over MW sweeps wi hi-vis sweeps every 500'. - Drill directionally in 97/8" hole wI RSS from 13512' to 14551 '. - Drilling parameters: WOB 15K to 25K, 630 GPM 3080 psi, 160 RPM on bottom Tq 23K, off bottom Tq 23K, P/U wt 250K, S/O wt 114K, Rot wt 154K. - ECD running ,4 to .7 ppg over calculated. - Alternating low-vis 2.0 ppg over MW sweeps wi hi-vis sweeps every 500', - CBU x 2 @ 630 GPM 3050 psi. - Monitor well - BID TO & lines. - Wiper trip from 14551' to 11521'. - POH from 14551' to 14075'. 50K drag @ 14075', M/U TO & back ream from 14075' to 11996'. More coal & sand @ B/U while back reaming. Back ream at 80 RPM, 630 GPM 2880 psi. - Pull 5 stands wlo pumps from 11996' to 11521'. Avg drag 20K. - RIH to 12600'. - Monitor well - RIH to 14458' wi no problems. - Fill DP & wash down from 14458' to 14551' @ 200 GPM 300 psi. - PJSM for displacement. - Spotted vacuum trucks & lowered pit volume. - Circulate during R/U @ 500 GPM 2150 psi. - Displace 870 bbls mud wi new 12.0 ppg spike fluid wI black products & Glydril. - Parameters @ start of displacement: P/U wt 230K, 8/0 wt 115K, Rot wt 160K, 80RPM Tq 21K. - Pump Rate & pressures during displacement: Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/10/2004 09:00 - 14:00 5.00 DRILL P PROD1 500 GPM 2170psi @ 500 stks, 500 GPM 1800 psi @ 3000 stks, 500 GPM 1850 psi @ 6900 stks, 500 GPM 2350 psi @ 15500 stks, 620 GPM 3180 psi @ 30000 stks, - Parameters after displacement to 10,8 ppg: P/U wt 202K, S/O wt 120K, Rot wt 156K, 80 RPM Tq 14.5K. 14:00 - 18:00 4.00 DRILL P PROD1 - Drill directionally in 97/8" hole wI RSS from 14551' to 15025' MD, - ECD .1 to .45 ppg over calculated. - Drilling parameters: WOS 15 to 20K, 625 GPM 3100 psi, 160 RPM, off bottom Tq 18K, on bottom Tq 21 K, P/U wt 215K, S/O wt 120K, Rot wt 159K. 18:00 - 00:00 6.00 DRILL P PROD1 - Drill directionally in 9 7/8" hole from 15025' to 15406' MD. · ECD increased up to .7 to .8 ppg over calculated ECD while drilling from 15212' to 15307'. Circulated off bottom, back ream stands x 2 & control drill to 110 FPH to reduce ECD's, - Drilling parameters: WOB 10K to 15K, 625 GPM 3370 psi, 160 RPM, off bottom TO 18K, on bottom TO 21K, P/U wt 215K, SIO wt 122K, Rot wt 157K. 10/11/2004 00:00 - 12:00 12,00 DRILL P PROD1 - Drill directionally in 9 718" hole wI RSS from 15406' to 15973'. - ECD .5 to .65 ppg over calculated decreasing to .2 to ,4 ppg. - Maintaining ROP to 110 FPH, for ECD. - Alternating lo-vis 2.0 ppg over MW wI high vis sweeps every 500'. · Drilling parameters: WOS 10 -15K, 625 GPM 3410 psi, 160 RPM, on bottom Tq 22K, off bottom Tq 19K, P/U wt 225K, SIO wt 123K, Rot wt 163K, 12:00 - 19:00 7.00 DRILL P PROD1 - Drill directionally in 9 7/8" hole wI RSS from 15973' to 16350'. · ECD .2 to .4 ppg over calculated ECD. - Drilling parameters: WOS 15 - 20K, 625 GPM 3600 psi, 160 RPM, on bottom Tq 25K, off bottom Tq 22K, P/U wt 250K, SIO wt 135K, Rot wt 176K, 19:00 - 20:00 1.00 DRILL P PROD1 - POH wI 4 stds DP & rack back. P/U 12 singles from pipeshed & RIH. 20:00 - 23:00 3.00 DRILL P PROD1 - Drill directionally in 97/8" hole wi RSS from 16350' to TO @ 16536' - ECD .3 to .4 ppg over calculated ECD. - Drilling parametrs: WOS 15 - 20K, 625 GPM 3670 psi, 160 RPM, on bottom Tq 26K, off bottom Tq 22K, P/U wt 255K, S/O wt 135K, Rot wt 178K, 23:00 - 00:00 1.00 DRILL P PROD1 - Circulate & condition @ 650 GPM 3850 psi, 80 RPM & reciprocating full stand, 10/12/2004 00:00 - 02:00 2.00 DRILL P PROD1 Circulated to condition mud & clean hole @ 650 GPM 3850 psi, 80 RPM & reciprocated full stand, Total of B/U x 2 02:00 - 05:30 3.50 DRILL P PROD1 Performed Wiper Trip from 16,536' to 12,041' - Pulled Upper Ghost reamer inside 10 3/4" casing, 1 OK Avg Drag During Wiper Trip. 05:30 - 08:30 3,00 DRILL P PROD1 Monitored well· RIH to 16,536'. Filled DP at 14,900' and 16,500'. 08:30 - 12:00 3.50 DRILL P PROD1 Pumped Lo vis weighted sweep followed by Hi vis sweep. Printed: 10/18/2004 9:58:32 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-119 S-11 9 DRlll+COMPlETE DOYON DRilLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/12/2004 08:30 - 12:00 3.50 DRILL P PROD1 Circulated 3 x Bottoms Up. Pump Rate 650 gpm, 3,810 psi, 80 RPM. 12:00 - 12:30 0.50 DRILL P PROD1 Monitored well. Pumped dry job. Blew down top drive. 12:30 - 00:00 11,50 DRILL P PROD1 POOH L /05" DP from 16,536' to 7,950'. Took Up and Down Weights every 500'. 16,500' - 275K Up Weight 140K Down Weight. 7,950' - 150K Up Weight 90K Down Weight 10/13/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Continued to POOH LID 5" DP from 7,950' to 6,780'. Continue to take Up and Down weights every 500', 01 :00 - 04:30 3.50 DRILL P PROD1 Attempted MAD pass to tie in logs. MWD correlated logs, discovered MAD pass 93' too high. Pipe count verified MWD findings. Ran back in hole to 6,763'. Performed MAD pass from 6,763' to 6,528'. 500 GPM 1720 PSI. 04:30 - 06:00 1.50 DRILL P PROD1 CBU bottoms up. Pumped and circulated around EP mud lube. 650 GPM 2500 PSI 80 RPM 7K TQ. 06:00 - 06:30 0.50 DRILL P PROD1 Monitor well. Pump dry job. Blow down TDS. 06:30 - 07:30 1.00 DRILL P PROD1 Slip and cut drill line. 07:30 - 08:00 0.50 DRILL P PROD1 Clean and service rig. 08:00 - 12:00 4,00 DRILL P PROD1 Continued POOH LID 5" DP from 6,528' to 3,818'. Continued taking Up and Down weights every 500', 12:00 - 12:30 0.50 DRILL P PROD1 Clean and service rig. 12:30 - 16:30 4.00 DRILL P PROD1 Continue LD drill pipe from 3,818' to BHA. 16:30 - 19:00 2.50 DRILL P PROD1 PJSM concerning source recovery and securing. LD BHA #4. 19:00 - 20:30 1.50 CASE P PROD1 Clear floor and pull wear bushing. Make dummy run with 7" mandrel hanger. Landed hanger and marked landing joint at 4.65' stickup.. Remove bails. MU casing fill up tool. Install long bails. 20:30 - 21 :30 1,00 CASE P PROD1 Rig up 7" casing running equipment. Test slips and elevators. 21 :30 - 22:00 0.50 CASÈ P PROD1 PJSM on running 7" casing. 22:00 - 23:00 1.00 CASE P PROD1 PU and MU shoe track. Fill pipe and check floats holding, OK, 23:00 - 00:00 1.00 CASE P PROD1 Run 7",26#, L-80, BTC-M casing as per running program to 900'. Running speed 30 seconds per joint while in casing. 10/14/2004 00:00 - 03:00 3.00 CASE P PROD1 Continue to run 7", 26#, L-80, BTC-M casing as per running program from 900' to 3,300'. Running speed 30 seconds per joint while in casing. 03:00 - 03:30 0,50 CASE P PROD1 Break circulation with casing fill up tool. 250 GPM. 100K Up Weight 85K Down Weight. 03:30 - 08:00 4.50 CASE P PROD1 Continue to run 7", 26#, L-80, BTC-M casing as per running program from 3,300' 'to 6,692', Running speed 30 seconds per joint while in casing. 08:00 - 09:00 1,00 CASE P PROD1 Circulate bottoms up at 250 GPM 490 PSI. 140K Up Weight 98K Down Weight. 09:00 - 00:00 15.00 CASE P PROD1 Continue to run 7", 26#, L-80, BTC-M casing as per running program from 6,692" , to 16,198', Average make up torque 9,500 ft/lbs. Running speed 60 seconds per joint while in open hole. Wash down every 20th joint staging up pump slowly to 4 BPM. Running rate 5-7 minutes while washing down. Washing data: 7,520' 3.8 bpm 310 psi 155K Up 100K Down 8,345' 3,8 bpm 360 psi 168K Up 98K Down 8,756' 3.8 bpm 380 psi 183K Up 100K Down 9.170' 3.5 bpm 400 psi 185K Up 95K Down Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/14/2004 09:00 - 00:00 15.00 CASE P PROD1 9,992' 4 bpm 460 psi 198K Up 95K Down 10,813' 4bpm 510psi 215KUp 97KDown 11,634' 4 bpm 550 psi 230K Up 95K Down Washed down 7 consecutive joints from 12,253' to 12,543'. 6 bpm 760 psi 251 K Up 102K Down 13,283' 4 bpm 650 psi 275K Up 105K Down 14,108' 4 bpm 660 psi 275K Up 105K Down 14,929' 4 bpm 810 psi 270K Up 100K Down 15,747' 4 bpm 820 psi 305K Up 110K Down At 16,198' 325K Up Weight 110K Down Weight 01 :00 - 02:00 1.00 CEMT P Zero losses during RIH and circulations PROD1 Continue to run 7", 26#, L-80, BTC-M casing as per running program from 16,198' to 16,483'. Running speed 60 seconds per joint while in open hole. PROD1 Make up landing joint, stab fill up tool and stage pumps up to 5 BPM at 800 psi. 330K Up Weight 120K Down Weight. After working pipe for 20 minutes recriprocating conditions began to deteriorate, pick up weight began to exceed 375K and slack off weight approached 80K. Landed casing on mandrel hanger. Weight on hanger, 128K. Casing shoe set at 16,513.9'. PROD1 Rig down casing fill up tool. Rig up cement head and circulating lines. BP Co Rep and Doyon Tourpusher loaded plugs. PROD1 Stage pumps up to 6 BPM (250 GPM) at 850 psi. Circ and condition hole prior to cement job. After first bottoms up, increase pump rate slowly to 9 BPM, 1320 psi. Prepare for cement job while circulating. Held PJSM wlDowell crew, Rig Crew, Truck drivers. PROD1 Switched over to Dowell. Pumped 10 bbls of water at 6 bpm, 1,000 psi. Shut in cement manifold and tested lines to 4,000 psi. OK. Flush water out of lines. Pumped 30 bbls Chem Wash at 7.75 bpm, 925 psi. Pump 50 bbls Mud Push at 7.5 bpm, 950 psi. Dropped bottom plug, pumped 100 bbls (512 sks) 15.8 ppg Premium Class G cement wi 3% Expander, ,07% Retarder, .3% Dispersant, .2 gps Antifoam and 2 gps GasBlok. Pumped cement at the following rates: Pumped Rate Pressure 10,0 bbls 7.50 bpm 1150 psi 25.0 bbls 7,50 bpm 1050 psi 50.0 bbls 7.50 bpm 900 psi 75.0 bbls 7.50 bpm 800 psi 100,0 bbls 4,00 bpm 235 psi 10/15/2004 00:00 - 00:30 0.50 CASE P 00:30 - 01 :00 0.50 CASE P 02:00 - 08:30 6.50 CEMT P 08:30 - 11 :30 3.00 CEMT P Dropped top plug, pumped 10 bbls water at 8.0 bpm, 280 psi. Pumped 100.0 bbls 200,0 bbls 300,0 bbls 400.0 bbls 500,0 bbls Rate 8.00 bpm 7,50 bpm 8.00 bpm 8.30 bpm 8,30 bpm Pressure 850 psi 900 psi 1 070 psi 1140 psi 1140 psi Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-119 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/15/2004 08:30 - 11 :30 3.00 CEMT P PROD1 550.0 bbls 600.0 bbls 618.0 bbls 632.0 bbls 8.30 bpm 8.30 bpm 3.00 bpm 3.00 bpm 1250 psi 1600 psi 1265 psi 1300 psi Did not bump plug. Checked floats, holding OK. Cement in place @ 1130 hrs. 11 :30 - 14:00 2.50 CEMT P PROD1 14:00 - 15:00 1.00 WHSUR P PROD1 15:00 - 17:00 2.00 EVAL P PROD1 17:00 - 19:30 2.50 EV AL P PROD1 19:30 - 20:30 1.00 EVAL P PROD1 20:30 - 21 :00 0.50 EVAL P PROD1 21 :00 - 00:00 3.00 RUNCOMP RUNCMP 10/16/2004 00:00 - 01 :00 1.00 RUNCOMP Rig down cement lines and head. Drain stack. Rig down long bails and casing elevator, Install short bails and drill pipe elevator. Install 7" pack off and test to 5,000 psi, OK. Spot slick line unit. PJSM. Rig up slick line and lubricator. RIH with sinker bars. Tag hard obstruction at 16,370'. Pick up and tag X3 to verify, OK. POOH with slick line assembly. Rig down slick line. Rig up to run 4.5" completion string. Change over flowline. Rig up casing test equipment. Waited on cement to reach 2,000 psi compressive strength prior to casing test, did not bump plug on cement job, RUNCMP Held PJSM - Tested 7" Casing to 4,000 psi. Recorded On Chart f/30 Minutes (Test Good). Held PJSM for Running Completion During Casing Test. RID Test Equipment. RUNCMP M I U 4-1/2" Tail Pipe Assembly: XN Nipple WLEG Assembly- X Nipple Assembly - 7" x 4-1/2" Premier Packer Assembly- CMD Sliding Sleeve Assembly. BakerLoc'd All Connections Below Packer, RUNCMP M I U and RIH w/4 1/2" 12.6# L-80 TC II Tubing to 6,996', PI U Joints wi Compensator, Torque Turned All Connections. M I U Torque 3,700 It Ilbs. 95K Up Weight 65K Down Weight. RUNCMP Continue to RIH w/4 1/2" 12.6# L-80 TC II Tubing to 14,915'. P I U Joints wI Compensator, Torque Turned All Connections, M I U Torque 3,700 It I Ibs. 165K Up Weight 78K Down Weight. 01 :00 - 02:00 1.00 RUNCOMP 02:00 - 12:00 10.00 RUNCOMP 12:00 - 00:00 12.00 RUNCOMP Performed Annular Injectivity I LOT on 7" x 10-3/4" Annulus wi 10.8 ppg Mud. Tested Lines to 3,000 psi, OK, Strokes Pressure 16 190 psi 32 280 psi 48 350 psi 64 400 psi 80 430 psi 96 460 psi Hold time in minutes Pressure o 390 psi 1 330 psi 2 310 psi 3 290 psi 4 290 psi 5 290 psi Pumped 2.8 bbls at 10 spm. Leak off pressure 240 psi. EMW=12,15. Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-119 S-11 9 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: Freeze protected 7" x 10-3/4" Annulus by Pumping 120 bbls Dead Crude at 3 bpm, 700 psi. Continue to RIH wI 4-1/2" 12.6# L-80 TC II Tubing to 15,686', P I U Joints wI Compensator, Torque Turned All Connections. M I U Torque 3,700 ft I Ibs. 175K Up Weight 78K Down Weight. M I U Tubing Hanger and Landing Joint. RIH Landed Hanger in Wellhead and RILDS. RID Ttubing Handling Equipment. R I U to Displace IA Directly from Truck. Held PJSM with All Crew and Truck Drivers. Pumped 75 bbls Clean Seawater, Followed by 215 bbls of Corrosion Inhibited Seawater Down 4-1/2" x 7" Annulus. Pump Rate 3 bpm, 230 psi Dropped Ball And Rod - Attempted to test surface lines to 4,000 psi. Discovered wash out in surface line. Repairing same Pressure Up On The Tubing To 4200 Psi To Set The Packer- Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test - Bleed The Pressure To 2500 Psi. - Pressure Annulus To 4000 Psi For 30 Mininutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Pressure To Shear The DCK Valve. Pumped both ways to verify valve sheared. Pump down tubing 1 bpm at 1300 psi, down annulus 1 bpm at 200 psi and 3 bpm at 850 psi. Valve not fully sheared. Blow down and rig down surface lines. LD landing joint. Install TWC. NO BOP's. Nipple Up Tubing Head Adapter And Production Tree. Test Tubing Head Adapter And Tree To 5,000 Psi. (Good Test). Rig Up DSM Lubricator And Pull Two Way Check Valve. Rig Down DSM. PJSM. Rig up slick line, Wire line RIH with 4.5" GS & slip stop style catcher. At 2,019' could make no further progress due to high angle. POOH to change wire line BHA. Wire line made up and RIH with catcher sub to set in profile nipple. At 7,000' RIH slowed to 65' per minute. At 23:00 hours, discussions between rig team and Anchorage lead to decision to discontinue catcher running operation, pull wire line to surface and run in and latchlretrieve DCK valve. RUNCMP POOH with wire line. RUNCMP Wirelline made up DCK valve latch and RIH. Tagged and latched DCK at 5,518' SLM. Jarred free at 01 :40 hrs. Wireline POOH, DCK returned to surface. PJSM to rig down wireline held during trip out. Rig down wireline. PJSM - Rig Up Circulating Lines And Equipment. Test Little Red Services Surface Lines And Equipment At 1,000 Psi. (Test Good). Pump 120 Barrels Of Diesel At 3 BPM With 500 Psi. U-Tube Diesel From Annulus To Tubing. Set BPV and test to 1,000 psi, Good Test. Secure well. 10/16/2004 12:00 - 00:00 12.00 RUNCOIIiP RUNCMP 10/17/2004 00:00 - 01 :00 1.00 RUNCOIIiP RUNCMP 01 :00 - 01 :30 0.50 RUNCOIIiP RUNCMP 01 :30 - 02:30 1.00 RUNCOIIiP RUNCMP 02:30 - 04:30 2.00 RUNCOMP RUNCMP 04:30 - 05:00 0.50 RUNCOIIiP RUNCMP 05:00 - 06:00 1.00 RUNCOfIII\J RREP RUNCMP 06:00 - 08:00 2.00 RUNCOMP RUNCMP 08:00 - 09:00 1.00 RUNCOMP RUNCMP 09:00 - 14:00 5.00 BOPSUF P POST 14:00 - 16:00 2.00 WHSUR P POST 16:00 - 17:00 1.00 WHSUR P POST 17:00 - 18:30 1.50 DHEQP P RUNCMP 18:30 - 21 :00 2.50 DHEQP P RUNCMP 21 :00 - 23:30 2,50 DHEQP P RUNCMP 23:30 - 00:00 10/18/2004 00:00 - 02:00 0.50 DHEQP P 2.00 DHEQP P 02:00 - 03:00 1.00 DHEQP P RUNCMP 03:00 - 03:30 0,50 WHSUR P POST 03:30 - 05:00 1.50 WHSUR P POST 05:00 - 06:00 1,00 RIGD P POST Printed: 10/18/2004 9:58:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-11 9 S-11 9 DRILL+COMPLETE DOYON DRILLING INC, DOYON 16 Start: 9/1/2004 Rig Release: Rig Number: 16 Spud Date: 9/27/2004 End: 10/18/2004 05:00 - 06:00 1.00 RIGD P POST Rig Released at 06:00 Hours. Printed: 10/18/2004 9:58:32 AM . . Well: Field: API: Permit: S-119 Prudhoe Bay Unit 50-029-23222-00-00 204-162 Accept: Spud: Release: 09/25/04 09/27/04 1 0/18104 16 POST RIG WORK 11/07/04 LOCATE AND PULL BALL AND ROD @ 15,556' SLM. ATTEMPT TO PULL STA. 1 DGLV. 11/08/04 PULL 1" BK, DGLV FROM STA.#1 @ 15,480' SLM. PULL 1" BK DGLV FROM STA.3 @ 12,896' SLM. 11/09/04 PULL 1" BK, DGLV FROM STAA @ 7705' (SLM). SET 1" BK, DGLV. IN STA. @ 5488' (SLM). SET 1" BK, {DOME GLV 16/64 PORT. 1990 TRO} IN STATION #4 @ 7703' (SLM}. SET 1" BK, {DOME GLV 16/64 PORT. 1983 TRO} IN STATION #3 @ 12,885 (SLM). 11/10/04 PULL RHC @ 15,656' SLM. D&T TD WI 3,625 TS & S, BAILER @ 16,262' SLM. PBTD=16,429' (TAG 167' ABOVE PBTD). 12/23/04 BEGIN KICKING OFF WELL WI AL @ 1 MM/D. PUMP 1.25" BALL THROUGH CT. PERFORM WEEKLY BOP TEST, MU 2 3/8" BAKER MHA. MU/RIH WI PDS MEM GRICCL IN 2.2" CARRIER WI 3,5" NZL DRIFT. TAG TD @ 16351', LOG FROM TD TO 15400'. PUH. PIPE PART AT SURFACE WHILE POOH. MU COIL TO COIL CONNECTOR, RECOVER ALL COIL FROM THE WELL. REMOVE PDS TOOLS. 12/26/04 PUMP 1.25" BALL. MU BAKER 2 3/8" PAC MHA. MU/RIH WI PDS GRICCL IN CARRIER WI 3.66" JSN DRIFT. TAG TD @ 16355', LOG FROM TD TO 15400'. PAINT FLAG @ 15800'. POOH. PHASE III CONDITIONS ANNOUNCED WHILE IN THE WELL. 12/27/04 SHOVEL OUT UNIT. MUIRIH WI 25' OF 3-3/8" POWERJETS, 6 SPF. TIE INTO FLAG, PERF FROM 15857'- 15882'. POOH, RIG DOWN IN PROGRESS, 12/28/04 OBTAINED SBHP AS PER PROGRAM, STOPS @ 15,830' & 15,680' MD, ,. S-119 Survey Report Schlumberger Report Date: 12-0ct-04 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 318.950° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: S-PADI S-119 (slot 13) TVD Reference Datum: KB Well: S-119 TVD Reference Elevation: 61.90 ft relative to MSL Borehole: S-119 Sea Bed I Ground Level Elevation: 36.00 ft relative to MSL UWI/API#: 500292322200 Magnetic Declination: 24.958° Survey Name I Date: S-119 1 September 12, 2004 Total Field Strength: 57589.426 nT Tort I AHD I DDII ERD ratio: 189.869° 114194.76 ft 16.789/1.961 Magnetic Dip: 80.867" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 26, 2004 . Location LatlLong: N 70.35592362, W 149.03413561 Magnetic Declination Model: BGGM 2004 Location Grid N/E Y/X: N 5980699.940 ftUS, E 618930.010 ftUS North Reference: True North Grid Convergence Angle: +0.90965999° Total Corr Mag North .) True North: +24.958° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head I Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (It) (deg/100 It) (ltUS) (ltUS) RTE 0.00 0.00 302.00 -61.90 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980699.94 618930.01 N 70.35592362 W 149.03413561 First Gyro Station 47.10 0.01 358.43 -14.80 47.10 0.00 0.00 0.00 0.00 0.00 0.02 5980699.94 618930.01 N 70.35592363 W 149.03413561 99.90 0.12 302.08 38.00 99.90 0.06 0.06 0.06 0.04 -0.05 0.22 5980699.98 618929.96 N 70.35592372 W 149.03413600 164.40 0.75 302.49 102.50 164.40 0.53 0.55 0.55 0.30 -0.46 0.98 5980700.23 618929.54 N 70.35592444 W 149.03413935 249.50 1.01 288.05 187.59 249.49 1.71 1.85 1.84 0.83 -1.64 0.40 5980700.75 618928.35 N 70.35592589 W 149.03414896 339.00 2.31 284.15 277.05 338.95 3.86 4.44 4.41 1.52 -4.14 1.46 5980701.39 618925.84 N 70.35592776 W 149.03416925 430.40 4.93 291.46 368.26 430.16 8.86 10.21 10.17 3.41 -9.58 2.90 5980703.19 618920.37 N 70.35593292 W 149.03421344 Last Gyro Station 529.80 8.45 294.56 466.97 528.87 19.31 21.78 21.73 8.00 -20.21 3.56 5980707.62 618909.68 N 70.35594549 W 149.03429968 First MWD+IFR+MS 561.21 9.63 292.90 497.99 559.89 23.77 26.72 26.67 9.99 -24.72 3.85 5980709.53 618905.13 N 70.35595090 W 149.03433638 657.10 13.98 296.05 591.83 653.73 41.65 46.33 46.26 18.20 -42.53 4.58 5980717.46 618887.20 N 70.35597333 W 149.03448095 745.14 17.81 296.59 676.48 738.38 63.91 70.43 70.34 28.90 -64.13 4.35 5980727.81 618865.43 N 70.35600257 W 149.0Jllr 840.22 21.73 296.32 765.94 827.84 93.61 102.59 1 02.48 43.22 -92.92 4.12 5980741.67 618836.42 N 70.35604168 W 149.0 4 934.47 25.65 299.13 852.24 914.14 128.92 140.44 140.29 60.89 -126.39 4.33 5980758.81 618802.68 N 70.35608996 W 149.03 194 1030.23 29.58 297.11 937.07 998.97 170.38 184.82 184.64 81.76 -165.55 4.22 5980779.05 618763.20 N 70.35614697 W 149.03547993 1125.15 31.67 295.95 1018.75 1080.65 215.07 233.17 232.99 103.34 -208.82 2.29 5980799.94 618719.60 N 70.35620593 W 149.03583126 1218.57 34.77 293.48 1096.90 1158.80 261.70 284.34 284.14 124.69 -255.31 3.62 5980820.55 618672.77 N 70.35626425 W 149.03620883 1314.99 35.21 293.90 1175.89 1237.79 311.71 339.63 339.39 146.91 -305.94 0.52 5980841.96 618621.80 N 70.35632494 W 149.03661997 1406.01 37.47 293.08 1249.20 1311.10 360.40 393.56 393.29 168.39 -355.41 2.54 5980862.66 618572.00 N 70.35638364 W 149.03702166 1499.97 39.07 292.63 1322.97 1384.87 412.66 451.75 451.43 190.99 -409.04 1.73 5980884.40 618518.03 N 70.35644537 W 149.03745714 1594.80 42.74 291.51 1394.63 1456.53 468.02 513.84 513.44 214.30 -466.58 3.95 5980906.79 618460.13 N 70.35650903 W 149.03792441 1685.29 45.73 293.52 1459.46 1521.36 524.55 576.95 576.51 238.49 -524.87 3.65 5980930.05 618401.47 N 70.35657511 W 149.03839777 1780.61 49.18 295.68 1523.91 1585.81 588.53 647.16 646.72 267.75 -588.69 3.99 5980958.29 618337.19 N 70.35665503 W 149.03891604 1873.97 53.18 296.51 1582.42 1644.32 655.54 719.89 719.42 299.76 -653.99 4.34 5980989.25 618271.40 N 70.35674244 W 149.03944635 1968.78 56.53 300.11 1637.00 1698.90 728.08 797.39 796.76 336.55 -722.19 4.70 5981024.95 618202.63 N 70.35684295 W 149.04000021 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-119 (slot 13)\S-119\S-119\S-119 Generated 10/22/20044:20 PM Page 1 of 5 II' Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DlS I Northing Easting latitude longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (ftUS) (ftUS) 2063.31 59.33 304.39 1687.20 1749.10 804.79 877.48 876.24 379.31 -789.88 4.85 5981066.63 618134.27 N 70.35695976 W 149.04054993 2158.35 60.85 310.15 1734.62 1796.52 885.41 959.84 957.02 429.19 -855.38 5.49 5981115.46 618068.00 N 70.35709600 W 149.04108184 2252.14 62.66 315.70 1779.03 1840.93 967.53 1042.45 1036.53 485.45 -915.82 5.56 5981170.75 618006.68 N 70.35724968 W 149.04157271 2348.42 65.05 318.09 1821.46 1883.36 1053.89 1128.87 1118.60 548.56 -974.86 3.34 5981232.91 617946.65 N 70.35742205 W 149.04205219 2443.55 66.56 319.38 1860.45 1922.35 1140.66 1215.64 1200.80 613.78 -1032.08 2.01 5981297.21 617888.40 N 70.35760022 W 149.04251696 2537.14 69.87 320.52 1895.18 1957.08 1227.54 1302.53 1283.17 680.30 -1087.98 3.71 5981362.83 617831.46 N 70.35778193 W 149.04297102 2628.65 69.09 321.37 1927.26 1989.16 1313.19 1388.23 1364.52 746.85 -1141.98 1.22 5981428.51 617776.41 N 70.35796372 W 149.04340962 2721.93 68.97 321.92 1960.64 2022.54 1400.20 1475.33 1447.40 815.16 -1196.03 0.57 5981495.94 617721.29 N 70.35815029 W 149.04384865 2820.07 68.71 322.07 1996.07 2057.97 1491.59 1566.86 1534.84 887.27 -1252.39 0.30 5981567.14 617663.80 N 70.35834728 W 149.04430639 2914.53 68.99 321.86 2030.15 2092.05 1579.56 1654.95 1619.44 956.66 -1306.67 0.36 5981635.66 617608.43 N 70.35853682 W 149.04474731 3009.91 69.62 321.88 2063.86 2125.76 1668.67 1744.18 1705.52 1026.85 -1361.76 0.66 5981704.95 617552.24 N 70.35872853 W 149.04.2 3104.21 69.39 320.83 2096.87 2158.77 1756.92 1832.51 1791.23 1095.83 -1416.92 1.07 5981773.05 617496.00 N 70.35891697 W 149.04 1 3199.57 69.17 320.4 7 2130.61 2192.51 1846.08 1921.70 1878.27 1164.81 -1473.47 0.42 5981841.11 617438.36 N 70.35910536 W 149.04610230 3293.85 69.21 321.12 2164.11 2226.01 1934.16 2009.83 1964.41 1233.10 -1529.18 0.65 5981908.50 617381.58 N 70.35929190 W 149.04655482 3388.41 69.33 321.62 2197.58 2259.48 2022.52 2098.27 2050.85 1302.18 -1584.39 0.51 5981976.70 617325.29 N 70.35948060 W 149.04700333 3482.74 69.70 321.67 2230.59 2292.49 2110.79 2186.63 2137.29 1371.48 -1639.22 0.40 5982045.10 617269.36 N 70.35966988 W 149.04744879 3577.05 69.58 320.94 2263.40 2325.30 2199.13 2275.05 2224.03 1440.49 -1694.50 0.74 5982113.22 617213.00 N 70.35985837 W 149.04789785 3671.40 69.03 320.99 2296.74 2358.64 2287.34 2363.31 2310.85 1509.04 -1750.08 0.59 5982180.88 617156.34 N 70.36004563 W 149.04834944 3766.41 69.15 321.97 2330.65 2392.55 2376.00 2452.07 2398.11 1578.48 -1805.36 0.97 5982249.43 617099.98 N 70.36023529 W 149.04879849 3861.76 69.48 321.97 2364.33 2426.23 2465.08 2541.27 2485.79 1648.75 -1860.31 0.35 5982318.81 617043.92 N 70.36042721 W 149.04924498 3955.85 69.37 323.22 2397.40 2459.30 2552.99 2629.36 2572.30 1718.72 -1913.82 1.25 5982387.91 616989.31 N 70.36061833 W 149.04967971 4049.54 68.92 322.75 2430.76 2492.66 2640.32 2716.91 2658.27 1788.63 -1966.53 0.67 5982456.97 616935.50 N 70.36080928 W 149.05010795 4144.72 69.42 322.98 2464.60 2526.50 2729.07 2805.87 2745.77 1859.55 -2020.23 0.57 5982527.02 616880.69 N 70.36100298 W 149.05054429 4238.79 70.09 322.94 2497.15 2559.05 2817.12 2894.13 2832.64 1930.00 -2073.40 0.71 5982596.61 616826.42 N 70.36119540 W 149.05097626 4333.27 70.53 322.19 2528.99 2590.89 2905.89 2983.08 2920.38 2000.63 -2127.47 0.88 5982666.37 616771.23 N 70.36138832 W 149.05141561 4427.58 70.14 322.55 2560.72 2622.62 2994.54 3071.89 3008.10 2070.96 -2181.69 0.55 5982735.83 616715.90 N 70.36158043 W 149.05185620 4522.56 70.14 321.77 2592.99 2654.89 3083.73 3161.22 3096.44 2141.51 -2236.49 0.77 5982805.49 616660.00 N 70.36177311 W 149.05230148 4617.40 68.78 321.84 2626.27 2688.17 3172.43 3250.03 3184.40 2211.30 -2291.41 1.44 5982874.40 616603.98 N 70.36196374 W 149.05274770 4712.04 69.19 322.37 2660.21 2722.11 3260.64 3338.38 3271.88 2281.02 -2345.67 0.68 5982943.24 616548.63 N 70.36215415 W 149.0.2 4806.78 69.58 322.33 2693.56 2755.46 3349.16 3427.05 3359.68 2351.23 -2399.83 0.41 5983012.57 616493.36 N 70.36234591 W 149.0 7 4899.49 68.78 322.60 2726.51 2788.41 3435.65 3513.70 3445.51 2419.94 -2452.63 0.90 5983080.44 616439.48 N 70.36253359 W 149.05405779 4994.93 69.25 323.39 2760.69 2822.59 3524.54 3602.81 3533.69 2491.11 -2506.26 0.92 5983150.73 616384.73 N 70.36272794 W 149.05449362 5090.69 69.95 323.28 2794.07 2855.97 3614.03 3692.57 3622.48 2563.10 -2559.86 0.74 5983221.86 616330.01 N 70.36292458 W 149.05492917 5185.29 69.70 323.95 2826.70 2888.60 3702.53 3781.36 3710.30 2634.58 -2612.53 0.72 5983292.49 616276.21 N 70.36311981 W 149.05535724 5277.85 70.15 323.03 2858.47 2920.37 3789.19 3868.30 3796.36 2704.46 -2664.26 1.05 5983361.53 616223.39 N 70.36331065 W 149.05577760 5372.44 69.55 321.85 2891.06 2952.96 3877.83 3957.10 3884.51 2774.85 -2718.38 1.33 5983431.05 616168.15 N 70.36350291 W 149.05621750 5466.94 68.62 321.37 2924.79 2986.69 3966.00 4045.37 3972.31 2844.04 -2773.20 1.09 5983499.35 616112.25 N 70.36369187 W 149.05666300 5560.57 68.90 321.09 2958.71 3020.61 4053.21 4132.64 4059.18 2912.08 -2827.85 0.41 5983566.51 616056.53 N 70.36387769 W 149.05710713 5655.18 70.00 320.90 2991.92 3053.82 4141.74 4221.23 4147.42 2980.92 -2883.61 1.18 5983634.45 615999.69 N 70.36406570 W 149.05756027 5750.29 70.12 319.11 3024.36 3086.26 4231.13 4310.64 4236.60 3049.41 -2941.07 1.77 5983702.02 615941.16 N 70.36425276 W 149.05802728 5844.92 69.95 318.18 3056.67 3118.57 4320.07 4399.58 4325.45 3116.18 -2999.83 0.94 5983767.83 615881.34 N 70.36443508 W 149.05850487 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Sld( do31 rt-546 ) S-119 (slot 13)\S-119\S-119\S-119 Generated 10/22/2004 4:20 PM Page 2 of 5 Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (ftUS) (ftUS) 5941.06 69.72 317.85 3089.81 3151.71 4410.30 4489.83 4415.65 3183.26 -3060.20 0.40 5983833.94 615819.92 N 70.36461828 W 149.05899551 6034.33 69.98 317.59 3121.94 3183.84 4497.84 4577.39 4503.18 3248.04 -3119.11 0.38 5983897.78 615760.00 N 70.36479519 W 149.05947426 6130.20 69.20 317.02 3155.38 3217.28 4587.65 4667.24 4593.01 3314.08 -3180.04 0.99 5983962.84 615698.04 N 70.36497553 W 149.05996944 6224.44 68.54 317.27 3189.35 3251.25 4675.51 4755.14 4680.90 3378.52 -3239.82 0.74 5984026.31 615637.24 N 70.36515151 W 149.06045536 6319.12 69.82 318.05 3223.00 3284.90 4763.99 4843.64 4769.37 3443.93 -3299.43 1.56 5984090.77 615576.61 N 70.36533014 W 149.06093979 6413.52 69.66 317.96 3255.69 3317.59 4852.53 4932.20 4857.89 3509.75 -3358.68 0.19 5984155.63 615516.33 N 70.36550988 W 149.06142139 6509.37 70.32 318.08 3288.49 3350.39 4942.59 5022.26 4947.91 3576.70 -3418.92 0.70 5984221.61 615455.04 N 70.36569271 W 149.06191103 6603.32 70.03 317 .48 3320.35 3382.25 5030.95 5110.64 5036.26 3642.16 -3478.31 0.68 5984286.11 615394.62 N 70.36587144 W 149.06239376 6631.61 69.81 317.09 3330.06 3391.96 5057.51 5137.21 5062.83 3661.68 -3496.33 1.51 5984305.34 615376.29 N 70.36592475 W 149.06254026 6765.19 68.40 315.63 3377.71 3439.61 5182.17 5262.00 5187.62 3751.99 -3582.45 1.47 5984394.27 615288.76 N 70.36617137 W 149.06324021 6855.98 68.49 315.32 3411.06 3472.96 5266.45 5346.44 5272.05 3812.19 -3641.66 0.33 5984453.51 615228.61 N 70.36633575 W 149.06_ 6949.56 68.93 316.51 3445.04 3506.94 5353.52 5433.64 5359.24 3874.82 -3702.32 1.27 5984515.17 615166.97 N 70.36650677 W 149.06 7044.93 68.89 315.81 3479.36 3541.26 5442.40 5522.62 5448.22 3939.00 -3763.95 0.69 5984578.36 615104.33 N 70.36668202 W 149.064 6 7139.13 68.82 316.15 3513.34 3575.24 5530.14 5610.47 5536.07 4002.18 -3825.00 0.34 5984640.55 615042.28 N 70.36685454 W 149.06521184 7233.06 68.49 316.92 3547.53 3609.43 5617.55 5697.96 5623.56 4065.68 -3885.19 0.84 5984703.08 614981.11 N 70.36702792 W 149.06570107 7329.71 68.40 317.38 3583.04 3644.94 5707.39 5787.85 5713.44 4131.58 -3946.32 0.45 5984768.00 614918.94 N 70.36720787 W 149.06619803 7423.50 68.39 317.46 3617.57 3679.47 5794.56 5875.05 5800.62 4195.79 -4005.32 0.08 5984831.26 614858.93 N 70.36738320 W 149.06667767 7518.51 68.10 318.00 3652.79 3714.69 5882.78 5963.30 5888.84 4261.09 -4064.68 0.61 5984895.60 614798.55 N 70.36756150 W 149.06716020 7610.11 69.04 318.08 3686.25 3748.15 5968.04 6048.56 5974.07 4324.49 -4121.69 1.03 5984958.08 614740.55 N 70.36773463 W 149.06762367 7703.75 69.65 318.54 3719.28 3781.18 6055.65 6136.18 6061.64 4389.92 -4179.96 0.80 5985022.58 614681.25 N 70.36791329 W 149.06809745 7798.28 69.49 318.47 3752.28 3814.18 6144.24 6224.77 6150.17 4456.27 -4238.65 0.18 5985087.98 614621.51 N 70.36809447 W 149.06857462 7888.44 69.90 319.01 3783.57 3845.47 6228.79 6309.32 6234.66 4519.84 -4294.42 0.72 5985150.65 614564.75 N 70.36826803 W 149.06902799 7980.68 70.40 319.23 3814.89 3876.79 6315.55 6396.08 6321.32 4585.43 -4351.20 0.59 5985215.33 614506.94 N 70.36844714 W 149.06948965 8074.61 70.06 318.96 3846.66 3908.56 6403.94 6484.48 6409.63 4652.24 -4409.08 0.45 5985281.20 614448.01 N 70.36862956 W 149.06996026 8167.95 69.53 319.14 3878.90 3940.80 6491.54 6572.07 6497.14 4718.40 -4466.49 0.60 5985346.44 614389.57 N 70.36881021 W 149.07042705 8263.63 69.30 319.87 3912.54 3974.44 6581.11 6661.64 6586.59 4786.52 -4524.65 0.75 5985413.61 614330.33 N 70.36899620 W 149.07090000 8357.17 68.92 319.48 3945.89 4007.79 6668.49 6749.03 6673.86 4853.14 -4581.21 0.56 5985479.33 614272.73 N 70.36917812 W 149.07135984 8451.28 68.68 319.00 3979.93 4041.83 6756.23 6836.77 6761.51 4919.60 -4638.49 0.54 5985544.86 614214.41 N 70.36935959 W 149.07182563 8544.81 68.79 318.73 4013.85 4075.75 6843.39 6923.94 6848.61 4985.25 -4695.83 0.29 5985609.59 614156.04 N 70.36953883 W 149.0.7 8638.64 69.21 319.42 4047.47 4109.37 6930.99 7011.53 6936.14 5051.43 -4753.21 0.82 5985674.85 614097.62 N 70.36971954 W 149.0 7 8734.07 69.24 318.68 4081.32 4143.22 7020.21 7100.76 7025.29 5118.82 -4811.69 0.73 5985741.29 614038.08 N 70.36990354 W 149.07323399 8828.74 69.33 318.39 4114.81 4176.71 7108.76 7189.31 7113.80 5185.18 -4870.32 0.30 5985806.71 613978.41 N 70.37008472 W 149.07371078 8921.77 69.33 318.15 4147.65 4209.55 7195.79 7276.35 7200.81 5250.14 -4928.26 0.24 5985870.73 613919.45 N 70.37026207 W 149.07418191 9014.80 69.22 318.24 4180.57 4242.47 7282.80 7363.36 7287.80 5315.00 -4986.26 0.15 5985934.65 613860.43 N 70.37043916 W 149.07465357 9110.30 69.34 317.94 4214.36 4276.26 7372.11 7452.68 7377.10 5381.47 -5045.92 0.32 5986000.17 613799.73 N 70.37062065 W 149.07513876 9205.36 71.23 318.69 4246.42 4308.32 7461.59 7542.17 7466.55 5448.30 -5105.43 2.12 5986066.04 613739.17 N 70.37080311 W 149.07562268 9300.32 70.85 318.62 4277.28 4339.18 7551.39 7631.97 7556.31 5515.72 -5164.76 0.41 5986132.50 613678.79 N 70.37098719 W 149.07610515 9390.76 70.73 319.64 4307.04 4368.94 7636.80 7717.38 7641.65 5580.30 -5220.64 1.07 5986196.18 613621.89 N 70.37116352 W 149.07655963 9484.11 70.67 319.98 4337.89 4399.79 7724.89 7805.48 7729.64 5647.61 -5277.50 0.35 5986262.57 613563.98 N 70.37134727 W 149.07702203 9577.90 70.37 320.34 4369.17 4431.07 7813.29 7893.90 7817.93 5715.50 -5334.14 0.48 5986329.55 613506.27 N 70.37153264 W 149.07748275 9674.28 69.88 320.46 4401.93 4463.83 7903.90 7984.54 7908.41 5785.34 -5391.92 0.52 5986398.46 613447.40 N 70.37172332 W 149.07795267 9765.97 69.58 320.95 4433.70 4495.60 7989.87 8070.55 7994.24 5851.90 -5446.39 0.60 5986464.14 613391.88 N 70.37190506 W 149.07839573 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-119 (slot 13)\S-119\S-119\S-119 Generated 10/22/2004 4:20 PM Page 3 of 5 .. Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (It) (deg/100 It) (ltUS) (ltUS) 9861.31 69.38 320.87 4467.12 4529.02 8079.11 8159.84 8083.33 5921.20 -5502.69 0.22 5986532.54 613334.49 N 70.37209427 W 149.07885367 9956.17 69.36 320.81 4500.54 4562.44 8167.84 8248.62 8171.92 5990.04 -5558.75 0.06 5986600.47 613277.35 N 70.37228222 W 149.07930968 10049.30 69.31 320.64 4533.41 4595.31 8254.94 8335.76 8258.89 6057.49 -5613.92 0.18 5986667.03 613221.12 N 70.37246638 W 149.07975837 10143.13 69.13 320.09 4566.70 4628.60 8342.63 8423.49 8346.48 6125.05 -5669.88 0.58 5986733.69 613164.10 N 70.37265084 W 149.08021355 10237.75 69.29 320.16 4600.28 4662.18 8431.08 8511.95 8434.83 6192.94 -5726.59 0.18 5986800.66 613106.33 N 70.37283618 W 149.08067487 10332.94 69.32 319.95 4633.92 4695.82 8520.11 8600.99 8523.77 6261.21 -5783.76 0.21 5986868.01 613048.08 N 70.37302257 W 149.08113994 10425.46 69.80 320.40 4666.23 4728.13 8606.78 8687.69 8610.35 6327.79 -5839.28 0.69 5986933.70 612991.51 N 70.37320434 W 149.08159159 10519.97 69.86 319.80 4698.82 4760.72 8695.48 8776.40 8698.96 6395.85 -5896.19 0.60 5987000.84 612933.54 N 70.37339015 W 149.08205449 10614.50 69.93 319.80 4731.31 4793.21 8784.24 8865.17 8787.65 6463.65 -5953.49 0.07 5987067.71 612875.18 N 70.37357526 W 149.08252059 10709.96 70.22 319.33 4763.84 4825.74 8873.98 8954.92 8877.33 6531.96 -6011.69 0.55 5987135.08 612815.90 N 70.37376174 W 149.08299410 10802.64 69.82 318.65 4795.51 4857.41 8961.08 9042.02 8964.40 6597.69 -6068.85 0.81 5987199.89 612757.71 N 70.37394117 W 149.08_ 10896.91 69.55 317.95 4828.24 4890.14 9049.48 9130.42 9052.79 6663.70 -6127.66 0.75 5987264.95 612697.87 N 70.37412137 W 149.08 10991.07 69.76 318.61 4860.98 4922.88 9137.76 9218.71 9141.07 6729.59 -6186.41 0.69 5987329.90 612638.08 N 70.37430126 W 149.08 9 11086.25 69.46 318.54 4894.14 4956.04 9226.97 9307.93 9230.26 6796.49 -6245.44 0.32 5987395.84 612578.00 N 70.37448388 W 149.08489560 11180.91 69.83 318.51 4927.07 4988.97 9315.72 9396.68 9319.00 6862.98 -6304.22 0.39 5987461.39 612518.18 N 70.37466540 W 149.08537377 11274.88 69.70 319.18 4959.57 5021.47 9403.89 9484.85 9407.14 6929.37 -6362.24 0.68 5987526.84 612459.12 N 70.37484663 W 149.08584583 11370.27 70.14 320.17 4992.32 5054.22 9493.47 9574.44 9496.66 6997.67 -6420.22 1.08 5987594.21 612400.07 N 70.37503309 W 149.08631751 11462.85 69.97 320.18 5023.90 5085.80 9580.48 9661 .46 9583.59 7064.51 -6475.95 0.18 5987660.15 612343.28 N 70.37521555 W 149.08677098 11559.39 70.22 321.39 5056.77 5118.67 9671.20 9752.24 9674.21 7134.84 -6533.34 1.21 5987729.55 612284.79 N 70.37540754 W 149.08723792 11651.65 69.72 321.35 5088.37 5150.27 9757.80 9838.91 9760.70 7202.55 -6587.45 0.54 5987796.39 612229.62 N 70.37559240 W 149.08767822 11747.35 69.72 321.35 5121.54 5183.44 9847.49 9928.68 9850.27 7272.66 -6643.52 0.00 5987865.59 612172.45 N 70.37578379 W 149.08813443 11842.26 69.39 321.42 5154.69 5216.59 9936.34 10017.61 9939.01 7342.14 -6699.02 0.35 5987934.18 612115.86 N 70.37597349 W 149.08858604 11936.00 69.39 321.57 5187.69 5249.59 10024.00 10105.35 10026.55 7410.80 -6753.64 0.15 5988001.96 612060.15 N 70.37616093 W 149.08903055 12032.75 69.33 322.06 5221.79 5283.69 10114.42 10195.89 10116.86 7481.97 -6809.62 0.48 5988072.23 612003.06 N 70.37635521 W 149.08948603 12127.26 69.15 322.49 5255.29 5317.19 10202.65 10284.27 10204.95 7551.87 -6863.69 0.47 5988141.25 611947.89 N 70.37654603 W 149.08992607 12221.67 68.66 322.18 5289.27 5351.17 10290.58 10372.35 10292.75 7621.60 -6917.51 0.60 5988210.11 611892.98 N 70.37673638 W 149.09036408 12316.47 68.09 322.46 5324.21 5386.11 10378.55 10460.48 10380.60 7691.34 -6971.38 0.66 5988278.99 611838.01 N 70.37692679 W 149.09080247 12411.65 67.88 322.44 5359.89 5421.79 10466.63 10548.72 10468.56 7761.30 -7025.16 0.22 5988348.08 611783.13 N 70.37711777 W 149.09124014 12504.87 69.00 321.37 5394.14 5456.04 10553.21 10635.41 10555.04 7829.53 -7078.65 1.61 5988415.44 611728.57 N 70.37730402 W 149.0.6 12600.14 69.67 321.07 5427.76 5489.66 10642.28 10724.55 10644.02 7899.02 -7134.48 0.76 5988484.03 611671.65 N 70.37749371 W 149.0 84 12694.16 69.75 320.30 5460.37 5522.27 10730.42 10812.74 10732.11 7967.24 -7190.35 0.77 5988551.35 611614.71 N 70.37767996 W 149.09258454 12788.36 69.71 320.11 5493.00 5554.90 10818.77 10901 .11 10820.41 8035.14 -7246.91 0.19 5988618.33 611557.08 N 70.37786529 W 149.09304483 12883.03 69.68 320.28 5525.86 5587.76 10907.53 10989.89 10909.12 8103.35 -7303.75 0.17 5988685.63 611499.17 N 70.37805148 W 149.09350741 12977.47 69.49 320.02 5558.80 5620.70 10996.02 11078.40 10997.57 8171.30 -7360.46 0.33 5988752.66 611441.39 N 70.37823696 W 149.09396898 13072.42 69.32 320.91 5592.20 5654.10 11084.87 11167.28 11086.37 8239.84 -7417.04 0.90 5988820.30 611383.74 N 70.37842408 W 149.09442944 13168.28 69.16 321.39 5626.18 5688.08 11174.44 11256.92 11175.87 8309.65 -7473.27 0.50 5988889.20 611326.41 N 70.37861463 W 149.09488709 13262.93 69.57 321.23 5659.53 5721.43 11262.94 11345.50 11264.30 8378.79 -7528.64 0.46 5988957.44 611269.96 N 70.37880336 W 149.09533777 13356.98 70.04 322.40 5692.00 5753.90 11351.10 11433.76 11352.38 8448.17 -7583.20 1.27 5989025.94 611214.30 N 70.37899274 W 149.09578191 13450.72 69.71 322.21 5724.25 5786.15 11438.96 11521.78 11440.16 8517.82 -7637.02 0.40 5989094.72 611159.39 N 70.37918286 W 149.09622000 13545.54 69.40 322.42 5757.37 5819.27 11527.66 11610.63 11528.77 8588.13 -7691.34 0.39 5989164.15 611103.97 N 70.37937479 W 149.09666212 13640.05 69.09 323.09 5790.87 5852.77 11615.84 11699.00 11616.87 8658.48 -7744.82 0.74 5989233.64 611049.38 N 70.37956684 W 149.09709754 13734.58 68.89 323.34 5824.76 5886.66 11703.84 11787.25 11704.77 8729.15 -7797.67 0.33 5989303.46 610995.42 N 70.37975976 W 149.09752773 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Sld( d031 rt-546 ) S-119 (slot 13)\S-119\S-119\S-119 Generated 10/22/2004 4:20 PM Page 4 of 5 1. Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (ftUS) (ftUS) 13829.41 69.07 323.03 5858.77 5920.67 11792.12 11875.77 11792.96 8800.02 -7850.71 0.36 5989373.4 7 610941.27 N 70.37995321 W 149.09795956 13924.68 69.36 323.11 5892.58 5954.48 11880.96 11964.84 11881.72 8871.22 -7904.23 0.31 5989443.80 610886.63 N 70.38014757 W 149.09839524 14018.20 69.63 323.20 5925.34 5987.24 11968.32 12052.43 11969.01 8941.32 -7956.75 0.30 5989513.05 610833.00 N 70.38033892 W 149.09882287 14113.00 70.03 323.38 5958.03 6019.93 12057.05 12141.42 12057.66 9012.66 -8009.95 0.46 5989583.53 610778.69 N 70.38053365 W 149.09925594 14207.05 70.26 323.53 5989.97 6051.87 12145.23 12229.88 12145.78 9083.72 -8062.62 0.29 5989653.75 610724.90 N 70.38072765 W 149.09968479 14300.94 69.89 323.15 6021.97 6083.87 12233.24 12318.15 12233.72 9154.53 -8115.32 0.55 5989723.70 610671.08 N 70.38092094 W 149.10011389 14396.42 69.56 322.55 6055.05 6116.95 12322.60 12407.71 12323.02 9225.92 -8169.41 0.68 5989794.22 610615.88 N 70.38111580 W 149.10055426 14490.74 69.60 320.87 6087.96 6149.86 12410.88 12496.10 12411.27 9295.29 -8224.18 1.67 5989862.71 610560.02 N 70.38130516 W 149.10100016 14586.46 69.93 320.63 6121.07 6182.97 12500.65 12585.92 12501.01 9364.84 -8281.00 0.42 5989931.34 610502.10 N 70.38149499 W 149.10146279 14681.32 69.95 321.28 6153.61 6215.51 12589.70 12675.02 12590.04 9434.05 -8337.13 0.64 5989999.64 610444.88 N 70.38168388 W 149.10191976 14776.52 69.70 321.53 6186.44 6248.34 12678.98 12764.38 12679.28 9503.89 -8392.88 0.36 5990068.58 610388.04 N 70.38187451 W 149.10.1 14869.84 69.37 321.13 6219.07 6280.97 12766.33 12851.81 12766.61 9572.15 -8447.51 0.54 5990135.96 610332.34 N 70.38206082 W 149.102 "10 14964.25 68.53 320.62 6252.98 6314.88 12854.39 12939.92 12854.65 9640.50 -8503.10 1.02 5990203.42 610275.67 N 70.38224739 W 149.10327106 15058.09 68.08 319.67 6287.67 6349.57 12941.56 13027.11 12941.81 9707.44 -8558.98 1.06 5990269.45 610218.75 N 70.38243007 W 149.10372599 15153.26 66.91 319.77 6324.10 6386.00 13029.48 13115.03 13029.71 9774.51 -8615.82 1.23 5990335.61 610160.85 N 70.38261313 W 149.10418879 15247.86 64.46 320.21 6363.05 6424.95 13115.67 13201.23 13115.89 9840.53 -8671.24 2.62 5990400.74 610104.39 N 70.38279333 W 149.10464004 15346.12 61.24 320.51 6407.88 6469.78 13203.06 13288.66 13203.27 9907.85 -8727.02 3.29 5990467.16 610047.56 N 70.38297706 W 149.10509417 15438.72 57.63 321.14 6454.96 6516.86 13282.74 13368.38 13282.93 9969.65 -8777.38 3.94 5990528.14 609996.22 N 70.38314572 W 149.10550427 15534.16 53.63 321.01 6508.83 6570.73 13361.44 13447.14 13361.62 10030.92 -8826.87 4.19 5990588.61 609945.78 N 70.38331295 W 149.10590721 15628.28 50.71 321.06 6566.55 6628.45 13435.73 13521.47 13435.89 10088.72 -8873.61 3.10 5990645.65 609898.13 N 70.38347069 W 149.10628784 15723.77 48.72 321.28 6628.29 6690.19 13508.51 13594.31 13508.66 10145.46 -8919.28 2.09 5990701.66 609851.56 N 70.38362556 W 149.10665976 15817.51 48.36 321.81 6690.35 6752.25 13578.69 13664.56 13578.82 10200.47 -8962.97 0.57 5990755.97 609807.01 N 70.38377570 W 149.10701554 15911.49 48.77 322.83 6752.55 6814.45 13649.02 13735.01 13649.14 10256.23 -9006.04 0.92 5990811.03 609763.07 N 70.38392790 W 149.10736625 16006.78 49.05 322.42 6815.18 6877.08 13720.69 13806.83 13720.79 10313.30 -9049.63 0.44 5990867.40 609718.58 N 70.38408367 W 149.10772130 16102.33 48.94 322.17 6877.87 6939.77 13792.68 13878.94 13792.76 10370.35 -9093.73 0.23 5990923.74 609673.58 N 70.38423937 W 149.10808046 16197.79 48.71 322.67 6940.72 7002.62 13864.40 13950.79 13864.4 7 10427.30 -9137.55 0.46 5990979.97 609628.86 N 70.38439479 W 149.10843735 16288.83 47.16 322.87 7001.71 7063.61 13931.83 14018.38 13931.89 10481.11 -9178.44 1.71 5991033.12 609587.13 N 70.38454166 W 149.10877039 16382.81 45.83 322.83 7066.40 7128.30 13999.84 14086.54 13999.88 10535.44 -9219.61 1.42 5991086.79 609545.11 N 70.38468995 W 149.1.66 Last MWD+IFR+MS 16478.04 44.55 322.94 7133.52 7195.42 14067.24 14154.10 14067.27 10589.31 -9260.38 1.35 5991140.00 609503.50 N 70.38483699 W 149.1 70 TD ( Projected) 16536.00 44.55 322.94 7174.82 7236.72 14107.80 14194.76 14107.83 10621.76 -9284.88 0.00 5991172.05 609478.48 N 70.38492555 W 149.1 29 Survey Type: Definitive Survey NOTES: GYD GC MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multlshots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) LeQal Description: Northina IY) rftUS1 EastinQ IX) rftUS1 Surface: 4496 FSL 4498 FEL S35 T12N R12E UM 5980699.94 618930.01 BHL: 4552 FSL 3209 FEL S21 T12N R12E UM 5991172.05 609478.48 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-119 (slot 13)\S-119\S-119\S-119 Generated 10/22/20044:20 PM Page 5 of 5 T~EE = ~ WELLHEAD = ,<.........---...--...,.. > ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max 4-1/16" CrN FMC NA 64.3 . DRLG 5-119 300 - - ,~q" "ß.= Datum 1V D = XXX'SS 10-314" CSG, 45.5#, L-80, BTC H 6700' r--- Minimum ID = 3.7250" 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#, L-80, TC-II [] I Z 10 ~. PERFORATION SUMMARY I REF LOG: TCP ÆRF ANGLE AT TOP PERF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" X Nipple ID = 3.183" H 15677' 4-1/2" XN Nipple 10:: 3.183" H 15698' 4-1/2" 12.6# L-80 TC II Tubing H 15710' I PBTD l-f 16429' L 7" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" H 16513' =1 I --'= . 980' 2213' 1-1 10-3/4" TAM PORT I COLLAR H 4-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD 1VD DEV TYPE VL V LA TCH 5 5517 3000 68 <BG-2-1R 4 7728 3800 69 <BG-2-1 R 3 12913 5600 69 <BG-2-1R 2 15199 6400 65 <BG-2-1R 1 15519 6560 55 <BG-2-1R 0----1 1!BB I' &--1 15650' H \ 4-1/2" BKR CMD sliding sleeve 7" X 4-1/2" BKR Premier PKR . I 15836' H 7" Marker Joint ~ DA TE REV BY COMMENTS 08/04/04 JES PROPOSED COMPLETION DA TE REV BY COMMENTS GPB AURORA WELL: S-119 ÆRMIT No: API No: BP Exploration (Alaska) SCRLUMBERGER Survey report Client. ..... ...... ... ....: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Aurora Well. . . . . . . . . . . . . . . . . . . . .: S-119 API number........... ....: 50-029-23222-00 Engineer............ .....: S. Moy RIG: . . . . . . . . . . . . . . . . . . . . .: Doyon 16 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.. ...: Minimum curvature Method for DLS..... ......: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference...... ....: Driller's Pipe Tally GL above permanent.... ...: 36.20 ft KB above permanent.. .....: N/A Top Drive ft DF above permanent.. .....: 61.90 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)..... ...: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).... .....: N 70.35592362 ft Departure (+E/W-)........: W 149.03413561 ft Azimuth from rotary table to target: 318.95 degrees [(c)2004 IDEAL ID8_1C_02] 12-0ct-2004 04:19:00 Spud date.... ........ ....: Last survey date.........: Total accepted surveys...: MD of first survey. ......: MD of last survey........: Page 1 of 7 27-Sept-04 12-0ct-04 179 0.00 ft 16536.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date. ...........: 04-0ct-2004 Magnetic field strength..: 1152.11 RCNT Magnetic dec (+E/W-) .....: 24.90 degrees Magnetic dip.. ...........: 80.84 degrees ----- MWD survey Reference Reference G..............: Reference R..............: Reference Dip. ...........: Tolerance of G. ..........: Tolerance of R... ........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152.11 RCNT 80.84 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.90 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.90 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction {o(z.sjocf . . Ä\J ~-,[ ~ '2- SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 2 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 290.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 47.10 0.01 358.43 47.10 47.10 0.00 0.00 -0.00 0.00 358.43 0.02 Gyro None 3 99.90 0.12 302.08 52.80 99.90 0.06 0.04 -0.05 0.06 308.96 0.22 Gyro None 4 164.40 0.75 302.49 64.50 164.40 0.53 0.30 -0.46 0.55 303.15 0.98 Gyro None 5 249.50 1. 01 288.05 85.10 249.49 1. 71 0.83 -1.64 1. 84 296.86 0.40 Gyro None 6 339.00 2.31 284.15 89.50 338.95 3.86 1.52 -4.14 4.41 290.12 1. 46 Gyro None . 7 430.40 4.93 291. 46 91. 40 430.16 8.86 3.41 -9.58 10.17 289.56 2.90 Gyro None 8 529.80 8.45 294.56 99.40 528.87 19.31 8.00 -20.21 21. 73 291. 61 3.56 Gyro None 9 561. 21 9.63 292.90 31.41 559.89 23.77 9.99 -24.72 26.67 291. 99 3.85 MWD IFR MS 10 657.10 13.98 296.05 95.89 653.73 41.65 18.20 -42.53 46.26 293.17 4.58 MWD IFR MS 11 745.14 17.81 296.59 88.04 738.38 63.91 28.90 -64.13 70.34 294.26 4.35 MWD IFR MS - 12 840.22 21.73 296.32 95.08 827.84 93.61 43.22 -92.92 102.48 294.94 4.12 MWD IFR MS 13 934.47 25.65 299.13 94.25 914 . 14 128.92 60.89 -126.39 140.29 295.72 4.33 MWD IFR MS 14 1030.23 29.58 297.11 95.76 998.97 170.38 81. 76 -165.55 184.64 296.28 4.22 MWD IFR MS - 15 1125.15 31.67 295.95 94.92 1080.65 215.07 103.34 -208.82 232.99 296.33 2.29 MWD IFR MS 16 1218.57 34.77 293.48 93.42 1158.80 261.70 124.69 -255.31 284.14 296.03 3.62 MWD IFR MS - 17 1314.99 35.21 293.90 96.42 1237.79 311. 71 146.91 -305.94 339.39 295.65 0.52 MWD IFR MS 18 1406.01 37.47 293.08 91.02 1311.10 360.40 168.39 -355.41 393.29 295.35 2.54 MWD IFR MS - 19 1499.97 39.07 292.63 93.96 1384.87 412.66 190.99 -409.04 451.43 295.03 1. 73 MWD IFR MS - 20 1594.80 42.74 291.51 94.83 1456.53 468.02 214.30 -466.58 513.44 294.67 3.95 MWD IFR MS 21 1685.29 45.73 293.52 90.49 1521. 36 524.55 238.49 -524.87 576.51 294.44 3.65 MWD IFR MS . - 22 1780.61 49.18 295.68 95.32 1585.81 588.53 267.75 -588.69 646.72 294.46 3.99 MWD IFR MS 23 1873.97 53.18 296.51 93.36 1644.32 655.54 299.76 -653.99 719.42 294.62 4.34 MWD IFR MS - 24 1968.78 56.53 300.11 94.81 1698.90 728.08 336.55 -722.19 796.76 294.99 4.70 MWD IFR MS - 25 2063.31 59.33 304.39 94.53 1749.10 804.79 379.31 -789.88 876.24 295.65 4.85 MWD IFR MS 26 2158.35 60.85 310.15 95.04 1796.52 885.42 429.19 -855.38 957.02 296.65 5.49 MWD IFR MS - 27 2252.14 62.66 315.70 93.79 1840.93 967.53 485.45 -915.82 1036.53 297.93 5.56 MWD IFR MS - 28 2348.42 65.05 318.09 96.28 1883.36 1053.89 548.56 -974.86 1118.60 299.37 3.34 MWD IFR MS - 29 2443.55 66.56 319.38 95.13 1922.35 1140.66 613.78 -1032.08 1200.80 300.74 2.01 MWD IFR MS - 30 2537.14 69.87 320.52 93.59 1957.08 1227.54 680.30 -1087.98 1283.17 302.02 3.71 MWD IFR MS [(c)2004 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 3 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2628.65 69.09 321.37 91. 51 1989.16 1313 .19 746.85 -1141.98 1364.52 303.18 1. 22 MWD IFR MS - 32 2721. 93 68.97 321. 92 93.28 2022.54 1400.20 815.16 -1196.03 1447.40 304.28 0.57 MWD IFR MS 33 2820.07 68.71 322.07 98.14 2057.97 1491. 59 887.27 -1252.39 1534.84 305.32 0.30 MWD IFR MS - 34 2914.53 68.99 321. 86 94.46 2092.05 1579.56 956.66 -1306.67 1619.44 306.21 0.36 MWD IFR MS - 35 3009.91 69.62 321. 88 95.38 2125.76 1668.67 1026.85 -1361.76 1705.52 307.02 0.66 MWD IFR MS 36 3104.21 69.39 320.83 94.30 2158.77 1756.93 1095.83 -1416.92 1791.23 307.72 1. 07 MWD IFR MS . - 37 3199.57 69.17 320.47 95.36 2192.51 1846.08 1164.81 -1473.47 1878.27 308.33 0.42 MWD IFR MS - 38 3293.85 69.21 321.12 94.28 2226.01 1934.16 1233.10 -1529.18 1964.41 308.88 0.65 MWD IFR MS - 39 3388.41 69.33 321.62 94.56 2259.48 2022.52 1302.18 -1584.39 2050.85 309.42 0.51 MWD IFR MS - 40 3482.74 69.70 321.67 94.33 2292.49 2110.79 1371. 48 -1639.22 2137.29 309.92 0.40 MWD IFR MS 41 3577.05 69.58 320.94 94.31 2325.30 2199.13 1440.49 -1694.50 2224.03 310.37 0.74 MWD IFR MS - 42 3671.40 69.03 320.99 94.35 2358.64 2287.34 1509.04 -1750.08 2310.85 310.77 0.59 MWD IFR MS 43 3766.41 69.15 321.97 95.01 2392.55 2376.00 1578.48 -1805.36 2398.11 311.16 0.97 MWD IFR MS - 44 3861.76 69.48 321.97 95.35 2426.23 2465.08 1648.75 -1860.31 2485.79 311.55 0.35 MWD IFR MS - 45 3955.85 69.37 323.22 94.09 2459.30 2552.99 1718.72 -1913.82 2572.30 311. 93 1. 25 MWD IFR MS 46 4049.54 68.92 322.75 93.69 2492.66 2640.32 1788.63 -1966.53 2658.27 312.29 0.67 MWD IFR MS - 47 4144.72 69.42 322.98 95.18 2526.50 2729.07 1859.55 -2020.23 2745.77 312.63 0.57 MWD IFR MS - 48 4238.79 70.09 322.94 94.07 2559.05 2817.12 1930.00 -2073.40 2832.64 312.95 0.71 MWD IFR MS - 49 4333.27 70.53 322.19 94.48 2590.89 2905.89 2000.63 -2127.47 2920.38 313.24 0.88 MWD IFR MS - 50 4427.58 70.14 322.55 94.31 2622.62 2994.54 2070.96 -2181.69 3008.10 313.51 0.55 MWD IFR MS 51 4522.56 70.14 321.77 94.98 2654.89 3083.73 2141.51 -2236.49 3096.44 313.76 0.77 MWD IFR MS . - 52 4617.40 68.78 321. 84 94.84 2688.17 3172.43 2211.30 -2291.41 3184.40 313.98 1.44 MWD IFR MS - 53 4712.04 69.19 322.37 94.64 2722.11 3260.64 2281.02 -2345.67 3271.88 314.20 0.68 MWD IFR MS - 54 4806.78 69.58 322.33 94.74 2755.46 3349.16 2351.23 -2399.83 3359.68 314.41 0.41 MWD IFR MS - 55 4899.49 68.78 322.60 92.71 2788.41 3435.65 2419.94 -2452.63 3445.51 314.62 0.90 MWD IFR MS 56 4994.93 69.25 323.39 95.44 2822.59 3524.54 2491.11 -2506.26 3533.69 314.83 0.92 MWD IFR MS - 57 5090.69 69.95 323.28 95.76 2855.97 3614.03 2563.10 -2559.86 3622.48 315.04 0.74 MWD IFR MS - 58 5185.29 69.70 323.95 94.60 2888.60 3702.53 2634.58 -2612.53 3710.30 315.24 0.72 MWD IFR MS - 59 5277 . 85 70.15 323.03 92 .56 2920.37 3789.19 2704.46 -2664.26 3796.36 315.43 1. 05 MWD IFR MS - 60 5372.44 69.55 321. 85 94.59 2952.96 3877.83 2774.85 -2718.38 3884.51 315.59 1. 33 MWD IFR MS [(c)2004 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 4 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) ( deg ) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5466.94 68.62 321.37 94.50 2986.69 3966.00 2844.04 -2773.20 3972.30 315.72 1. 09 MWD IFR MS - 62 5560.57 68.90 321. 09 93.63 3020.61 4053.21 2912.08 -2827.85 4059.18 315.84 0.41 MWD IFR MS - 63 5655.18 70.00 320.90 94.61 3053.82 4141.74 2980.92 -2883.61 4147.42 315.95 1.18 MWD IFR MS - 64 5750.29 70.12 319.11 95.11 3086.26 4231.13 3049.41 -2941.07 4236.60 316.04 1. 77 MWD IFR MS - 65 5844.92 69.95 318.18 94.63 3118.57 4320.07 3116.18 -2999.83 4325.45 316.09 0.94 MWD IFR MS 66 5941. 06 69.72 317.85 96 .14 3151.71 4410.30 3183.26 -3060.20 4415.65 316.13 0.40 MWD IFR MS . 67 6034.33 69.98 317.59 93.27 3183.84 4497.84 3248.04 -3119.11 4503.18 316.16 0.38 MWD IFR MS - 68 6130.20 69.20 317.02 95.87 3217.28 4587.65 3314.08 -3180.04 4593.01 316.18 0.99 MWD IFR MS - 69 6224.44 68.54 317.27 94.24 3251.25 4675.51 3378.52 -3239.82 4680.90 316.20 0.74 MWD IFR MS - 70 6319.12 69.82 318.05 94.68 3284.90 4763.99 3443.93 -3299.43 4769.37 316.23 1. 56 MWD IFR MS 71 6413.52 69.66 317.96 94.40 3317.59 4852.53 3509.75 -3358.68 4857.89 316.26 0.19 MWD IFR MS - 72 6509.37 70.32 318.08 95.85 3350.39 4942.59 3576.70 -3418.92 4947.91 316.29 0.70 MWD IFR MS - 73 6603.32 70.03 317.48 93.95 3382.25 5030.95 3642.16 -3478.31 5036.26 316.32 0.68 MWD IFR MS - 74 6631.61 69.81 317.09 28.29 3391. 96 5057.51 3661.68 -3496.33 5062.83 316.32 1.51 MWD IFR MS - 75 6765.19 68.40 315.63 133.58 3439.61 5182.17 3751.99 -3582.45 5187.61 316.32 1.47 MWD IFR MS 76 6855.98 68.49 315.32 90.79 3472.96 5266.45 3812.19 -3641.66 5272.05 316.31 0.33 MWD IFR MS 77 6949.56 68.93 316.51 93.58 3506.94 5353.52 3874.82 -3702.32 5359.24 316.30 1. 27 MWD IFR MS - 78 7044.93 68.89 315.81 95.37 3541.26 5442.40 3939.00 -3763.95 5448.22 316.30 0.69 MWD IFR MS - 79 7139.13 68.82 316.15 94.20 3575.24 5530.14 4002.18 -3825.00 5536.07 316.30 0.34 MWD IFR MS - 80 7233.06 68.49 316.92 93.93 3609.43 5617.55 4065.68 -3885.19 5623.56 316.30 0.84 MWD IFR MS 81 7329.71 68.40 317.38 96.65 3644.94 5707.39 4131.58 -3946.32 5713.44 316.31 0.45 MWD IFR MS . - 82 7423.50 68.39 317.46 93.79 3679.47 5794.56 4195.79 -4005.32 5800.62 316.33 0.08 MWD IFR MS - 83 7518.51 68.10 318.00 95.01 3714.69 5882.78 4261.09 -4064.68 5888.84 316.35 0.61 MWD IFR MS - 84 7610.11 69.04 318.08 91.60 3748.15 5968.04 4324.49 -4121.69 5974.07 316.38 1. 03 MWD IFR MS - 85 7703.75 69.65 318.54 93.64 3781.18 6055.66 4389.92 -4179.96 6061.64 316.40 0.80 MWD IFR MS 86 7798.28 69.49 318.47 94.53 3814.18 6144.24 4456.27 -4238.65 6150.17 316.43 0.18 MWD IFR MS - 87 7888.44 69.90 319.01 90.16 3845.47 6228.79 4519.84 -4294.42 6234.66 316.47 0.72 MWD IFR MS - 88 7980.68 70.40 319.23 92.24 3876.79 6315.55 4585.44 -4351.20 6321. 32 316.50 0.59 MWD IFR MS - 89 8074.61 70.06 318.96 93.93 3908.56 6403.94 4652.24 -4409.08 6409.63 316.54 0.45 MWD IFR MS - 90 8167.95 69.53 319.14 93.34 3940.80 6491. 54 4718.40 -4466.49 6497.14 316.57 0.60 MWD IFR MS [(c)2004 IDEAL ID8_1C_02] . SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 5 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8263.63 69.30 319.87 95.68 3974.44 6581.11 4786.52 -4524.65 6586.59 316.61 0.75 MWD IFR MS - 92 8357.17 68.92 319.48 93.54 4007.79 6668.49 4853.14 -4581. 21 6673.86 316.65 0.56 MWD IFR MS - 93 8451.28 68.68 319.00 94.11 4041.82 6756.23 4919.60 -4638.49 6761.51 316.68 0.54 MWD IFR MS 94 8544.81 68.79 318.73 93.53 4075.75 6843.39 4985.25 -4695.83 6848.61 316.71 0.29 MWD IFR MS - 95 8638.64 69.21 319.42 93.83 4109.37 6930.99 5051.43 -4753.21 6936.14 316.74 0.82 MWD IFR MS 96 8734.07 69.24 318.68 95.43 4143.22 7020.21 5118.82 -4811.69 7025.29 316.77 0.73 MWD IFR MS . 97 8828.74 69.33 318.39 94.67 4176.71 7108.76 5185.18 -4870.32 7113.80 316.79 0.30 MWD IFR MS - 98 8921. 77 69.33 318.15 93.03 4209.55 7195.79 5250.14 -4928.26 7200.81 316.81 0.24 MWD IFR MS - 99 9014.80 69.22 318.24 93.03 4242.47 7282.80 5315.00 -4986.26 7287.80 316.83 0.15 MWD IFR MS - 100 9110.30 69.34 317.94 95.50 4276.26 7372.11 5381. 47 -5045.92 7377.10 316.84 0.32 MWD IFR MS 101 9205.36 71. 23 318.69 95.06 4308.32 7461.59 5448.30 -5105.43 7466.55 316.86 2.12 MWD IFR MS - 102 9300.32 70.85 318.62 94.96 4339.18 7551.40 5515.72 -5164.76 7556.32 316.88 0.41 MWD IFR MS - 103 9390.76 70.73 319.64 90.44 4368.93 7636.80 5580.30 -5220.64 7641.65 316.91 1. 07 MWD IFR MS - 104 9484.11 70.67 319.98 93.35 4399.79 7724.89 5647.61 -5277.50 7729.65 316.94 0.35 MWD IFR MS 105 9577.90 70.37 320.34 93.79 4431. 06 7813.29 5715.50 -5334.14 7817.93 316.98 0.48 MWD IFR MS 106 9674.28 69.88 320.46 96.38 4463.83 7903.90 5785.34 -5391. 92 7908.41 317.02 0.52 MWD IFR MS - 107 9765.97 69.58 320.95 91. 69 4495.60 7989.87 5851.90 -5446.39 7994.24 317.06 0.60 MWD IFR MS - 108 9861.31 69.38 320.87 95.34 4529.02 8079.11 5921.20 -5502.69 8083.33 317.10 0.22 MWD IFR MS - 109 9956.17 69.36 320.81 94.86 4562.44 8167.84 5990.04 -5558.75 8171.92 317.14 0.06 MWD IFR MS - 110 10049.30 69.31 320.64 93.13 4595.30 8254.94 6057.50 -5613.92 8258.89 317.18 0.18 MWD IFR MS 111 10143.13 69.13 320.09 93.83 4628.59 8342.63 6125.06 -5669.88 8346.48 317.21 0.58 MWD IFR MS . - 112 10237.75 69.29 320.16 94.62 4662.18 8431.08 6192.94 -5726.59 8434.83 317.24 0.18 MWD IFR MS - 113 10332.94 69.32 319.95 95.19 4695.82 8520.11 6261.21 -5783.76 8523.77 317.27 0.21 MWD IFR MS - 114 10425.46 69.80 320.40 92 .52 4728.13 8606.78 6327.79 -5839.28 8610.35 317.30 0.69 MWD IFR MS - 115 10519.97 69.86 319.80 94.51 4760.72 8695.48 6395.85 -5896.19 8698.96 317.33 0.60 MWD IFR MS 116 10614.50 69.93 319.80 94.53 4793.21 8784.24 6463.65 -5953.49 8787.65 317.35 0.07 MWD IFR MS - 117 10709.96 70.22 319.33 95.46 4825.74 8873.98 6531.96 -6011.69 8877.33 317.38 0.55 MWD IFR MS - 118 10802.64 69.82 318.65 92.68 4857.41 8961. 08 6597.69 -6068.85 8964.40 317.39 0.81 MWD IFR MS - 119 10896.91 69.55 317.95 94.27 4890.14 9049.48 6663.70 -6127.66 9052.79 317.40 0.75 MWD IFR MS - 120 10991. 07 69.76 318.61 94.16 4922.88 9137.76 6729.59 -6186.41 9141.07 317.41 0.69 MWD IFR MS [(c)2004 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 6 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11086.25 69.46 318.54 95.18 4956.04 9226.97 6796.49 -6245.44 9230.26 317.42 0.32 MWD IFR MS 122 11180.91 69.83 318.51 94.66 4988.96 9315.72 6862.98 -6304.22 9319.00 317.43 0.39 MWD IFR MS 123 11274.88 69.70 319.18 93.97 5021. 47 9403.89 6929.37 -6362.24 9407.14 317.44 0.68 MWD IFR MS - 124 11370.27 70.14 320.17 95.39 5054.22 9493.47 6997.67 -6420.22 9496.66 317.46 1. 08 MWD IFR MS 125 11462.85 69.97 320.18 92.58 5085.80 9580.48 7064.51 -6475.95 9583.59 317.49 0.18 MWD IFR MS 126 11559.39 70.22 321.39 96.54 5118.67 9671. 20 7134.84 -6533.34 9674.21 317.52 1. 21 MWD IFR MS . - 127 11651. 65 69.72 321.35 92.26 5150.27 9757.80 7202.55 -6587.45 9760.70 317.55 0.54 MWD IFR MS - 128 11747.35 69.72 321.35 95.70 5183.44 9847.49 7272.66 -6643.52 9850.27 317.59 0.00 MWD IFR MS - 129 11842.26 69.39 321.42 94.91 5216.59 9936.34 7342.14 -6699.02 9939.01 317.62 0.35 MWD IFR MS 69.3'9 - 130 11936.00 321.57 93.74 5249.59 10024.00 7410.80 -6753.64 10026.55 317.66 0.15 MWD IFR MS 131 12032.75 69.33 322.06 96.75 5283.69 10114.42 7481.97 -6809.62 10116.85 317.69 0.48 MWD IFR MS - 132 12127.26 69.15 322.49 94.51 5317.19 10202.65 7551.87 -6863.69 10204.95 317.73 0.47 MWD IFR MS - 133 12221.67 68.66 322.18 94.41 5351.17 10290.58 7621.60 -6917.51 10292.75 317.77 0.60 MWD IFR MS - 134 12316.47 68.09 322.46 94.80 5386.11 10378.55 7691.34 -6971.38 10380.60 317.81 0.66 MWD IFR MS - 135 12411.65 67.88 322.44 95.18 5421.78 10466.63 7761.30 -7025.16 10468.56 317.85 0.22 MWD IFR MS 136 12504.87 69.00 321.37 93.22 5456.04 10553.21 7829.53 -7078.65 10555.04 317.88 1. 61 MWD IFR MS 137 12600.14 69.67 321. 07 95.27 5489.66 10642.28 7899.02 -7134.48 10644.02 317.91 0.76 MWD IFR MS - 138 12694.16 69.75 320.30 94.02 5522.27 10730.42 7967.24 -7190.35 10732.11 317.93 0.77 MWD IFR MS - 139 12788.36 69.71 320.11 94.20 5554.90 10818.77 8035.14 -7246.91 10820.41 317.95 0.19 MWD IFR MS - 140 12883.03 69.68 320.28 94.67 5587.75 10907.53 8103.35 -7303.75 10909.13 317.97 0.17 MWD IFR MS 141 12977.47 69.49 320.02 94.44 5620.70 10996.02 8171.30 -7360.46 10997.57 317.99 0.33 MWD IFR MS . - 142 13072.42 69.32 320.91 94.95 5654.10 11084.87 8239.84 -7417.04 11086.37 318.01 0.90 MWD IFR MS - 143 13168.28 69.16 321.39 95.86 5688.07 11174.44 8309.65 -7473.27 11175.87 318.03 0.50 MWD IFR MS - 144 13262.93 69.57 321.23 94.65 5721. 43 11262.94 8378.79 -7528.64 11264.30 318.06 0.46 MWD IFR MS - 145 13356.98 70.04 322.40 94.05 5753.90 11351.10 8448.17 -7583.20 11352.38 318.09 1. 27 MWD IFR MS 146 13450.72 69.71 322.21 93.74 5786.15 11438.96 8517.81 -7637.02 11440.16 318.12 0.40 MWD IFR MS - 147 13545.54 69.40 322.42 94.82 5819.27 11527.66 8588.13 -7691.34 11528.77 318.15 0.39 MWD IFR MS - 148 13640.05 69.09 323.09 94.51 5852.76 11615.84 8658.48,-7744.82 11616.86 318.19 0.74 MWD IFR MS - 149 13734.58 68.89 323.34 94.53 5886.66 11703.84 8729.15 -7797.67 11704.77 318.23 0.33 MWD IFR MS - 150 13829.41 69.07 323.03 94.83 5920.67 11792 . 12 8800.02 -7850.71 11792.96 318.26 0.36 MWD IFR MS [(c)2004 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 12-0ct-2004 04:19:00 Page 7 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (deg I tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 13924.68 69.36 323.11 95.27 5954.48 11880.96 8871.22 -7904.23 11881.72 318.30 0.31 MWD IFR MS - 152 14018.20 69.63 323.20 93.52 5987.24 11968.31 8941.32 -7956.75 11969.00 318.33 0.30 MWD IFR MS 153 14113.00 70.03 323.38 94.80 6019.93 12057.04 9012.66 -8009.94 12057.66 318.37 0.46 MWD IFR MS - 154 14207.05 70.26 323.53 94.05 6051.87 12145.23 9083.72 -8062.62 12145.77 318.41 0.29 MWD IFR MS - 155 14300.94 69.89 323.15 93.89 6083.87 12233.24 9154.53 -8115.32 12233.72 318.44 0.55 MWD IFR MS 156 14396.42 69.56 322.55 95.48 6116.95 12322.60 9225.92 -8169.41 12323.02 318.48 0.68 MWD IFR MS . 157 14490.74 69.60 320.87 94.32 6149.86 12410.88 9295.29 -8224.18 12411.27 318.50 1. 67 MWD IFR MS - 158 14586.46 69.93 320.63 95.72 6182.97 12500.65 9364.84 -8281.00 12501.01 318.51 0.42 MWD IFR MS - 159 14681.32 69.95 321.28 94.86 6215.51 12589.70 9434.05 -8337.13 12590.04 318.53 0.64 MWD IFR MS - 160 14776.52 69.70 321. 53 95.20 6248.34 12678.98 9503.89 -8392.87 12679.28 318.55 0.36 MWD IFR MS 161 14869.84 69.37 321.13 93.32 6280.97 12766.33 9572 . 15 -8447.50 12766.61 318.57 0.54 MWD IFR MS - 162 14964.25 68.53 320.62 94.41 6314.88 12854.39 9640.50 -8503.10 12854.65 318.59 1. 02 MWD IFR MS - 163 15058.09 68.08 319.67 93.84 6349.57 12941.56 9707.44 -8558.97 12941.81 318.60 1. 06 MWD IFR MS 164 15153.26 66.91 319.77 95.17 6386.00 13029.47 9774.51 -8615.82 13029.71 318.61 1. 23 MWD IFR MS - 165 15247.86 64.46 320.21 94.60 6424.94 13115.66 9840.53 -8671.24 13115.89 318.61 2.62 MWD IFR MS 166 15346.12 61. 24 320.51 98.26 6469.78 13203.06 9907.85 -8727.02 13203.27 318.63 3.29 MWD IFR MS - 167 15438.72 57.63 321.14 92.60 6516.86 13282.74 9969.65 -8777.38 13282.93 318.64 3.94 MWD IFR MS - 168 15534.16 53.63 321.01 95.44 6570.73 13361.44 10030.92 -8826.86 13361.62 318.65 4.19 MWD IFR MS - 169 15628.28 50.71 321.06 94.12 6628.45 13435.72 10088.72 -8873.61 13435.89 318.67 3.10 MWD IFR MS - 170 15723.77 48.72 321.28 95.49 6690.19 13508.51 10145.46 -8919.28 13508.66 318.68 2.09 MWD IFR MS 171 15817.51 48.36 321.81 93.74 6752.25 13578.69 10200.47 -8962.97 13578.82 318.69 0.57 MWD IFR MS . - 172 15911.49 48.77 322.83 93.98 6814.45 13649.02 10256.23 -9006.03 13649.14 318.71 0.92 MWD IFR MS - 173 16006.78 49.05 322.42 95.29 6877.07 13720.69 10313.30 -9049.63 13720.79 318.73 0.44 MWD IFR MS - 174 16102.33 48.94 322.17 95.55 6939.77 13792.67 10370.35 -9093.73 13792.76 318.75 0.23 MWD IFR MS - 175 16197.79 48.71 322.67 95.46 7002.61 13864.39 10427.29 -9137.55 13864.46 318.77 0.46 MWD IFR MS 176 16288.83 47.16 322.87 91. 04 7063.61 13931. 83 10481.11 -9178.44 13931.88 318.79 1. 71 MWD IFR MS - 177 16382.81 45.83 322.83 93.98 7128.30 13999.83 10535.44 -9219.61 13999.88 318.81 1. 42 MWD IFR MS - 178 16478.04 44.55 322.94 95.23 7195.41 14067.23 10589.31 -9260.37 14067.26 318.83 1. 35 MWD IFR MS 179 16536.00 44.55 322.94 57.96 7236.72 14107.80 10621.76 -9284.88 14107.82 318.84 0.00 Projected to TD [(c)2004 IDEAL ID8_1C_02J . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No S-119 Date Dispatched: 2-Sep-04 Installation/Rig Doyon 16 Dispatched By: J,Bosse Data No Of Prints No of Floppies Surveys 2 Rec,w,dø.-> e-mail address:johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ÄO (.(- I ~ ~ fc'f-L . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-119 BP Exploration (Alaska) Inc. Permit No: 204-162 Surface Location: 4497' NSL, 4498' WEL, SEC. 35, TI2N, R12E, UM Bottomhole Location: 4361' NSL, 3009' WEL, SEC. 21, TI2N, RI2E, UM Dear Mr.Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 07 (pager). BY ORDER <?f. THE COMMISSION DA TED this.:1fday of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. III Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a, Location of Well (Governmental Section): Surface: 4497' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 4104' NSL, 2795' WEL, SEC. 21, T12N, R12E, UM Total Depth: , 4361' NSL, 3009' WEL, SEC. 21:, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 y- 5980700 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: ...<.. ..,'.~~., deQrees Specifj~tiQþ Grade Coupling H-40 Weld L-80 BTC L-80 BTC-M ¡µ6Æ- 'Ys lst 2..004 . STATE OF ALASKA . ALASKA~IL AND GAS CONSERVATION COMM'SS'ORECEIVED PERMIT TO DRILL 20 MC 25.005 / AUG 2 42004 1b. Current Well Class 0 Exploratory .~.eIÆr'l!~Oj ('nM~¡¡W.Ùi>M o Stratigraphic Test 0 Service cr'tM.%lb'ØI1'êrWefIoI~"'YMrm/ii¡IOn 5. Bond: IBI Blanket 0 Single Well 11, Well NMiI\ø(a\ItJmber: Bond No. 2S100302630-277 PBU 5-119 / 6. Proposed Depth: 12. Field I Pool(s): MD 16213 TVD 7022 Prudhoe Bay Field 1 Aurora Pool 7, Property Designation: ADL 028256 8, Land Use Permit: 13, Approximate Spud Date: September 5, 2004 ./ 14. Distance to Nearest Property: 1275' 9. Acres in Property: 2560 Hole 42" 13-1/2" 9-7/8" Casing 20" 10-3/4" Weight 91.5# 45.5# 26# Length 80' 6545' 16189' 10, KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 60,2 feet S-107 is 1675' away 17, Maximum Anticipated Pressures in psig (see 20 MC 25.0~ Downhole: 3300 Surface: 2630 Quan (c TVD (including stage data) 110' 260 sx Arctic Set (Approx.) 3420' 993 sx AS Lite, 343 sx Class 'G' ./ 7022' 283 sx Class 'G' 7" MD TVD Surface Surface Surface Surface Surface Surface MD 110' 6569' 16213' 19. PRESENT WELL CONDITION SUMMARY (To be Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments IBI Filing Fee, $100 0 BOP Sketch a Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): IBI Drilling Program 0 Time vs Depth Plot o Seabed Report a Drilling Fluid Program o Shallow Hazard Analysis a 20 MC 25,050 Requirements Date: Contact Jim Smith, 564-5773 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Crane Title Senior Drilling Engineer Phone 564-4089 Date Permit To Drill " . ~, I API Number:, ...., .? ~.. -") -ry Permit Approval Number: 2.C57-- /.6 2_ 50- 02.? - ~ _>/-?-.k..", Date: Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required Hydrogen Sulfide Measures 0 Yes ~.No Directional Survey Required Other:T€St 7;0 PE 400Q t?$../. .' p~- 'le; r. ·ss f..k') () L cdtf2-ýYL.:~+e.. boPE fesf ~eDt.u24/Lcr ¡ $ a.fprOved. Date d~/ðlÞ þ:m0n ~'Iicate See cover letter for other requirements o Yes ~o ;gYes 0 No Approved B . Form 10-401 ORIGINAL APPROVED BY THE COMMISSION · . IWell Name: 18-119 Drill and Complete Plan Summary I Type of Well : Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: 1 Producer x = 618,930.' Y = 5,980,700' / 449~FSL, 4498'FEL,Sec.35,T12N,R12E / X = 609,900' Y = 5,990,730' 4103' FSL, 2795' FEL, Sec. 21, T12N, R12E /' 6680'TVDss X = 609,681' Y = 5,990,984' ./ 4361'FSL,3009'FEL,Sec.21,T12N,R12E I AFE Number: 1 AUD5M0069 1 I Estimated Start Date: 19/5/2004 MD:116213 I I TVD: 17022 I I I Rig: 1 Doyon 16 ~ ..._____i I Operating days to comPlete:(27J~/ ,~,.--' RT/GL: 124.0' I I RKB/MSL: 160.2 1 I Well Design (conventional, slim hole, etc.): 1 Slimhole (with 7" longstring) I Objective: 1 Single zone producer in the Kuparuk formation 9-7/8" Production Hole (6569' -16213'): Interval Density YP PV (ppg) 9.7-10.1 /\ éY Upper Interval Top of HRZ toTO Add Glycol Mud weight for the HRZ is determined from the Kingak study of 1998 Mud Program: 13 1/2" Surface Hole (0-6569'): Densitv (ppg) Initial 8.5 - 9.2 Base PF to top SV 9.2 - 9.7 SV to TO 9.7 25-30 22-30 S-119 Drilling Permit application Viscosity (seconds) 250-300 250 150-200 10-15 14-20 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ff) (mls/30min) 45 - 70 NC 35 - 45 < 8 25 -- 35 < 8 9.0-9.5 9.0- 9.5 9.0- 9.5 pH LSND 10' Gel API Filtrate 6-8 9.0--9.5 10 9.0-9.5 4-5 10 Page 1 . . Hydraulics: Suñace Hole: 13-1/2" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2500' 550-600 5" 19.5# 10.0 N/A 18,18,18,16 .942 2500' -6569' 650-700 5" 19.5# 2950 10.3 N/A 18,18,18,16 .942 Production Hole: 9-7/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 6569' - 16213' 600-650 5" 19.5# 215 4100 11.5 N/A 3x12,3x13 .720 Casing Criteria: Casing Description Burst Collapse Rating (psi) Rating (psi) 5205 2480 / 7240 5410 20" insulated conductor 10-3/4" , 45.5#, L-80, BTC 7", 26#, L-80, BTCM Di rectional: Ver. I Anadrill P4 KOP: 300' Maximum Hole Angle: Close Approach Wells: 69.6 deg at 2524' MD S-108 and S-11 0 are adjacent 15' center wells. The interval of closest approach is from 240'MD to 290'MD on the S-119. All wells pass the close approach risk assessment and may continue to flow if IFR + MS survey corrections are employed. None Logging Program: Suñace Intermediate/Production Hole Drilling: Open Hole: Drilling: Open Hole: Cased Hole: MWD 1 GR with IFR + Multi Station None Cased Hole: None MW D/GR/PWD/RES/DEN/NEU with IFR + Multi Station None S-119 Drilling Permit application Page 2 . . Formation Markers: Formation Tops MD TVDss Estimated pore pressure, PPG KOP 300 -240 KOP in Permafrost SV6 1747 -1535 Base Permafrost 2300 -1860 SV5 3067 -2140 SV4 3526 -2300 cr,7 Fault 4848 -2750 SV3 4933 -2790 SV2 5292 -2915 SV1 6282 -3260 8.6 ppg EMW 10-3/4" sfc casing 6569 -3360 ;Jo Çio <.U UG4A 7287 -3610 Non Commercial Hydrocarbons, 8.8 ppg ** UG3 8004 -3860 9.0 ppg EMW UG1 9391 -4345 9.0 ppg EMW Ugnu Ma 10243 -4640 9.2 ppg EMW Top Schrader NA 10989 -4900 8.8ppg EMW Schrader OA 11334 -5020 8.8 ppg EMW OBd 11736 -5160 CM1 (Colville) 14951 -6280 Shale THRZ 15603 NEED MUD AT 10.8 PPG FROM JUST ABOVE IO'~ -6570 THE HRZ TO TD FOR SHALE STABILITY BHRZ (Kalubik) 15689 -6625 Top Kuparuk C4 15775 target -6680 Hydrocarbon Bearing, 9.5 ppg EMW Kuparuk C3 15820 -6709 Hydrocarbon Bearing, 9.5 ppg EMW Kuparuk C2 15988 -6817 Hydrocarbon Bearing, 9.5 ppg EMW Kuparuk C1 16035 -6847 Hydrocarbon Bearing, 9.5 ppg EMW LCU (Kup B) 16063 -6865 No Hydrocarbons _ TDn" prod casing 16213 -6961 150' MD below top of Kuparuk B CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg c.D. / ./ MDITVD MDITVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 13-1/2" 1 0-3/4" 45.5# L-80 BTC 6545' GL 6569'/3420 9-7/8" 7" 26# L-80 BTC-M 16189' GL 16213'/7022' Tubing 4 %" 12.6# L-80 TC-II 15602' GL 15625/6648' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from su rface shoe Test Type LOT EMW 13.0 ppg EMW Target S-119 Drilling Permit application Page 3 . . Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 110-3/4" Surface in 13-112" hole, shoe at 6569'MD I Basis: Lead: Based on conductor set at 110', 2220' of annulus in the permafrost @ 225% excess and 3519 of open hole from top of tail slurry to base permafrost @ 30% excess. Lead roc: To surface. Plan to have TAM port collar as contingency, set at1000'MD Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -5819MD, 3160TVD .~ I Total Cement Volume: Lead 785 bbl I 4409ft~ ~I~' S rctic Set Lite Permafrost cement at 10.7 ppg ã.J].,d .' cf/sk. ~ Tail 70.9 bbl I 398 ft' @3' s õf 'G' at 15.8 ppg and~ cVsk. . Casing Size 17" Production Longstring in 9-7/8" hole I Basis: Based on TOC 500' above top of Kuparuk form~ti , ::F30% excess + 80' shoe Cement Placement: Tail from shoe at 16213' t 52 '/MD. Planned TOC at 500' above Kuparuk " ~., Total Cement Volume: I Tail 160.~.~ 340ft" j sks of gasBLOK 'G' at 15.8 ppg an~~f/sk. " Well Control: Surface hole will be drilled with a diverter. The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blindlshear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future fracture stimulation treatment, the BOP equipment will / be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3300 psi @ 6680' TVDss - Kuparuk C Sands 2630 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: required for fracture stimulation.) · Planned completion fluid: 4000 psi (The casing and tubing will be tested to 4000 psi as 8.6 ppg filtered seawater I 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 8-119 Drilling Permit application Page 4 . . DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Doyon 16. / 2. Nipple up and test the diverter. PU 5" DP as required and stand back in derrick. 3. MU 13-1/2" drilling assembly with MWD/GR and AIM to kick off at 300' and directionally drill surface hole to approximately 100' TVD below the SV1 sand at 6569'MD. An intermediate wiper/bit trip to surface will be performed after exiting the Permafrost. Motor bend can be reduced if hole angle build is adequate. 4. Run and cement the 10-3/4", 45.5# surface casing. Cement to surface, a TAM port collar should be / placed near 1 OOO'MD on this well due to the length of surface hole. // 5. ND diverter and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 9-7/8" rotary steerable drilling assembly with MWD/GR/RES/DEN/NEU & PWD, RIH to float collar. Test the 10-3/4" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below / 10-3/4" shoe and perform Leak Off Test. 8. Drill to +/-200'MD above the HRZ holding mud weight near 9.7 ppg to that depth, condition mud to 10.8 ppg for shale stability prior to reaching the HRZ. (begin Glydril additions or swap here). 9. Use the MI solids van to assist in preservation of mud properties on the entire 9-7/8" interval. ,/ Perform short trips if needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD at -150' MD below Top Kuparuk B (TD at approx. 16213'MD). 11. Condition hole for casing, spot G seal across the UGNU & Schrader sands prior to POOH. 12. POOH and lay down drillpipe. 13. Run and cement the 7" production casing in a single stage, displace cement with seawater. Planned / TOC is 500'MD above the top of the Kuparuk. 14. Freeze-protect the 7" x 10-3/4" annulus as required with heated dead crude. Record formation breakdown pressure on the Morning Report. 15. Test casing to 4000 psi for 30 minutes. /' 16. Run the 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packer within 200'MD above the top of Kuparuk after circulating heated seawater. Test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below TWC to 1000 psi. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect well by pumping diesel to upper GLM (where DCK valve is placed). Allow to equalize. 19. Rig down and move off. Perforating will be performed post-rig. / S-119 Drilling Permit application Page 5 . . 5-119 Drilling Program Job 1: MIRU Hazards and Contingencies ~ S-Pad is not designated as an H2S site. Recent well tests indicate near 8 ppm H2S concentrarrõñs as typical but S-40 had 70 ppm on 1/2000. Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest well locations are: S-108 at 15' to the north; S-110 at 15' to the south. ~ Two wells (S-108 and S-110, both producers at 15' away on either side) will require removal of the well house and a surface shut in (with pressure bleed off) during rig move in and move out. ~ Check the landing ring height on S-119 prior to rig mobilization. The BOP nipple up may need review for proper space-out prior to spud. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" ~< ....M;;...._.~~,~_, .;-".q-¡--!!'!!Wm:«!I)!O¡¡':;;', Job 2: Drillinq Surface Hole ~ There are two critical nearby wells in the surface hole. Those are the S-108 and the S-11 0 which are still 15 feet away from the planned wellpath in the interval of 250'MD to 300'MD . ~ Surveys will need to be IFR + MS corrected. ~ Gas hydrates have been observed in some wells drilled on S-Pad. These were encountered near the base of permafrost to TD which is below the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation ~ S-119 is expected to cross one fault in the surface hole, this fault is near 2750'TVDss/4818'MD in the SV4 or top of SV3. No significant problems are expected during drilling but lifting of cement to surface may only be possible using the TAM port collar. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Planned cement amount is: 225% excess cement through the permafrost zone and 30% excess below the permafrost. A 10-3/4" port collar will be positioned at ±1 OOO'MD to allow remedial cementing should cement not reach the surface on the primary cementing job. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" S-119 Drilling Permit application Page 6 . . 10-3/4",45.5#, L-80, STC 100% 80% Collapse 2480 1984 Burst 5205 4164 Tensile 1042k 833k ID 9.950" Make-up Torque To Position · Centralizers: one bow-spring type per joint first 15 joints, plus one each side of the port collar. · Reciprocate casing -10' while displacing cement, if hole allows. Report reciprocation on Morning Report if it is achieved.) Note: Check surface cement level prior to leaving well to establish if cement has slumped. Record depth tagged on Morning Report. If TOC is greater than 20' below top of conductor, notify AOGCC and perform top job at an opportune time. Note: In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial port collar cement work for possible witness of cement to surface. Review the "Surface Casing and Port Collar RP" /' Job 7: DrillinQ Production Hole Hazards and Contingencies ~ S-119 will cross two faults - in the lower OBd at - 6275'TVDss, 14,936' MD (+/- 250'), and at 6500'TVDss/15,484' in the Colville. Lost circulation or breathing is considered to be a moderate risk. Monitor ECD loading of the wellbore and Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: In the scenario of 9.7 ppg pore pressure at the Kuparuk target depth, gauge hole, a fractær ra ient of 12.0 ppg at the surface casing shoe, 10.8 ppg mud in the hole the kick tolerance i 16 bls. Contact Drilling Manager/ODE if LOT is less than 12.0 ppg due to ECD concerns w e mud weight required at the HRZ. ~ Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time many wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. ~ There is risk of hole instability during drilling of the HRZ at elevated hole angle. To combat this concern, mud weight for drilling the HRZ has been selected at 10.8 ppg as recommended in the 1998 Shale Drilling study by Sophie Dawson, et.a!. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" S-119 Drilling Permit application Page 7 . . Job 9: Case & Cement Production Hole Hazards and Contingencies );> The interval is planned to be cemented in a single stage with a 15.8 ppg slurry, and top of cement at 500' above the Kuparuk. ~ Ensure the production cement has reached at least a 70BC thickening value prior to freeze protecting the 10-3/4" by 7" annulus. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. ~ Pump approximately Y2 the volume of the 10-3/4" casing by 7" casing annulus prior to its freezing. After freeze protecting the 7" x 10-3/4" casing outer annulus with dead crude (estimated at 7.5 ppg) to 2500' MD, 2000'TVD, the hydrostatic pressure will be equal or greater to the formation pressure immediately below the shoe (assume 7.5 ppg crude above 10.8 ppg mud to shoe). To prevent pressure on the annulus pump 120 bbl of the dead crude into the annulus. );> Ensure a minimum hydrostatic equivalent of 10.8 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Loss of hole integrity and packing off have resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. );> Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition, a LCM pill composed of 10#/bbl "G Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" 7",26#, L-80, BTC-mod 100% 80% Collapse 5410 psi 4328 psi Burst 7240 psi 5792 psi Tensile 604,000 Ib 483,200 Ib ID 6.276" 6.151" drift Make-up Torque To Position . Centralization: For planning purposes, 1 per joint 7" x 8-1/4" solid centralizers (floating) from the shoe to 200' above the top of Kuparuk 1) One short jOint is required. Place it near the top of the Kuparuk. . Pressure test casing to 4000 psi on chart recorder for 30 minutes if not pressure tested during plug bump above. Plan casing test for after cement has reached a minimum 1000 psi compressive strength. Job 12: Run Completion Hazards and Contingencies );> Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalanced if there is a casing integrity problem. );> When testing annulus maintain no more than a 1500 psi differential: i.e., 2500 psi tubing pressure, 4000 psi annulus pressure to avoid premature shear of the DCK valve. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus S-119 Drilling Permit application Page 8 . . Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus Operational Specifics . ND stack. NU tree and test to 250 and 5000 psi with diesel. Test packoff to 5000 psi. Pull TWC. 8-119 Drilling Permit application Page 9 e . S-119 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 2300'MD and near the hole section TD as well. · S-30 and S-25 located on the Southern portion of the pad, reported outer annulus pressures in the past. In December 2002 S-25 was shut in. S-30 is on production however and is being monitored. The pressure does not appear to have charged up any shallow sands in the wells drilled since that time. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · Hole enlargement could lead to loss of the hole if permafrost thaw becomes excessive due to spending too long a period in the interval. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk's 9.5 pore pressure. · Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time nineteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. · S-119 will cross faults at -2750' TVDss, 6275'TVDss, and 6500'TVDss. Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S ./ · This drill-site is M! designated as an H2S drill site. Recent wells tests indicate 8 ppm H2S concentration in Kuparuk wells. Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION S-119 Drilling Permit application Page 10 TREE = WELLHEAD = ACTUA TOR = ~ ~ KB. ELEV = BF. ELEV = KOP= Max Angle = , ~.,.. 'wuw Datum MD = Datum lVO = 4-1/16" CrN FMC NA 64.3 . 8-119 ~ 300 - - =--t 1000' I 2200' H 9-5/S" TAM PORT COLLAR 1 H 4-1/2" HES X NIP, 10 = 3.S13" 1 XXX' SS 10-314" CSG, 45.5#, L-SO, BTC 1-1 6568' I~ Minimum ID = 3.750" 4-1/2" HES XN NIPPLE ---1: ST MD 5 4 3 2 2 GAS LIFT MANDRELS lVD DEV TYÆ VLV LATCH PORT 3000 3S00 5600 6400 xxxx 1 join"!bove the CMO sliding sleeve DATE 14-1/2" TBG, 12.6#, L-SO, TC-II 4-1/2' X rtPe 4-1/2' )t. rtPe ~_ -I 15535' I I 4-1/2"BKRCHDslidingsleeve Z - I 15575' H 7" X 4-1/2" BKRSB3 PKR ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: xx @ xxxx' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I \ -----i 1-1 Short Joint 1jt above top 1 KUP I PBTD H 16125' ~ I 7" CSG, 26#, L-SO, .03S3 bpf, ID = 6.276" H 16213' DATE REV BY COMMENTS OS/04/04 JES PROPOSED COMPLETION OA TE REV BY COMMENTS GPB BOREALIS WELL: S-119 ÆRMIT No: API No: BP Exploration (Alaska) 5-119 (P4) Proposal Schlumberger Report Date: July 30, 2004 Surv,y I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 318.950" Field: Prudhoe Bay Unit - WOA 07/29/04 Vertical Section Origin: N 0.000 It, E 0.000 It Structure I Slot: S-PAD I S-119 (slot 13) TVD Reference Datum: KB Well: Plan S-119 APpro TVD Reference Elevation: 60.20 It relative to MSL Borehole: Plan S-119 Sea Bed I Ground Level Elevation: 36.20 It relative to MSL UWUAPI#: 50029 Magnetic Declination: 24.979" Survey Namel Date: S-119 (P4) I July 29,2004 Total Field Strength: 57587.967 nT Tort I AHD I DDII ERD ratio: 95.449" /13891.41 It / 6.486/1.978 Magnetic Dip: 80.866" . Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 08, 2004 Location Lat/Long: N 70.35592362, W 149.03413561 Magnetic Declination Model: BGGM 2003 Location Grid N/E Y/X: N 5980699.940 ItUS, E 618930.010 ItUS North Reference: True North Grid Convergence Angle: +0.90965999" Total Corr Mag North -> True North: +24,979" Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head I Comments Measured , Inclination I Azimuth , Sub-Sea TVD , TVD Vertical , Along HOle' NS EW , DLS , Tool Face , Build Rate , Walk Rate , Northing Easting Latitude Longilude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) RTE 0.00 0.00 290.00 -60.20 0.00 0.00 0.00 0.00 0.00 0.00 -70.00M 0.00 0.00 5980699.94 618930.01 N 70.35592362 W 149.03413561 KOP Bid 1.5/100 300.00 0.00 290.00 239.80 300.00 0.00 0.00 0.00 0.00 0.00 -70.00M 0.00 0.00 5980699.94 618930.01 N 70.35592362 W 149.03413561 Bid 3.5/100 400.00 1.50 290.00 339.79 399.99 1.15 1.31 0.45 -1.23 1.50 -70.00M 1.50 0.00 5980700.37 618928.77 N 70.35592484 W 149.03414560 500.00 5,00 290.00 439.61 499.81 6.11 6.98 2.39 -6.56 3.50 -70.00M 3.50 0.00 5980702.22 618923.42 N 70.35593014 W 149.03418885 600.00 8.50 290.00 538.90 599.10 16.39 18.73 6.41 -17.60 3.50 O.OOG 3.50 0.00 5980706.07 618912.31 N 70.35594112 W 149.03427853 700.00 12.00 290.00 637.29 697.49 31.96 36.52 12.49 -34.32 3.50 O.OOG 3.50 0.00 5980711.88 618895.50 N 70.35595774 W 149.03441428 800.00 15.50 290.00 734.41 794.61 52.75 60.29 20.62 -56.65 3.50 O.OOG 3.50 0.00 5980719.66 618873.04 N 70.35597995 W 149.03459562 900.00 19.00 290.00 829.90 890.10 78.70 89.94 30,76 -84.51 3.50 O.OOG 3.50 0.00 5980729.35 618845.03 N 70.35600765 W 149.03482186 1000.00 22.50 290.00 923.40 983.60 109.69 125.36 42.88 -117.80 3.50 O.OOG 3.50 0.00 5980740.94 618811.56 N 70.35604075 W 149.03509216 1100.00 26.00 290.00 1014.56 1074.76 145.63 166.42 56.92 -156.39 3.50 O.ooG 3.50 0.00 5980754.37 618772.75 N 70.35607912 W 149.03540552 1200.00 29.50 290.00 1103.04 1163.24 186.37 212.98 72.84 -200.13 3,50 o.oOG 3.50 0.00 5980769.59 618728.76 N 70.35612261 W 149.03576075 Cry 3.5/100 1300.00 33.00 290.00 1188.52 1248.72 231.75 264.85 90.58 -248,88 3.50 43.95G 3.50 0.00 5980786.55 618679,75 N 70.35617107 W 149.036_ 1400.00 35.59 294.17 1271.14 1331.34 282.02 321.17 111.82 -301.03 3.50 40.5OG 2.59 4.17 5980806.96 618627.27 N 70.35622909 W 149.036 1500.00 38.31 297.84 1351.06 1411.26 337.38 381.27 138.22 -355.01 3.50 37.57G 2.72 3.67 5980832.50 618572.88 N 70.35630121 W 149.0370 1600.00 41.13 301.08 1427.97 1488.17 397.62 445.16 169,69 410.60 3.50 35.07G 2.82 3.24 5980863.08 618516.80 N 70.35638717 W 149.03746984 1700.00 44.04 303.98 1501.60 1561.80 462.52 512.82 206.11 467.61 3.50 32.94G 2.90 2.89 5980898.58 618459.23 N 70.35648665 W 149.03793278 SV6 1747.02 45.42 305.23 1535.00 1595.20 494.58 545.91 224.91 -494.84 3.50 32.05G 2.95 2.67 5980916.94 618431.70 N 70.35653800 W 149.03815393 1800.00 47.00 306.58 1571.66 1631.86 531.84 584.15 247.34 -525.82 3.50 31.12G 2.98 2.54 5980938.88 618400.38 N 70.35659928 W 149.03840546 1900.00 50.03 308.94 1637.90 1698.10 605.32 659.05 293.23 -585.01 3.50 29.55G 3.02 2.36 5980983.82 618340.47 N 70.35672463 W 149.03888613 2000.00 53.09 311.10 1700.07 1760.27 682.68 737.36 343.61 -644.96 3.50 28.21G 3.07 2.16 5981033.23 618279.74 N 70,35686224 W 149.03937299 I: 2100.00 56.19 313.09 1757.93 1818.13 763.64 818.91 398.28 -705.44 3.50 27.06G 3.10 1.99 5981086.94 618218.39 N 70.35701160 W 149.63986423 2200.00 59.32 314.94 1811.28 1871.48 847,89 903.47 457.06 -766.24 3.50 26.o7G 3.13 1.85 5981144.73 618156.67 N 70.35717214 W 149.04035802 2300.00 62.48 316.67 1859.91 1920.11 935.12 990.84 519.70 -827.13 3.50 25.23G 3,16 1.73 5981206.40 618094.81 N 70.35734328 W 149.04085250 Base Perm 2300.19 62.48 316.67 1860.00 1920.20 935.29 991.00 519.83 -827.24 3.50 25.23G 3.17 1.68 5981206.52 618094.69 N 70.35734361 W149.04085344 2400.00 65.65 318.31 1903.64 1963.84 1025.00 1080.75 586.00 -887.87 3.50 24.51G 3.18 1.64 5981271.72 618033.02 N 70.35752437 W 149.04134585 WellDesign Ver 3.1 RT-SP3.03-HF4.oo Bld( d031 rt-546 ) $-119 (slot 13)\Plan $-119\Plan $-119\$-119 (P4) Generated 7/30/2004 9:41 AM Page 1012 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg/100 ft) (deg) (deg/100 ft) (deg/100 ft) (ftUS) (ftUS) 2500.00 68.85 319.86 1942.31 2002.51 1117.21 1172.96 655.69 -948.25 3.50 23.91G 3.19 1.56 5981340.43 617971.55 N 70.35771473 W 149.04183622 End Crv 2523.93 69.61 320.23 1950.80 2011.00 1139.58 1195.33 672.84 -962.62 3.50 O.OOG 3.20 1.51 5981357.35 617956.92 N 70.35776157 W 149.04195291 SV5 3067.02 69.61 320.23 2140.00 2200.20 1648.52 1704.40 1064.10 -1288.30 0.00 O.OOG 0.00 0.00 5981743.36 617625.10 N 70.35883033 W 149.04459826 SV4 3526.29 69.61 320.23 2300.00 2360.20 2078.91 2134.90 1394.97 -1563.71 0.00 O.OOG 0.00 0.00 5982069.79 617344.49 N 70.35973410 W 149.04683553 Fault Crossing 4817.99 69.61 320.23 2750.00 2810.20 3289.39 3345.68 2325.55 -2338.31 0.00 O.OOG 0.00 0.00 5982987.88 616555.28 N 70.36227580 W 149.05312893 SV3 4932.80 69.61 320.23 2790.00 2850.20 3396.99 3453.30 2408.27 -2407.16 0.00 O.OOG 0.00 0.00 5983069.48 616485.13 N 70.36250172 W 149.05368842 SV2 5291.61 69.61 320.23 2915.00 2975.20 3733.23 3789.63 2666.76 -2622.33 0.00 O.OOG 0.00 0.00 5983324.51 616265.91 N 70.36320770 W 149.05543690 SV1 6281.91 69.61 320.23 3260.00 3320.20 4661.26 4717.89 3380.20 -3216.19 0.00 O.OOG 0.00 0.00 5984028.37 615660.85 N 70.36515613 W 149.06026333 10-314" Csg pt 6568.95 69.61 320.23 3360.00 3420.20 4930.26 4986.95 3587.00 -3388.32 0.00 O.OOG 0.00 0.00 5984232.39 615485.47 N 70.36572087 W 149.06166247 UG4 7171.75 69.61 320.23 3570.00 3630.20 5495. 14 5551.98 4021.27 -3749.80 0.00 O.OOG 0.00 0.00 5984660.83 615117.17 N 70.36690679 W 149.06460091 UG4A 7286.56 69.61 320.23 3610.00 3670.20 5602.74 5659.61 4103.99 -3818.65 0.00 O.OOG 0.00 0.00 5984742.44 615047.02 N 70.36713267 W 149.065_ UG3 8004.17 69.61 320.23 3860.00 3920.20 6275.23 6332.26 4620.98 -4248.98 0.00 O.OOG 0.00 0.00 5985252.49 614608.57 N 70.36854440 W 149.0686 UG1 9390.59 69.61 320.23 4343.00 4403.20 7574.47 7631.83 5619.80 -5080.39 0.00 O.OOG 0.00 0.00 5986237.90 613761.49 N 70.37127168 W 149.07542011 Ma 10243.11 69.61 320.23 4640.00 4700.20 8373.39 8430.94 6233.98 -5591.62 0.00 O.OOG 0.00 0.00 5986843.83 613240.61 N 70.37294857 W 149.07957826 Na 10989.43 69.61 320.23 4900.00 4960.20 9072.78 9130.50 6771.65 -6039.17 0.00 O.OOG 0.00 0.00 5987374.28 612784.63 N 70.37441648 W 149.08321896 OA 11333.88 69.61 320.23 5020.00 5080.20 9395.57 9453.38 7019.80 -6245,73 0.00 O.OOG 0.00 0.00 5987619.11 612574.17 N 70.37509395 W 149.08489945 OBd 11735.74 69.61 320.23 5160.00 5220.20 9772.16 9830.06 7309.32 -6486.71 0.00 O.OOG 0.00 0.00 5987904.73 612328.64 N 70.37588432 W 149.08686017 Fault Crossing 14936.28 69.61 320.23 6275.00 6335.20 12771.45 12830.10 9615.08 -8406.00 0.00 O.OOG 0.00 0.00 5990179.54 610373.16 N 70.38217824 W 149.10248131 CM1 14950.63 69.61 320.23 6280.00 6340.20 12784.90 12843.55 9625.42 -8414.60 0.00 O.OOG 0.00 0.00 5990189.75 610364.39 N 70.38220646 W 149.10255138 Drp 4i100 15154.59 69.61 320.23 6351.06 6411.26 12976.04 13034.73 9772,36 -8536.91 0.00 180.00G 0.00 0.00 5990334.71 610239.77 N 70.38260751 W 149.10354719 15200.00 67.80 320.23 6367.55 6427.75 13018.33 13077.04 9804.88 -8563.98 4.00 180.00G -4.00 0.00 5990366.79 610212.20 N 70.38269626 W 149.10376756 15300.00 63.80 320.23 6408.54 6468.74 13109.50 13168.23 9874.97 -8622.32 4.00 180.00G -4.00 0.00 5990435.94 610152.76 N 70.38288755 W 149.10424255 15400.00 59.80 320.23 6455.79 6515.99 13197.59 13256.34 9942.69 -8678.68 4.00 180.00G -4.00 0.00 5990502.75 610095.33 N 70.38307237 W 149.10470150 Fauilt Crossing 15483.72 56.45 320.23 6500.00 6560.20 13268.65 13327.42 9997.32 -8724.16 4.00 180.00G -4.00 0.00 5990556.65 610049.00 N 70.38322148 W 149.10507177 15500.00 55.80 320.23 6509.07 6569.27 13282.16 13340.94 10007.71 -8732.80 4.00 180.00G -4.00 0.00 5990566.90 610040.19 N 70.38324983 W 149.10514216 15600.00 51.80 320.23 6568.13 6628.33 13362.82 13421.61 10069.72 -8784.41 4.00 180.00G -4.00 0.00 5990628.07 609987.61 N 70.38341907 W 149.10556239 Top HRZ 15603.02 51.67 320.23 6570.00 6630.20 13365.19 13423.98 10071.54 -8785.93 4.00 180.00G -4.00 0.00 5990629.87 609986.06 N 70.38342404 W 149.10557474 End Drp 15644.89 50.00 320.23 6596.44 6656.64 13397.64 13456.44 10096.49 -8806.69 4.00 O.OOG -4.00 0.00 5990654.48 609964.90 N 70.38349213 W 149,10574382 Base HRZ 1 Ka/ubik 15689.32 50.00 320.23 6625.00 6685.20 13431.67 13490.48 10122.65 -8828.47 0.00 O.OOG 0.00 0.00 5990680.30 609942.72 N 70.38356354 W 149.10592112 S-119Tgt 15774.89 50.00 320.23 6680.00 6740.20 13497.20 13556.03 10173.03 -8870.40 0.00 O.OOG 0.00 0.00 5990730.00 609900.00 N 70.38370104 W 149.10626255 Top KUP 1 C4 15774.90 50.00 320.23 6680.01 6740.21 13497.21 13556.04 10173.04 -8870.41 0.00 O.OOG 0.00 0.00 5990730.01 609899.99 N 70.38370106 W149.1062. Kup C3 15820.00 50.00 320.23 6709.00 6769.20 13531.75 13590.59 10199.59 -8892.51 0.00 O.OOG 0.00 0.00 5990756.21 609877.47 N 70.38377354 W 149.10644 Kup C2 15988.02 50.00 320.23 6817.00 6877.20 13660.43 13719.30 10298.52 -8974.85 0.00 O.OOG 0.00 0.00 5990853.81 609793.58 N 70.38404353 W 149.10711304 OWC 16016.02 50.00 320.23 6835.00 6895.20 13681.88 13740.75 10315.01 -8988.57 0.00 O.OOG 0.00 0.00 5990870.08 609779.60 N 70.38408853 W 149.10722478 Kup C1 16034.69 50.00 320.23 6847.00 6907.20 13696.18 13755.05 10326.00 -8997.72 0.00 O.OOG 0.00 0.00 5990880.92 609770.28 N 70.38411853 W 149.10729928 16062.69 50.00 320.23 6865.00 6925.20 13717.62 13776.50 10342.49 -9011.44 0.00 O.OOG 0.00 0.00 5990897.19 609756.30 N 70.38416353 W 149.10741103 LCUIKupB 16062.71 ,/,50.00 320.23 6865.01 6925.21 }!!,17.63 13776.51 10342.50 -9011.45 0.00 O.OOG 0.00 0.00 5990897.20 609756.29 N 70.38416355 W 149.10741109 TD / 7" Csg 16212.69 50.00 320.23 6961.42 7021.62 13832.50 13891.41 10430.81 -9084.95 0.00 O.OOG 0.00 0.00 5990984.32 609681.41 N 70.38440457 W 149,10800961 Leqal Description: Northina (YI [nUS] Eastinq (XI [nus] Surface: 4496 FSL 4498 FEL S35 T12N R12E UM 5980699.94 618930.01 5-119 Tgt: 4103 FSL 2795 FEL S21 T12N R12E UM 5990730.00 609900.00 BHL: 4361 FSL 3009 FEL S21 T12N R12E UM 5990984.32 609681 .41 WellDesign Ver 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) S-119 (slot 13)\Plan S-119\Plan S-119\S-119 (P4) Generated 7/30/2004 9:41 AM Page 2 of 2 £ 0 0 '" ~ 3200 §: ~ II Q) ~ C/) c ~ 4800 Schlumberuer WELL STRUCTURE 5-PAD FIELD Prudhoe Bay Unit - WOA 5-119 (P4) MagnaticParamaters Model: BGGM 2003 I SurfaœLocation Data: $eptember08,2004 lat: N702121.325 FS: 57588.0nT Lon: W14922.888 TVD Ref: KB (60.20 ft above MSl) Srvy Date: July 30, 2004 NAD27 AlaSka State Planes, Zone 04, US Feet Northing: 5980699.94ftUS GridConv: +0.90965999" EastIng: 618930.01 ftUS Scale Fact: 0.9999160676 Miscellaneous Slot: S_119 (slot 13) Plan: 5-119(P4) Dip: 80.866" MagDeC: +24.979' o 1600 3200 4800 6400 8000 9600 11200 12800 o j RTE _KOP Bid 1.51100 -Bid 3.51100 ~~..,. } nd Cry ~..- / - ,-~- . . - , .. ... n_ y...__..~_'_' ~ "......... ~ J "-""""" / s,:- ~ ''''''4........ ~~ """'-... ......... ............ ~ ~ Drp: ~/100 \ J"d Drp . .._ _. _. S.:)."-~T.p.t. .. <t .:I:~::~::~:: ·:;~;-:~ì=~; " , L<';U/"UP,:~· TD 17" Csg . o 1600 1600 3200 4800 . 6400 6400 o 1600 3200 4800 6400 8000 9600 Vertical Section (ft) Azim = 318.95°, Scale = 1 (in):1600(ft) Origin = 0 N/-S. 0 E/-W 11200 12800 ^ ^ ^ 6000 6000 z =- Õ 0 LO ~ g ~ II Q) 4500 4500 Iii <> C/) C/) v v v 3000 3000 I WEll 5-119 (P4) '" "",,,,P.._le. Model: BGGM 2003 10500 . . Schlumberger FIELD STRueTI)RE 5-PAD Prudhoe Bay Unit - WOA Dip: 80.866' MagDec; +24.979" I SuñaœLocation Date: September 08, 2004 lat: N70 21 21.325 FS: 57588.00T Loo: W14922.888 TVD Ref: KB (60.20 ft above MSl) SrvyDate: JuIyJO,2004 NAD27 Alaska State PlanllS, Zone 04, US Feet Northing" 5980699.94f1US GridConv; +0.90965999' Easting: 618930.01 flUS Scale Fact: 0.9999160676 MisceHanaous Slot: S-119 (slot 13) Plan: S-119(P4) -9000 -1500 o -7500 -6000 -4500 -3000 9000 7500 10500 9000 \ ¡~ ~1)1,¡,'",.""""."""",,'¡/ ~!" 7500 1500 o 1500 o Cry 3.51100 RTE -9000 -1500 o -7500 -6000 -4500 -3000 «< W Scale = 1(in):1500(ft) E >>> . . Oilfield Services, Alaska Schlumberger Drilling & Measurements SclllumllBpll8P 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Friday, July 30, 2004 Jim Smith Prudhoe Bay 5-119 (P4) BP Exploration Alaska Doyon 16 Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Proqram: Instrument Type MWD MWD + IFR + MS Start Depth 24.00'md 1,400.00'md End Depth 1,400.00'md 16,212.69'md Close Approach Analvsis results: Under method (2), all wells may flow. / All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillinq Aids to be provided: A drilling map and a traveling cylinder, will be provided. Checked by: Scott Delapp 07/30/04 . Schlumberger Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 24.00 to 16212.69 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM 18CW8A Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/17/2001 Validated: No Planned From To Survey ft ft 24.00 1400.00 Planned: Plan #4 V1 24.00 16212.69 Planned: Plan #4 V1 Version: 3 Toolcode Tool Name MWD MWD+IFR+M8 MWD - Standard MWD + IFR + Multi 8tation Casing Points 6568.95 3420.20 16212.69 7021.62 10.750 7.000 13.500 8.750 103/4" 7" Summary PB S Pad Plan S-111 Plan 5-111 V5 Plan: PI 496.59 500.00 29.93 8.82 21.11 Pass: Major Risk PB 8 Pad Plan 8-123 Plan S-123 V5 Plan: PI 383.89 400.00 1022.55 6.89 1015.66 Pass: Major Risk PB 8 Pad Plan S-203 Plan 8-203 (East) V3 P 468.15 500.00 1328.23 9.72 1318.51 Pass: Major Risk PB 8 Pad Plan 8-203 Plan 8-203 (West) V5 P 468.16 500.00 1327.54 7.93 1319.61 Pass: Major Risk PB 8 Pad Plan 8-208 Plan 8-208 VO Plan: S- 367.42 400.00 1612.25 8.09 1604.16 Pass: Major Risk PB 8 Pad Plan S-214 Plan 8-214 V1 Plan: 8- 393.18 400.00 165.64 6.59 159.05 Pass: Major Risk PB S Pad 8-01A 8-01A V1 293.78 300,00 849.98 7.98 842.01 Pass: Major Risk PB 8 Pad 8-01 B S-01 B V1 289.91 300.00 849.95 7.90 842.05 Pass: Major Risk PB S Pad 8-01 8-01 V1 474.49 500.00 848.26 11.32 836.94 Pass: Major Risk PB S Pad 8-02APB1 8-02APB1 V1 339.77 350.00 853.07 6.61 846.46 Pass: Major Risk PB 8 Pad 8-02A 8-02A V1 339.77 350.00 853.07 6.61 846.46 Pass: Major Risk PB 8 Pad S-02 8-02 V1 338.63 350.00 853.06 6.59 846.47 Pass: Major Risk PB 8 Pad 8-03 S-03 V1 338.32 350.00 873.32 6.06 867.26 Pass: Major Risk PB 8 Pad 8-04 S-04 V1 415.61 450.00 901.78 7.93 893.86 Pass: Major Risk PB 8 Pad 8-05APB1 8-05APB1 V1 378.13 400.00 948.85 9.65 939.20 Pass: Major Risk PB 8 Pad 8-05A 8-05A V1 378.13 400.00 948.85 9.65 939.20 Pass: Major Risk PB 8 Pad S-05 S-05 V1 372.73 400.00 948.75 9.54 939.21 Pass: Major Risk PB S Pad 8-06 8-06 V1 335,03 350.00 1003.27 6.07 997.20 Pass: Major Risk PB 8 Pad 8-07A 8-07 A V1 375.39 400.00 1064.04 7.20 1056.84 Pass: Major Risk PB 8 Pad 8-07 8-07 V1 375.39 400.00 1064.04 7.20 1056.84 Pass: Major Risk PB 8 Pad 8-08 8-08 V1 333.78 350.00 1136.19 8.77 1127.42 Pass: Major Risk PB 8 Pad 8-08 8-08A V2 333.78 350.00 1136.19 8.77 1127.42 Pass: Major Risk PB 8 Pad 8-08 8-08B V3 333.78 350.00 1136.19 8.77 1127.42 Pass: Major Risk PB 8 Pad 8-09 8-09 V1 333.56 350.00 1213.42 6.96 1206.46 Pass: Major Risk PB 8 Pad 8-100 8-100 V10 739.10 750.00 56.58 13.17 43.41 Pass: Major Risk PB 8 Pad 8-101 8-101 V3 195.78 200.00 77.01 4.69 72.32 Pass: Major Risk PB 8 Pad 8-101 8-101PB1 V9 195.78 200.00 77.01 4.69 72.32 Pass: Major Risk PB 8 Pad 8-102 8-102V11 494.28 500.00 36.44 . 8.80 27.64 Pass: Major Risk PB 8 Pad 8-102 8-102L1 V5 494.28 500.00 36,44 8.80 27.64 Pass: Major Risk PB 8 Pad 8-102 8-102L 1PB1 V7 494.28 500.00 36.44 8.80 27.64 Pass: Major Risk PB 8 Pad 8-102 8-102PB1 V14 494.28 500.00 36.44 8.80 27.64 Pass: Major Risk PB 8 Pad 8-103 8-103 V6 646.23 650.00 74.27 10.30 63.96 Pass: Major Risk PB 8 Pad 8-104 8-104V1 346.28 350.00 150.68 6.62 144.06 Pass: Major Risk PB 8 Pad 8-105 8-105 V5 747.45 750.00 135.45 12.99 122.46 Pass: Major Risk PB 8 Pad 8-106 8-106 V2 289.99 300.00 107.01 6.40 100.61 Pass: Major Risk PB 8 Pad 8-106 8-106PB1 V12 289.99 300.00 107.01 6.36 100.65 Pass: Major Risk PB 8 Pad 8-107 8-107 V36 593.37 600.00 61.88 11.63 50.26 Pass: Major Risk PB 8 Pad 8-108 5-108 V6 239.81 250.00 15.47. 4.58 10.89 Pass: Major Risk PB 8 Pad 8-109 8-109 V8 296.05 300.00 30,09 5.03 25.05 Pass: Major Risk PB 8 Pad 8-109 S-109PB1 V2 296.05 300.00 30.09 5.03 25.05 Pass: Major Risk PB 8 Pad 8-10APB1 8-10APB1 V1 370.46 399.96 1292.66 7.19 1285.48 Pass: Major Risk PB 8 Pad 8-10A 8-10A V1 370.49 400.00 1292.66 7.12 1285.54 Pass: Major Risk PB 8 Pad 8-10 8-10 V1 370.46 399.96 1292.66 7.19 1285.48 Pass: Major Risk . Schlumberger Anticollision Report . Summary PB 5 Pad 5-110 5-110V18 290.60 300.00 17.52 6.27 11.25 Pass: Major Risk PB S Pad 5-112 5-112V20 437.41 450.00 169.19 8.44 160.75 Pass: Major Risk PB 5 Pad 5-113 5-113 V14 940.67 950.00 25.02 19.96 5.06 Pass: Major Risk PB 5 Pad 5-113 5-113A V3 940.67 950.00 25.02 19.81 5.22 Pass: Major Risk PB S Pad 5-113 5-113B V6 940.67 950.00 25.02 19.81 5.22 Pass: Major Risk PB 5 Pad 5-114 5-114V13 1853.54 1850.00 72.30 35.09 37.22 Pass: Major Risk PB S Pad 5-114 5-114A V6 1853.54 1850.00 72.30 34.93 37.37 Pass: Major Risk PB 5 Pad 5-115 5-115 5T V1 Plan: Plan 296.05 300.00 91.90 5.52 86.38 Pass: Major Risk PB 5 Pad 5-115 5-115V7 296.05 300.00 91.90 5.43 86.48 Pass: Major Risk PB 5 Pad 5-116 S-116 V6 394.02 400.00 226.10 6.56 219.53 Pass: Major Risk PB 5 Pad 5-117 5-117 V4 394.81 400.00 121.07 7.02 114.06 Pass: Major Risk PB 5 Pad 5-118 5-118 V5 394.56 400.00 210.89 6.53 204.36 Pass: Major Risk PB S Pad 5-11 5-11 V4 368.90 400.00 1375.91 7.90 1368.01 Pass: Major Risk PB 5 Pad 5-11 5-11A V1 369.57 400.00 1375.92 7.92 1368.01 Pass: Major Risk PB 5 Pad 5-11 5-11BV1 369.94 400.00 1375.93 7.93 1368.01 Pass: Major Risk PB 5 Pad 5-120 S-120 V4 394.79 400.00 136.84 7.26 129.59 Pass: Major Risk PB 5 Pad S-12A 5-12A V1 327.24 350.00 1458.91 7.89 1451.01 Pass: Major Risk PB 5 Pad 5-12 5-12 V1 93.07 100.00 1466.16 2.29 1463.87 Pass: Major Risk PB S Pad 5-13 5-13 V1 330.52 350.00 1557.43 6.34 1551.09 Pass: Major Risk PB 5 Pad 5-14 Plan#3 S-14A VO Plan: 400.00 450.00 1651.75 13.15 1638.60 Pass: Major Risk PB 5 Pad 5-14 5-14 V5 400,00 450.00 1651.75 13.04 1638.71 Pass: Major Risk PB 5 Pad 5-15 S-15 V2 383.78 400.04 1203.60 9.43 1194.17 Pass: Major Risk PB 5 Pad 5-16 5-16 V1 339.11 350.00 1310.77 6.68 1304.08 Pass: Major Risk PB 5 Pad 5-17 5-17 V1 425.13 450.00 1423.95 9.23 1414.72 Pass: Major Risk PB 5 Pad 5-17 5-17A V1 425.13 450.00 1423.95 9.23 1414.72 Pass: Major Risk PB 5 Pad S-17 5-17AL 1 V1 425.13 450.00 1423.95 9.23 1414.72 Pass: Major Risk PB 5 Pad 5-17 5-17APB1 V1 425.13 450.00 1423.95 9.23 1414.72 Pass: Major Risk PB 5 Pad 5-17 5-17B V1 425.13 450.00 1423.95 9.23 1414.72 Pass: Major Risk PB 5 Pad S-17 5-17C V1 425.13 450.00 1423.95 9.12 1414.83 Pass: Major Risk PB S Pad 5-17 5-17CPB1 V2 425.13 450.00 1423.95 9.12 1414.83 Pass: Major Risk PB S Pad 5-17 S-17CPB2 V1 425.13 450.00 1423.95 9.12 1414.83 Pass: Major Risk PB 5 Pad 5-18 5-18 V1 417.86 450.00 1532.88 7.43 1525.45 Pass: Major Risk PB S Pad 5-18 S-18A V16 420.20 450.00 1532.93 7.32 1525.61 Pass: Major Risk PB 5 Pad 5-19 5-19 V1 425.36 450.00 846.88 8.80 838.07 Pass: Major Risk PB 5 Pad 5-200PB1 5-200PB1 V4 441.24 450.00 196.40 7.13 189.26 Pass: Major Risk PB 5 Pad S-200 5-200 V2 441.24 450.00 196.40 7.24 189.16 Pass: Major Risk PB S Pad 5-201 5-201 V2 245.78 250.00 90.40 4.44 85.96 Pass: Major Risk PB 5 Pad S-201 5-201 PB1 V11 245.78 250.00 90.40 4.39 86.00 Pass: Major Risk PB 5 Pad 5-20 5-20 V4 380.94 399.99 856.92 7.10 849.82 Pass: Major Risk PB S Pad S-20 S-20A V2 380.94 399.99 856.92 7.10 849.82 Pass: Major Risk PB 5 Pad 5-213 Plan 5-213A OBb V3 Pia 399.01 400.00 151.36 6.31 145.06 Pass: Major Risk PB S Pad 5-213 Plan 5-213AL1 OBcV4 P 399.01 400.00 151.36 6.41 144.95 Pass: Major Risk PB 5 Pad 5-213 Plan 5-213AL2 OBd V2 P 399.01 400.00 151.36 6.41 144.95 Pass: Major Risk PB 5 Pad 5-213 Plan 5-213AL3 OBa V1 P 399.01 400.00 151.36 6.41 144.95 Pass: Major Risk PB 5 Pad 5-213 Plan 5-213AL4 OA V2 PI 399.01 400.00 151.36 6.41 144.95 Pass: Major Risk PB 5 Pad 5-213 5-213 V6 394.57 400.00 151.29 6.24 145.05 Pass: Major Risk PB 5 Pad 5-215 5-215 V9 464.05 500.00 1226.00 8.83 1217.17 Pass: Major Risk PB 5 Pad 5-216 5-216 V2 344.89 350.00 180.84 7.15 173.69 Pass: Major Risk PB 5 Pad 5-21 5-21 V1 384.35 400.00 880.31 7.06 873.25 Pass: Major Risk PB 5 Pad 5-22A 5-22A V1 388.65 400.00 845.97 6.99 838.98 Pass: Major Risk PB 5 Pad 5-22B 5-22B V2 388.65 400.00 845.97 7.10 838.87 Pass: Major Risk PB 5 Pad 5-22 5-22 V1 388.65 400.00 845.97 6.99 838.98 Pass: Major Risk PB 5 Pad 5-23 5-23 V1 341.77 350.00 863.96 6.16 857.80 Pass: Major Risk PB 5 Pad 5-24 5-24 V5 382.22 400.00 892.04 6.91 885.13 Pass: Major Risk PB 5 Pad 5-24 S-24A V1 384.39 400.00 892.08 6.97 885.11 Pass: Major Risk PB 5 Pad S-24 5-24B V2 384.39 400.00 892.08 6.97 885.11 Pass: Major Risk PB 5 Pad 5-25APB1 S-25APB 1 V2 457.00 500.00 914.06 10.78 903.28 Pass: Major Risk PB 5 Pad 5-25A 5-25A V1 381.42 400.00 916.74 6.75 910.00 Pass: Major Risk PB 5 Pad 5-25 5-25 V1 381.42 400.00 916.74 6.75 910.00 Pass: Major Risk PB 5 Pad S-26 5-26 V1 338.57 350.00 932.13 5.43 926.70 Pass: Major Risk PB S Pad 5-27 5-27 V1 380.63 400.00 965.31 6.89 958.42 Pass: Major Risk PB 5 Pad S-27 S-27 A V3 380.63 400.00 965.31 6.78 958.53 Pass: Major Risk PB 5 Pad 5-27 5-27B V7 379.93 400.00 965.30 6.61 958.69 Pass: Major Risk . Schlumberger Anticollision Report . Summary PB S Pad 8-28 8-28 V4 337.89 350.00 983.22 6.64 976.58 Pass: Major Risk PB 8 Pad 8-28 8-28A V1 337.89 350.00 983.22 6.64 976.58 Pass: Major Risk PB 8 Pad 8-28 S-28B V2 338.89 350.00 983.23 6.65 976.58 Pass: Major Risk PB 8 Pad 8-28 8-28BPB 1 V7 338.89 350.00 983.23 6.65 976.58 Pass: Major Risk PB 8 Pad 8-29AL 1 8-29AL 1 V1 333.13 350.00 1159.43 6.59 1152.84 Pass: Major Risk PB S Pad 8-29A Plan 8-29AL2 VO Plan: 336.24 350.00 1159.47 6.46 1153.01 Pass: Major Risk PB 8 Pad 8-29A 8-29A V1 333.13 350.00 1159.43 6.59 1152.84 Pass: Major Risk PB 8 Pad 8-29 Plan 8-29B V1 Plan: S- 336.24 350.00 1159.47 6.56 1152.92 Pass: Major Risk PB 8 Pad 8-29 8-29 V1 333.13 350.00 1159.43 6.59 1152.84 Pass: Major Risk PB S Pad S-30 8-30 V1 337.85 350.00 1044.38 6.11 1038.26 Pass: Major Risk PB 8 Pad 8-31A 8-31A V3 335.21 350.00 1086.20 5.97 1080.23 Pass: Major Risk PB 8 Pad 8-31 S-31 V1 335.21 350.00 1086.20 5.97 1080.23 Pass: Major Risk PB 8 Pad 8-32 8-32 V1 334.99 350.00 1263.50 8.18 1255.32 Pass: Major Risk PB 8 Pad 8-33 S-33 V1 332.95 350.00 1110.20 5.70 1104.50 Pass: Major Risk PB S Pad 8-34 8-34 V1 330.07 350.00 1321.43 5.67 1315.76 Pass: Major Risk PB 8 Pad 8-35 S-35 V1 331.87 350.00 1348.94 5.49 1343.45 Pass: Major Risk PB 8 Pad S-36 8-36 V1 330.29 350.00 1405.15 5.58 1399.57 Pass: Major Risk PB S Pad 8-37 8-37 V1 330.11 350.00 1431.45 5.51 1425.94 Pass: Major Risk PB 8 Pad 8-38 8-38 V1 331.95 350.00 1236,74 5.47 1231.27 Pass: Major Risk PB 8 Pad 8-40A 8-40A V1 383.32 400.00 1455.99 6.14 1449.85 Pass: Major Risk PB 8 Pad 8-40 8-40 V1 383.32 400.00 1455.99 6.14 1449.85 Pass: Major Risk PB S Pad 8-41 L 1 S-41L1 V1 432.18 450.00 345.17 6.73 338.44 Pass: Major Risk PB 8 Pad 8-41PB1 8-41PB1 V1 432.18 450.00 345.17 6.73 338.44 Pass: Major Risk PB S Pad 8-41 8-41 V1 432.18 450.00 345.17 6.73 338.44 Pass: Major Risk PB 8 Pad 8-42PB 1 8-42PB1 V1 432,18 450.00 316.53 7.48 309.05 Pass: Major Risk PB S Pad 8-42 S-42 V2 432.18 450.00 316.53 7.48 309.05 Pass: Major Risk PB 8 Pad 8-43L 1 S-43L 1 V2 484.73 500.00 283.14 8.16 274.98 Pass: Major Risk PB 8 Pad 8-43 8-43 V3 484.73 500.00 283.14 8.11 275.03 Pass: Major Risk PB 8 Pad 8-44L 1PB1 S-44L1PB1 V3 439.69 450.00 254.84 6.88 247.95 Pass: Major Risk PB 8 Pad S-44L 1 S-44L 1 V5 439.69 450.00 254.84 6.84 248.00 Pass: Major Risk PB S Pad 8-44 8-44 V10 439.69 450.00 254.84 6.84 248.00 Pass: Major Risk . S-PAD N 1100-' N1010 ~ m ~ ~ í í VJ VJ ....!!==,-; =-=, .... ~~;~~ª~2 ~ ~~~85~ I I I I I I I I I IIIIII ~~~~~~ø~ ~ ~~~oooooo o N I VJ : ~=' .... ~~~~ I I I I I (I) (/)00 v)(n -- , ~ ~ ~ ~ I I I I (/) (f) (f) (/) N840- I - y~ I- ö:: C> Z ¡::: (f) X w '" to ~ LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR ,- f- Z «: ..J c.. -~- I WELLS S-111. S-119 & S-120 RENAME NOTE THIS AS-BUILT DRAWING IS A REISSUE OF PREVIOUS AS-BUILT DRAWINGS FOR WELLS S-III, S-119 AND S-120. S-111 WAS PREVIOUSLY ISSUED AS SLOT 15 ON JUNE 17, 2002. S-119 WAS PREVIOUSLY ISSUED AS SLOT 13 ON DECEMBER 31, 2001, S-120 WAS PREVIOUSLY SHOWN AS S-116, REISSUED AS SLOT 4 AND ORIGINALLY ISSUED AS WELL S-103 ON JULY 4, 2000, NOTES: 1. DATE OF SURVEYS: (S-120 JULY 2, 2000) (S-119 JANUARY 31, 2001) (S-111 JUNE 15, 2002) 2, REFERENCE FIELD BOOKS: (S-120 WoOO-06 PGS, 1-4) (S-119 Wo01-05 PGS. 33-37) (S-111 Wo02-08 Pg. 7) 3, COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0,9999165. 6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTA TION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM, . 27 26 25 S PAD jJ :;0 . 34 36 3 T.12N. T.11N. 2 '-- VICINITY MAP N,T.S. ~N~ Ow -1-1 O::J ~O 20 «::::;: ::::;: SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 2, 2000. LOCATED WITHIN PROTRACTED SEC, 35, T. 12 N" R. 12 E" UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO, COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS S-111 Y=5,980,730,34 N, 1010.61 70'21'21.624" 70.3560067" 356' 4,527' FSL X= 618.930.49 E. 124,60 149'02'02.860" 149.0341278' , 4.497' FEL S-119 Y=5,980,699,94 N. 1,010,12 70'21'21.325" 70.3559236' 36.2' 4,497' FSL X= 618,930.01 E. 155,00 149'02'02.888" 149.0341356' 4.498' FEL S-120 Y=5,980,564,33 N. 1,010.27 70'21'19.991" 70.3555531' 35,8' 4,361' FSL X= 618,930,21 E. 290.63 149'02'02,945" 149,0341515' 4,500' FEL ~Ob' ORA 'WN: Obp JJC CHECKED: LOH DATE: DRAWING; SHEET: FRB03 WOA-S 02-00 WOA S-PAD 1 cn~[}J[~o JOB NO: SCALE: RENAMED AS-BUILT CONDUCTORS 1 OF 1 OIQNEUS AAIO lAfIO SURYEVDRS WELL S-111, 5-119 & S-120 JJC LOH 801\1£51 FlR£\I£[1} \..ANE 1'= 150' BY CHK N<CHORAGE, AlASKA 99503 o 11/02/03 ISSUED FOR INFORMA "ON NO. DATE REVISION TERRIE L HUBBLE 89-611252 13B BP EXPLORATION AK 'Ne "Mastercard Check" PO BoX 196612 MB7-5 rro /)( I 0 ANCHORAGe, AK 99519-6612 DArr 1/ ð - oC, _ <.¡ ~fE~t~%~cc: $/œ':LÂR~- ~rst~~nal Bank Alaska :::"Š~KI '"9' Y~òf fi~ . .: ~ 25 WOO bO.: <¡ <¡ ".w b 2 2 7'" ~ 5 5 bl~ 0 HB . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /11 Cf S-//7" PTD# ~091_/C2 ~ Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE"· Tbe permit is for a new we1lbore segment of existing well, . Permit No, .' API No. Production. sbould continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be clearly differentiated 'in botb name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for we1l (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception that may occur. AU dry ditch sampJe sets submitted to tbe Commission must be in no greater than 30' sampJe intervals from beJow tbe permafrost or from where sampJes are first caught and 10' sampJe inter:vaJs through target zones. Field & Pool PRUDHOE BAY, AURORA OIL - 640120 Well Name PRUDHOE BAY UN AURO S-119 Program DEV Well bore seg 0 ~--* ~ PTD#: 2041620 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV /1-0IL GeoArea Unit On/Off Shore On Annular Disposal Administration 1 P~rmil fee attached, , - - - - - - - - - - - - - - - - - - - - - - ,_, _'' Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 leéi!s~ _number ,appropriale _ _ . _ _ _ _ - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 ,U,nlque well,n,a(T1~,aod o\tmb~r , , ' , ' , , ' , , , , ' , ' , , , , ' . .","", ,Y~s - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - . - - -- - - - - - - - -- 4 WeU Jocat~d ina defined pool_ - - - - - - - - - - - - - - - - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 5 WellJocat~d proper distance from driJling unilb,ound_ary_ , - - - - - Y~s - - - - - -- - - - - - - - - - - - -- - - - - - 6 We.lIJQCat~ prpper øistance_ from other w~lIs _ _ _ , _ _ - - - _, Y~s - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - 7 _Sutficient.acreage,aYailable in,dJilIiog unjL ' , , , , , , ' , , , _ _ . . , - - - , , - , ,Y~s ' The Aurora OiJ pool ha_sa4_0,acr~,spéi!cjn9. S-1 19, wiIJ be the third .A.uror.apool producer inse~t.Z1 T12N R12E 8 Jtd~viated, js_ we.llbore plç¡linclu,ded _ _ _ _ ' , _ - - - - - - - - . ,,_ - - - - - - Y~s - - - - - - - - - - - - - 9 ,Oper_ator ol1l~ éi!ff~cted party, _ _ _ _ _ _ _ _ ' , - , , - , - - - - - , _" - - Y~s - - - - - - - - - - - - - -- 10 ,Operator has,appropriate,b.ond inJorce , , _ , , , , , , ' , , , , , . ."""" Y~$ - - - - - - - - - - - - - - - - - - - - - - - -- 11 P~rmil c.an be issued wjthout CO,nserva,tiOI1 order _ _ _ - - - - - - . - - - , , ,Y~s - - - - - - - - - - - - - - Appr Date 12 _P~rmil c.ao be iss\ted without ad,mini$trati'le, apprpvaJ _ - - - , , , ., _""" Y~s - - - - - RPC 8/24/2004 13 Can permit be approved before 15-day wait Yes . 14 WellJocaled within area and,strç¡taauthorized by_lnjectioo Ord~r # (PulIO# in_cpmm~nts), (For_ NA - - - - - - - - - - - - - , ' 15 ,All wells,withirUl4,llJile,area,of reyiew id~otlfjed (FQr $.ervjcewell OI1I~>- _ ' , ' , , , , , ' , , , , ,NA - - - - - - - - - - - - - - - - - - - - - - - -- 16 PJe-prOduçed injector; duration of pre-proøuctioo I~ss, than 3 months (For,selYtce well only) - NA - - - - - - - - - - - - - - - 17 ACMP_F:ïl1djn9,ofCon,stste!1Gy,h,as Þee,nJ$.sued,forJbis pr_olect , _ _ _ , '" _ _ ,NA, - - - - - - - - Engineering 18 ,C.ondu_ctor $tring,PJQvided , , - - - - - - - ,_ _" Y~s ' , , , _ 20~' @ 1t0~. , 19 ,Rurfac~ ,ca$.ing_ pJote(j$. alLk!'1own USQW$ - - - - - - - - -- - - -" Y~$ - - - - - - - - - - - - 20 ,CMT v,ol adeQu,ateJo circ_ulate_on,cond,uctoc & SUJtcsg , _ _ , , , , ' - , - , , - , ,Y~s ' , ,.A.de~uate exce$.s. . - - - - - - 21 _CMT vol adeQu_ateJo tie-tnJongstring to surf C$.g_ . _ No, - - - - - - - - - - - - - 22 ,CMTwill Goyer,all koown-PfQ.ductiye hQrilOn,s_ , , _ , _ - - - , , , , ' - , - _", Y~s - - - - - - 23 _C_a$ing de,signs ad,eQuate fpr C"T" B_&,perruafrp$t , , ' - - - - - - - Y~s - - - - - - - - - - - - - - - - 24 AdequateJanl<ç¡ge_oJ re_seI'Ye pit _ . _ - - Y~s ' , , , ,Doypo 16., . , 25 Jta.re-drill" has,a to,4,03 for abandonme,nt be~n apPJoved , , . , NA . _ _ . . New welt , , _ , ' , , , ' , , , , . 26 ,AØequatewellbore $.epç¡ratjonpro'po$.eø, , ' , , ~ , , , ' , , , , , , ' , , "'" Y~s - - - - - - - - - - - - - - - - - - - - - - - - - 27 Rdjverter JequiJed, does it meet reguJations_ _ _ - - - - - - - - - - - -- ,_, - - Y~s - - - - - - - - - - - - Appr Date 28 ,DJiUiog fluid,program $~hemç¡tic,& equip Ji$tadequale , ' _ _ _ -, - - - Y~$ , , , , ,Max MW 10,8ppg. WGA 8/25/2004 29 _BOPEs"d,o,they meelreguJation , , ' , , , ' , , , , , , ' , , , , Y~s - - - - - - - - - - - - - - - . 30 _BOPE_PIess rating appropriate; test to (put psig tn _comments). . - Y~s ' , , _ _ Test tp .4000, psi.MSI' 2630 psi.. 31 ,C,hoke_ruanjfold compJies. w/APl RI'-53 (May 64) - - - - - - ' _ , _ _ .Y~s - - - - - - - - - - 32 Work will oçc,ur withoytoperatjon_sbutdown- - - - -- ,. - - - Y~s - - - - - - - -- 33 Js. pre$.enœ_ of H2S gas, prob,aþle _ . - - - - - - - - - - - - - - ,,_. _ No, ' , , , ,NoLan H2S pad. 34 MechanicaLcondjtion Qf well$ within .A.OR yerified (for, service w~1J only) NA Geology 35 P~rmil c.a!1 be issu.ed wlo hydrogen s,ulfide meaS,ures. ' Y~s 36 _D_atapJesented on potential pveJpressurezones _ , _NA - - - - Appr Date 37 ,S~tsmic,analysjs, of shaJlow gas,zpoes, _ , ' , , , , , , ' , , , , , , ' _ ""NA - - -- RPC 8/24/2004 38 ,S~abedcondjtipO survey (if off-shpre) . _NA - - - - 39 Conta,ct narnelphOl1eJorwe~kly progre$s,reports [exploratory ,0nlYl NA Geologic Date: Engineering Date Date Commissioner Commissioner 7zd/ðfC