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207-020
STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Wel 20AAC 25.105 20AAC 25.110 GINJ ❑ =NJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Develop r/Q�en(��pjfy,L"I to ❑ ServicpJ'�SV°rlyB'�t ❑ 2. Operator Name: e. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 2/8/2020 207-020 ' 319496 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 4/14/2007 50-029-22340-01-00 ' 4a. Location of Well (Governmental Section): B. Date TO Reached: 16. Well Name and Number: 4/30/2007 PBU 03-36A ' Surface: 906' FSL, 899 FIN&, Sec. 11, TI ON, R15E, UM g Ref Elevations KB 55.67 17. Field/Pool(s): Top of Productive Interval: 47' FNL, 4896' FEL, Sec. 14, T10N, R15E, UM GL 27.00 BF 26.80 PRUDHOE BAY, PRUDHOE OIL Total Depth: 1561' FNL, 2141' FWL, Sec. 14, TION, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 4580'/ 4120' ADL 028327, 028321 & 028332 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 714172 y- 5936972 Zane - ASP 4 15365' / 9043' 74-017 TPI: x- 713685 y- 5936004 Zone - ASP 4 12, SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/WD: Total Depth: x- 715487 y- 5934541 Zone - ASP 4 None 1900' (Approx.) r 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Wndow MDRVO: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 4756't 4230' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD / GR / RES / PWD / V b ation, MWD / GR / RES / ABI, Cement Evaluation 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH WD HOLE SIZE CEMENTINGRECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94# NT60 E 31' 107' 31' 107' 30" 281 ou 8 Arctic Set 13-3/8" 68# NT -so 30' 3973' 30' 3728' 16" 1517 sx CS III, 400 sx Class'G', 165 sx CS II 9-5/8" 47# Nreas 28' 4756' 28' 4230' 12-1/4" 1210 sx Class'G' 7" 26# L-60 4599' 10588' 4132' 8662' 8-1/2" 579 sx LiteCrete, 166 sx Class'G' 4-1/2" 12.6# L -6o 10416' 15363' 8548' 9043' 6-1/8" 605 sx Class'G' 24. Open to production or injection? Yes ❑ No RI 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# L-80 10435' 10379'/ 8523' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283(i)(2) attach electronic and printed Yes ❑ No 0 information Ir�ImeG.. crrr+VlV MAT 2 20DEPTHINTERVAL(MD) �D AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Injection Method of Opem6on (Flowing, gas lift, etc.): N/A Date of Test:Production Hours Testetl:: for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio Test Period -.0 Flow Tubing Press Casing Press: Calculated 24 Hour Rale —111� Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (cow): Form 10-007 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMs--Wtj MAR 0 4 2020 el-Q63hel2a V C, 28. CORE DATA Conventional Core(s) Yes ❑ No 21 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of tap and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 21 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 11144' 8965' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 5751' 4961' ' HRZ 10289' 8463' ' Base HRZ 10569' - 8649' - Shublik C 10650' - 8703' ' Sadlerochit - Zone 4B 10703' 8739' ' 42SB - Zone 4A 10871' 8846' ' COIL - Zone 3 10968' 8897' Base of CGL - Zone 2C 11144' 8965' Formation at total depth: Zone 2C 11144' 8965' r 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production Orwell test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Minge, David Contact Email: David.Minge@bp.com Authorized Title: SI cialist AIA22 qq Authorized Signature: Date: I J'yq/ Contact Phone: +1 9075645279 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. 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 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Reviewthe reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cared and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: 03-36A 26• Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 10326' 27 Bbls Class'G' 10326'- 10331' Punch Tubing 8754' 44 Bbls Class'G' 4610' Cut & Pull Tubing 4580' Set Whipstock T/I/O=SSV/200/150, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS), pre side track. PPPOT-T: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 12/4/2019 min (PASS). Bled void to 0 psi. ***WELL S/I ON ARRIVAL*** (pre rig) RIG UP HES SLICKLINE UNIT 046 12/5/2019 ***CONT. ON 12/06/19 WSR*** ***CONT. FROM 12/05/19 WSR*** (pre rig) PULLED 4-1/2" PXN-PLUG @ 10,423' MD 12/6/2019 ***JOB COMPLETE, WELL LEFT S/I*** T/1/0=200/180/180 Temp=Sl Injectivity Test (SIDETRACK) Pumped 2 bbls 60/40 followed by 280 bbls 1% KCL @ 5 BPM down TBG for Injectivity Test. (See log for details) Pumped :4 bbls 60/40 followed by 38 bbls crude down TBG for FP. Hung FP tag on WV. Valve Positions=SV,WV,SSV closed MV Open, CV's OTG 12/11/2019 FWHP=0/900/310 SLB Cementing Services Job Scope: Reservoir Cement Plug Pre Sidetrack. Estimate TOC @ 10700' MD. (-3 bbls of cement behind pipe). LRS assisted by pumping 10 bbls of 60/40 and 290 bbls of 1 % KCL down the tubing SLB followed with 5 bbl Fresh water spacer, 27 bbls of 15.8 ppg Glass "G" cement, 2 bbls of FW. Launch (2) 6" foam balls, 5 bbls of fresh water spacer. LRS pumped 155 bbls diesel displacment. Hesitate. Walked pressure up to 2145 psi w/ 1 bbl diesel (total 156 bbls of diesel) Pressure slowly brokeover and stablized at 1871 psi. Held for 30 mins. Bled pressure to 500 psi See LRS WSR for details. Wash up 12/21/2019 Isurface lines. RDMOL **Job Complete** T/I/O = /158/134 Temp - SI. Assist w/ Cement Job (SIDETRACK) Heat DSL transport to 70*. Pumped 10 bbls 60/40 meth, 281 bbls 120* 1%KCL and 1 bbl 60/40 meth down Tbg for load. Cementers pumped FW, Cement and dropped ball. Pumped 157 bbls 60* DSL down Tbg to displace cement to perfs. Held pressure on Tbg for 30 mins. Bled Tbg to 500 psi. 12/21/2019 DSO notified ofwell status per LRS departure. FWHP's=500/280/100 SV,WV,SSV=C ***WELL S/I UPON ARRIVAL*** (Sidetrack) BRUSH TREE & BPV PROFILE W/ DOUBLE 4 1/2" BRUSHES, 3.0" GAUGE RING. DRIFTED W/ 2.50" CENT, 20'x 1.75" DD BAILER TO TOP OF CEMENT @ 10,310' SLM (2 cups cement). 12/29/2019 ***JOB CONTINUED ON 30-DEC-2019*** ***JOB CONTINUED FROM 29-DEC-2019*** (Sidetrack) TAGGED TOP OF CEMENT W/ 2.50" SAMPLE BAILER @ 10,310' SLM. RAN READ GR/CCL/MTT LOG AS PER PROGRAM (good data). LRS PERFORMED PASSING STATE WITNESS MIT-T (Brian Bixby). STATE WITNESSED (Brian Bixby) TAG TOC W/ 2.50" SAMPLE BAILER, 2.85" CENT @ 10,309' SLM. 12/30/2019 I ***WELL S/1 ON DEPARTURE*** IT/I/O= 21/164/122 Temp=Sl Assist SL (SIDETRACK) AOGCC MITxT pump approx 3 bbls crude do TBG to attain test pressure ***PASS*** 12/30/2019 FWHP = 18/73/99 well left in SLB custody AFE Sign and tag hung Daily Report of Well Operations PBU 03-36A ***WELL S/I ON ARRIVAL*** (SLB ELINE TBG PUNCH) INITIAL T/1/0 = 0/100/100. MIRU & PT TO 2900 PSI. PUNCH TBG 10,326'- 10,331- W/ 1.56" 4 SPF 0 DEG PHASE SMALL CHARGE GUN. ALL LOGS CORRELATED TO 4.5" TUBING TALLY DATED 02 -MAY -2007. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 650/0/100. 1/1/2020 ***JOB COMPLETE ON 01 -JAN -2020*** T/1/0= 610/77/121 Temp= S/1 ( LRS Unit 42 Assist SLB pump crew w/ Cement Job/ Sidetrack) Pumped 10 bbis 60/40 followed by 283 bis 1 % KCL followed by 73 bbis 9.8 1/3/2020 brine, Down TBG IA to Adjacent flowing well (03-14). ***Job continued on 01/04/2020*** ***Job continued from 01/03/2020*** ( LRS Unit 42 Assist SLB pump crew w/ Cement Job/ Sidetrack) Pumped a total of 380 bbis 9.8 brine followed by 34 bbis DSL for a U -Tube FP on TBG & IA. Surface lines & choke skid Fp'd with 60/40 meth. Valve positions= SV, 1/4/2020 SSV = closed MV, IAC, OAC= open FWHP= 615/615/180 SLB Fullbore Cementers - TxIA cement balance plug - Plug and & Abandonment (SIDETRACK) ***LRS in control of well upon arrival*, see LRS AWGRS 1/4/20 and 1/5/20 for more details*** Circ'd the following fluids down 03-36 TBG with IA returns to outlet well 03-14: LRS pumped 290 bbis 1 % KCI, 330 bbls 9.8 ppg NaCl, SLB pumped 10 bbis freshwater spacer, 44 bbis 15.8 ppg Class G CMT, 2 bbis freshwater flush, dropped balls, 5 bbis freshwater spacer, LRS displaced with 123 bbis 9.8 ppg NaCl, 34 bbis diesel. U -tubed TxIA. FWHPs = 615/615/180. 03-14 SV = closed, 03-36 SV/SSV=C, MV=O, IA/OA= OTG. FP'd Return line, grease crew serviced tree valves and choke skid, notified DSO. ***Job 1/4/2020 Complete*** T/I/O = SSV/10/110. Temp = SI. Bleed OAP to 0 psi (eval OA BUR). OA FL @ surface. Bled OAP to BT to 0+ psi in 5 min (12 gal). Maintained open bleed for an additional 3 hrs (no measurable returns). Monitored for 30 min. OAP increased 10 psi. Final WHPs = 1/9/2020 SSV/10/10. ***WELL S/I ON ARRIVAL*** (Sidetrack) ATTEMPT TO RIG UP BUT TEMPS FALL BELOW -40 1/9/2020 ***CONT. ON 01/10/20 WSR*** ***CONT. FROM 01/09/20 WSR*** (Sidetrack) RIG UP HES SLICKLINE UNIT 046 1/10/2020 ***CONT. ON 01/11/20 WSR*** T/1/0=0/5/135 Temp= S/1 LRS Unit 42 State witnessed AOGCC CMIT-TxIA (Witnessed by Bob Noble) G uIIT-TxIA Passed [7 2 39/2757 psi max applied psi. I arget pressure- res ure2700 2700psi. Pressured up T/IA to 2766/2801 psi with 3 bbis -20* diesel. 1st 15 min T/IA lost 17/27 psi. 2nd 15 min T/IA lost 10/17 psi for a total loss of 27/44 psi in 30 min. Bled back 3 bbis. Pressured up TBG to 500 psi w/.65 bbis diesel for BPV test when set. Slickline in 1/11/2020 control of well upon departure. Tags hung. AFE sign hung on well. IA OA= OTG. Final ***CONT. FROM 01/10/20 WSR*** (Sidetrack) RAN 2.50" CENT. & 1.75" S. BAILER, TAG TOC @ 8754' SLM... GOOD CEMENT SAMPLE RECOVERED BRUSHED TREE & BPV PROFILE W/ DOUBLE 4-1/2" BL -BRUSHES & 2.34" SWAGE DRIFT FREELY @ 150 FPM TO 5000' SLM W/ 3.70" CENT. FOR UPCOMING JET CUT LRS PERFORM PASSING (AOGCC STATE WITNESSED) CMIT-Tx IA (see Irs wsr) TAG TOC @ 8754' SLM (AOGCC STATE WITNESSED) W/ 2.50" CENT. & 1.75" S. BAILER (good sample recovered) 1/11/2020 ***WELL S/I ON DEPARTURE, PAD -OP NOTIFIED*** Daily Report of Well Operations PBU 03-36A T/I/O = 530/180/60. Temp = SI. Inflow Test Passed 3rd attempt (Pre-Rig). No AL. T FL & IA FL @ surface. Bled TP from 530 psi to 0 psi in 15 mins & held open bleed for additional 30 mins (0.3 bbls fluid). IAP decreased 40 psi. Attempted failing Tbg inflow test (slow steady drip). Held open bleed on Tbg for 1 hr & attempted 2nd inflow test w/ same results. Bled IAP from 140 psi to 0 psi in 5 mins (<5 gals fluid). TP went on a vac. Conducted inflow test on Tbg for 30 mins w/ no observable flow. Final WHPs = 0/0+/60. 1/12/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1340 hrs. T/I/O = SSV/190/60. Temp = SI. WHPs (eval OA BUR). No AL. 1/12/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00. ***WELL SHUT IN UPON ARRIVAL*-* (ELINE CUT TUBING) INTIAL T/I/0=50/0/50 CUT 4-1/2" TUBING AT 4586' WITH 3.65" JET CUTTER PRESSURE TUBING UP PRIOR TO CUTTING T/I/0=500/0/50 GOOD INDICATION OF CUT-COMMUNICATION OF TUBING AND IA CORRELATE TO READ MTT LOG DATED 30-DEC-2019. FINAL T/I/0= 150/150/50 1/13/2020 ***JOB COMPLETED*** T/I/O = SSV/40/110. Temp = Sl. WHPs (eval OA BUR). No AL. IAP increased 40 psi, OAP increased 50 psi overnight. 1/13/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 T/1/0=0/0/0 OA Integrity test/CMIT TxIA (Side Track) Pumped 10 bbis Diesel down OA for Integrity test PASSED per WIE LLR=0.4 BPM @ 700 PSI Bled back 2 bbls. CMIT TAA PASSED to 2779/2777 psi 2700 Target, 2800 Max Pumped 3.3 bbls diesel into IA to reach test pressure. Loss of 11/10 Psi. 1 st 15 min, Loss of 9/9 psi 2nd 15 min. bled 1/14/2020 back 3 bbls. FWHP=0/0/0 SV,WV,SSV shut, MV,IA,OA Open T/I/O = SSV/80/170. Temp = SI. WHPs (pre CTD). Wellhouse, scaffold, and flowline disconnected. IA & OA FL @ near surface. 1/22/2020 Valve crew in control of valves upon departure. 20:30 T/I/0=40/80/170. Pre Parker272. Set 4" HP H plug with Cameron wellhead guy Opsi and open bleed on I/A. RD 4" Cameron upper tree. RU 4" temp valve #36. Torqued to API spec. PT to low 300psi and high 5000psi for 5 min ea. Passed. RD 2" I/A blind flange. RU 2" temp valve #3. Torqued to API spec. PT to low 300psi and high 3500psi for 5 min ea. Passed. RD 2" O/A blind flange. RU 2" temp valve #30. Torqued to API spec. PT to low 300psi and high 3500psi for 5 min ea. Passed. Bleed on O/A to Opsi for 2" VR plug verification. @ 6psi. Will 1/23/2020 continue 2" VR plug verification later. Final WHP's 0/0/6. Initial T/1/0=0/5/0. (Test TWC). Pumped 5.47 bbl's of DSL down IA to achieve test pressure of 2794 psi. Lost a total of 17 psi in 5 mins. No psi gain on TBG. ***PASS*** per FB WSL 1/25/2020 Rea. Bled back -4.7 bbls. FWHP's 0/10/0 Well shut in upon departure. T/1/0=0/0/108. Verify 2" VR plug. Bleed companion O/A to Opsi. Monitor for 1 hr. Passed. RD 2" companion O/A blind flange verify 2" VR plug. RU 2" companion O/A blind flange with Alimite fitting. Torqued to API spec. PT to low 300psi and high 3500psi for 5 min ea. Passed. 1/30/2020 ljob Complete. See log. Final WHP's 0/0/0. MV=O. IA,O/A=OTG. =SSV/O+/140. Temp = SI. WHPs (pre CTD). Wellhouse, scaffold, and flowline ITM/VI/O= disconnected. IA & OA FL@ near surface. 1/31/2020 O. IA, OA = OTG. 09:30 North America - ALASKA - BP Page 1 Qw Operation Summary Report Common Well Name: 03-36 - - - - Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/8/2020 End Date: Project: PBU Site: 03 Rig Name/No.: PARKER 272 Spud Date/Time: 4/3/1993 12:00:OOAM Rig Release: Rig Contractor: PARKER DRILLING CO. PU01: USA00001408 Active datum: ACTUAL KB P272 @73.80usft (above Mean Sea Level) Date From - To His Task Code No Total Depth Phase Description of Operations _ (hr) usft) 2/4/2020 11:00 - 1430 3.50 RIGID P -0.35 PRE . GENERAL RIG DOWN OPERATIONS �- SKID THE RIG FLOOR LAY OVER THE DERRICK - DISCONNECT INTERCONNECTS - SPLIT MODULES, STAGE ON PAD AND PREPARE FOR RIG MOVE 14:30 - 00:00 9.50 MOB P -0.35 PRE MOVE RIG FROM J-PAD TO OXBOW 2/5/2020:00 - 12:00 12.00 MOB P -0.35 PRE MOVE RIG FROM THE OXBOW TO DS-03 112:00 - 16:00 4.00 MOB P -0.35 PRE SPOT MODULES !I '- FUNCTION E-STOPS PRIOR TO SPOTTING OVER WELL I- RIG UP UTILITY MOD. PIPE SHED AND INTER !CONNECT 2- RIG UP MUD MOD PIPE SHED AND INTER CONNECT F6:00 116:00 - 22:30 6.50 RIGU P -0.35 PRE GENERAL RIG UP OPERATIONS -RAISE DERRICK =543K OFF RACK - SKID RIG FLOOR I- RIG UP MAN RIDERS _ - BUTTON UP HAUNCH - INSTALL FLOW LINES - CONNECT MM-DM B UM-DM INTERCONNECT ! LINES I,-CALIBRATE TOTCO j SPOT CUTTINGS BIN i- -CONNECT WATER, AIR, STEAM TO RIG FLOOR - INSTALL HIGH PRESSURE MUD 1, CEMENT JUMPER HOSES ON RIG FLOOR -TIGHTEN 1502 STANDPIPEAND KELLY HOSE UNIONS - BRIDLE DOWN, HANG BRIDLE LINES, CONNECT BLOCKS TO TOP DRIVE - CALIBRATE DRAWWORKS AMPHION SYSTEM - RIG UP TONGS, OFFLINE MOUSE HOLES, INSTALL ROOF WALKWAYS _ -"ACCEPT RIG AT 22: 30^* 2230 - 23:30 1.00 RIGU P 035 PRE HOLD PRESPUD MEETING WITH MARQUES W RICES CREW __-TABLE TOP H2S/RIG EVACUATION DRILL 23:30 - 00000.50 RIGU P -0.35 PRE _ NIPPLE DOWN DRY HOLE TREE -FMC ON LOCATION TO BLEEDADAPTER I VOID SIMOPS: GENERAL RIG UP OPERATIONS - HOLD PRESPUDAND TABLE TOP H2S/RIG EVACUATION DRILL WITH BEN HERBERT'S —r - - CREW DURING PRETOUR MEETING 2/6/2020 100:00 - 05:30 5.50 RIGU P i -0.35 PRE CONTINUE TO NIPPLE DOWN TREE -CLEAN TUBING HANGER - INSPECT TUBING HANGER THREADS -INSTALL DARTAND TEST FIT CROSSOVER :(B TURNS) Printed 2/26/2020 3:24:44PM **Ali depths reported in Drillers Depths- North America - ALASKA- BP Page 2 aE" Operation Summary Report Common Well Name: 03-36 Event Type: RE-ENTER- ONSHORE(RON) Start Date: 2/8/2020 End Date: — Project: PBU I Site: 03 Rig Name/No.: PARKER 272 Spud Date/Time: 4/3/1993 12:00:OOAM Rig Release: Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001408 Active datum: ACTUAL KB P272 @73.80usft (above Mean Sea Level) Date From - To Hrs __(hr) Task Code NPT Total Depth (usf) Phase Description of Operations 05:30 - 11:00 5.50 RIGU P -0.35 PRE NIPPLE UPADAPTER FLANGE, HIGH PRESSURE RISERS AND BOP STACK - NIPPLE UP HIGH PRESSURE RISERAND SPACER SPOOL - NIPPLE UP BOP STACK I- NIPPLE UP FLOW RISER - ATTACH TURNBUCKLES AND HOLE FILL LINES - INSTALL MOUSEHOLE '- NIPPLE UP CHOKE LINE - TROUBLESHOOTAND RESOLVE ISSUES j RELATED TO COLD WEATHER SIMOPS TROUBLESHOOT SUPER CHOKE PANEL ISSUES __.. ._._ _ - CHANGE OUT THE SAVER SUB TO 4-1/2" IF 11:00 - 11:30 0.50 RIGU P -0.35 PRE RIG UP TO PRESSURE TEST BORE .- INSTALL TEST JOINT _+PERFORM - FLUID PACK SYSTEM SHELL TEST ON BORE 11:30 - 18.30 7.00 RIGU r-P� -0.35 E 'PRESSURETEST BOPETO 250 PSI LOWAND 4000 PSI HIGH FOR 5 MIN EACH '.- TESTANNULAR TO 3500 PSI HIGH -TEST WITH 4",4-1/2",5", AND 7" TEST JOINTS -TEST ALARMS, PVT AND FLOW SHOW - TEST WITNESSED BYAOGCC REP BRIAN 1830 - 20:00 1830 1.50 RIGU P -0.35 BIXBY PRE PULL BPV - MAKE UP T -BAR -PULL DART _ -PULL BEV .20:00 - 21:30 1.50 DRILL P -0.35 DECOMP RIG DOWN TESTING EQUIPMENT - BREAK DOWN TEST JOINT .._... _.... _ j ! -BLOW DOWN BORE X21:30 - 22:30 1.00DRILL IIS P —-_ -0.35 DECOMP ROCK OUT DI EBEL FREEZE PROTECT TAKING RETURNS TO TIGER TANK i -PUMP 20 BBL DOWNIA - -PUMP 60 BBL DOWN TUBING T 22:30 - 23.00 0.50 CASING P 4,599.65 DECOMP PULLTUBING HANGER TO RIG FLOOR FROM CUT AT 4600MD TO 4550' MD -MAKEUP LANDING JOINT TO TUBING HANGER (8 TURNS) _ _._._....._..... }I- 113:00 - 00:00 _..-__- 1.00_ CASING4,599.65 - UNSEAT HANGER WITH 79K, PULL HANGER TO FLOOR WITH 76K NO ISSUES UNSEATING HANGER DECOMP CIRCULATE SURFACE TO SURFACE - 10 BPM, 275 PSI I� _ -PUMP SOAP SWEEP 2!7/2020 00:00 - 00:30 0.50 CASING P— _ 4,599.6DECOMP CIURFACE TO SURFACE - 10 BPM, 275 PSI ------- �-PUMP SOAP SWEEP _�-�-I_ Printed 2/26/2020 3:24:44PM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 fie. Operation Summary Report Common Well Name: 03-36 Event Type: RE-ENTER- ONSHORE(RON) Start Date: 2/8/2020 'End Date: Project: PBU Site: 03 - Rig Name/No.: PARKER 272 Spud Date/Time: 4/3/1993 12:00 OOAM Rig Release: I Rig Contractor: PARKER DRILLING CO. I BPUOI: USA00001408 Active datum: ACTUAL KB P272 @73.80usft (above Mean Sea Level) Date 1 From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (us(t) 00:30 - 07:30 7.00 CASING P 4,599.65 DECOMP PULLAND LAY DOWN 4-1/2", 12.6#, TCII TUBING FROM 4550' MD TO SURFACE - MONITOR WELL FOR 10 MIN (STATIC) - BRINE WEIGHT IN/OUT= 9.8 PPG - LAY DOWN TOTAL OF 109 FULL JOINTS, 4 PUPS, 1 X NIPPLE, 1 CUT JOINT (22.321), AND TUBING HANGER WITH PUP SIMOPS: BUILD STANDS OF 5" DP WHILE LAYING DOWN TUBING 11.07:30 - 08:00 0.50 CASING P 4,599.65 DECOMP RIG CASING EQUIPMENT Ii08:00 - 23:00 15.00 WHSUR P 4,599.65 DECOMP (CHANGE OUT 9-5/8" PACKOFF SEALS AND ADD INTERMEDIATE CASING SPOOL - NIPPLE DOWN THE BOP STACK -SPLIT THE WELLHEAD BETWEEN THE III CASING AND TUBING HEADS '- CHANGE OUT PACKOFF SEALS - NIPPLE UP INTERMEDIATE CASING SPOOL - PRESSURE TEST PACKOFF TO 3500 PSI j FOR 15 MIN (PASS), TESTAPPROVED BY WSUP j - NIPPLE UP THE BOP STACK - INSTALL TEST PLUG AND PRESSURE TEST BREAKS ON WELLHEAD TO 260 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH (PASS) -SET WEAR BUSHING (10-3/16" ID) SIMOPS: j - LOAD WHIPSTOCK TOOLS AND EQUIPMENT _ IN PIPE SHED �,21 300 -00:00 1.00 STWHIP '', P j 41599.65 i WEXIT RIG DOWNAND BLOWDOWNTESTING (EQUIPMENT 2/8/2020 100:00 - 02:00 00 STWHIP �Ii P 4,599.65 WEXIT MAKE UP WHIPSTOCKWNDOW MILLING j BHA TO TOTAL LENGTH OF 1044.47' MD 'I- SU RFACE TEST THE MWD WITH 550 GPM, 900 PSI � -SINGLE IN WITH DRILL COLLARS AND HWDP 02:00 - 07:00 5.00 STWHIP !I P 4,609.65 WEXIT RUN IN THE HOLE WITH THE WINDOW MILLING BHAT04610'MD - RUN IN THE HOLEAT45 FPM PER FISHING REP -TAGTUBING STUBAT4610'MD 107:00 _ �P - 08:30 1.50 STWHIP 4,609.65 WEXIT SETWHIPSTOCK -ORIENT WHIPSTOCK TO 150° RIGHT OF HIGH SIDE ' - SET DOWN 10K ON TUBING STUB TO TRIP THEANCHOR - PICK UP 7' AND SET WHIPSTOCK - SHEAR OFF WHIPSTOCK WITH 37K UNDER STRING WEIGHT -TOP OF WHIPSTOCK AT 4580' MD, BOTTOM WEXIT OF SLIDLAI 4594 MD DISPLACE WELL T09.3 PPG _SND MILLING 108:30 09:00 0.50 STWHIP P 4,609.fi5 FLUID ! I- - 600 GPM, 1650 PSI 40 BBL SPACER AHEAD -- J-� MONITOR WELL FOR 10 MIN (STATIC) Printed 2/26/2020 3:24:44PM **All depths reported in Drillers Depths" North America - ALASKA- SP Page 4 Id*A Operation Summary Report Common Well Name: 03-36 - -- Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/8/2020 End Date: Project: PBU Site: 03 Rig Name/No.: PARKER 272 Spud Date/rime: 4/3/1993 12:00:OOAM Rig Release: Rig Contractor. PARKER DRILLING CO. BPUO1: USA00001408 _ Active datum: ACTUAL KB P272 @73.e0usft (above Mean Sea Level) _ Date From -To HIM Task Code NPT Total Depth Phase Description of Operations (hr) I (usft) 09:00 - 17. STWHIP P 4,613.65 WEXIT IMILLWINDOW IN 97/8" CASING AND 20' OF NEW FORMATION - FROM 4580' MD TO 4614' MD -260 GPM, 515 PSI I- 120 RPM, 5 KFT-LBS TORQUE ON BOTTOM, 5 KFT-LBS TORQUE OFF BOTTOM, 4 KLBS WOB - PU 150 KLBS, SO 130 KLBS, ROT 140 KLBS MUD WEIGHT IN/OUT= 9.3 PPG WORK THROUGH WINDOW SEVERAL TIMES WITH AND WITHOUT ROTATION AND PUMPS WITH NO ISSUES i (TOP OF WINDOW. 4580 MD, 4127 TVD 4,613.65 WEXIT BOTTOM OF WINDOW. MD, 4136' TVD PULLUPTOTHETOP OFTHEWINDOWAND :17:30 - 18:00 0.50 STWHIP P ! 11 I CIRCULATE BOTTOMS UP - 600 GPM, 1570 PSI WEIGHT IN/OUT=9.3 PPG 18:00 - 19:30 1.50 STWHIP P T_-MUD ' 1 4,613.65 WEXIT PERFORM LOT MUD WEIGHT: 9.3 PPG, 4127' TVD, 4580' MD 1-LOT - PUMP BBL TO 975 PSI, BLEED BACK 5 BBL EMW=13.8 PPG 119:30 - MONITOR WELL FOR 10 MIN (STATIC) - BLOW DOWN CHOKE AND KILL LINES - 22:00 2.50 STWHIP P _ 4,613.65 EXIT PULL OUT OF THE HOLE FROM THE TOP OF THE WINDOWAT 4580'MD TO THE TOP OF THE BHAAT 1021' MD - MONITOR WELLAT THE TOP OF THE BHA _L —. _ FOR IO MIN (STATIC) 22.00 - 00:00 2.00 STWHIP P 4,613.65 WEXIT LAY DOWN BHA FROM 1021' MD TO SURFACE 1 - RACK BACK HWDPAND DRILL COLLARS - GAUGE OF MILLS = LEAD MILL 1/32" OUT, FOLLOW MILL IN GAUGE, DRESS MILL 1/16" OUT 2/9/2020 '00:00 - 01:30 150 STWHIP P 4,613.65 WEXIT CLEAN OUT STACK FROM WINDOW MILLING OPERATIONS 1 - PULL WEAR RING I - RUN STACK CLEANER AND FLUSH STACK + __ ! �-SETWEAR RING to= 101. _ _ 01:30 - 04:30 3.00 STWHIP P ',, j 4,613.65 WEXIT MAKE UPAND RUN IN THE HOLE WITH 8-1/2" ''.x 9-7/8" INTERMEDIATE DRILLING ASSEMBLY TO 1315'MD PER BAKER DD/MWD -NOV 8-1/2" SK616-JI D PDC BIT -ANDERREAMER 133' BACK FROM BIT -ANDERREAMER COMPLETELY DRESSED WITH NEW PARTS TO MINIMIZE RISK OF FATIGUE FAILURE WHILE ROTATING ACROSS _ i__ — __WHIPSTOCK 04:30 - 07:00 2.50 STWHIP P r 4,613.65 WEXIT 1 RUN IN THE HOLE WITH 8-1/2" x 9-7/8" 1 1 INTERMEDIATE DRILLING ASSEMBLY ON 5" DRILL PIPE FROM 1513' MD TO BOTTOM AT 14614' MD - MUD WEIGHT IN/OUT = 9.3 PPG - MONITOR WELL WITH HOLE FILLAND TRIP 1 TANK WHILE RUNNING IN: GOOD (DISPLACEMENT Printed 2/26/2020 3:24:44PM --All depths reported in Drillers Depths" DATE I REV BY COMMENTS DATE REV BY COMMENTS 0429/93 ORIGNAL COMPLETION 12109119 TJS/JMD PULLED PXN PLUG (12106/19) 005MW07 WES SIDETRACK (03JBA 01/0620 (W/JMO CMT PLUG (1221/19) 0128/19 CJWJMD SET PXN PLUG 0123119 01/0020 MSIJMD TBG PUNCH 01/0120 04/14119 BB/JMD CORRECTION TO 123/19 PLUG0110620 JUJMD CMT PLUG N TX IN (01104f20) 07(JO/19 JMG/JMD PULLED PXN PLUG 07129/19 01/18/20 RCB/JMD TAGGED TOC 01/1120 0821/19 MT JJMD SET PXN PLUG (0820119) 0111620 EPD/JMD 7BG CUi (01/1320) PRUDHOE BAYUNIT WELL: 03-36A PERMIT No:'2070200 API No: 5D -029-2234D-01 BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Bob Noble Petroleum Inspector Section: 11 Township: 10N Drilling Rig: n/a Rig Elevation: n/a Operator Rep: Mike Harris Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 13 5/8" O.D. Shoe@ Intermediate: 9 5/8" O.D. Shoe@ Production: - Feet O.D. Shoe@ Liner: 7" O.D. Shoe@ Liner: 41/2" O.D. Shoe@ Tubing: 41/2" O.D. Tail@ Plugging Data: DATE: January 11, 2020 SUBJECT: Well Bore Plug & Abandonment PBU 03-36A BPXA PTD 2070200; Sundry 319-496 Range: 12E Meridian: Umiat Total Depth: 15365 ft MD - Lease No.: ADL 029327 107 Feet 3973 Feet 4756 Feet Csg Cut@ Feet 10588 Feet 15363 - Feet 10435 - Feet Suspend: P&A: XX Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Pluq Founded on De th Btm Denth To MW Above Verified Tubing Bottom - 10309 ft MD 8754 ft MD 6.9 ppg - Wireline tag Remarks: 2nd plug in the well; stacked on the plug verified by AOGCC Inspector Brian Bixby on12/30/2019. I witnessed a passing combination MIT-TxIA. A slick line tag with a 1.75' bailer was also performed. The retrieved bailer was found with hard cement that had to be driven out of the bailer with a bar. Picture included. Attachments: Photo rev. 11-28-18 2020-0111_Plug Verification_PBU_03-36A_bn Plug Verification — PBU 03-36A (PTD 2070200) Photo by AOGCC Inspector B. Noble 1/11/2020 Sample retrieved from slickline bailer used in plug tag MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� 1 I)ig(Z020 P.I. Supervisor FROM: Brian Bixby Petroleum Inspector DATE: December 30, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 03-36A BP Exploration Alaska Inc. PTD 2070200; gundry 319-496 Section: 11 Township: 10N Range: 15E Meridian: Umiat ' Bridge plug Drilling Rig: n/a Rig Elevation: n/a Total Depth: 15365 ft MD ' Lease No.: ADL 029327 Operator Rep: Gerald Boyles Suspend: P&A: XXX Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 20" O.D. Shoe@ 107 - Feet Csg Cut@ Feet Surface: 135/8" O.D. Shoe@ 3973 _ Feet Csg Cut@ Feet Intermediate: 9 5/8" - O.D. Shoe@ 4756 , Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 10588 - Feet Csg Cut@ Feet Liner: 4 1/2" O.D. Shoe@ 15363 - Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 10435 - Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Bridge plug 12,600 ft MD 10,309 ft MD -1 6.7 ppg Wireline tag 121 121 Initial 15 min 30 min 4.5 min Raciilt Tubing 2729 2606 2575 ' IA 213 213 212 #:::::::::1 P OA 121 121 121 Remarks: This is a P&A for a redrill. Pretest Pressures T/I/O = 20/164/115; BBLS in 3.8. BBLS out 2.9 Attachments: none rev. 11-28-18 2019-1230_Plug_Verification_PBU_03-36A_bb THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Bjork Senior Completion Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-36A Permit to Drill Number: 207-020 Sundry Number: 319-496 Dear Mr. Bjork: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Jerem rice Chair DATED thissl day of November, 2019. 'BDMSJL� NOV 7 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAr. 9s qRn RECEIVED NOV A i info --- - • c.W 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ O/jj�er��4Q)n(.� u('pw Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChangCAp(�e4dtl�Wr09rd Plug for Reddll 0 - Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 207-020 ` 3. Address: P.O. Boz 196612 Anchorage, AK 6. APINumber: 50-029-22340-01 410 "- 99519-6612 Stratigraphic ❑ Service 0° 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 03-36A 9. Property Designation (Lease Number): 10, Field/Pools: ADL 028327, 028331 & 028332 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective DepM Plugs (MD): 10423, 12600, Junk (MD): 15365 9043 10423 85523 12980, 13620, 14180, 14650 None Casing Length Size MDD Burst CollapseStructural Conductor 76 20" 31 - 1007 2300 520Surface 3943 13-3/8" 30 - 3928 5020 2260Intermediate 4726 9-5/8" 28-4730 6870 4760Liner 5989 7" 4599 - 108662 740 5410 Liner 4947 4-1/2" 10416 - 15363 8548 - 9043 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 12300 - 15110 9036-9047 4-1/2" 12.6# L-80 26 - 10435 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 10379/8523 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: December 1, 2019 15. Well Status after proposed work: ❑ WINJ 11WDSPL ❑ Suspended 0 ----]Oil 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedureapproved herein will not Contact Name: Nocas, Noel be deviated from without prior written approval. Contact Email: Noel.Nocas@bp.com Authorized Name: Bjork, David Contact Phone: +1 9075645027 Authorized Title: Senior Completion Engineer Authorized Signature: q Date: �� COMMISSION USE ONLY Conditions of approval: Notify Commission so thatrepresentative may witness Sundry Number: La — Plug Inte n BOP Test M ---'Mechanical Integrity Test Y/ Location Clearance ❑ I q LD{ Other�:T1WO,QE 2S7 � U �'rro[s�L %® WiTNS-�,S �`'✓cam �Cr���E3�.e✓D i��/iA1Q6N��M%�t�r� /dB�65[Yl�/K f�iBoUE �oDucTicrd�ic Post Initial Injection MIT Recd? Yes ❑ No Spacing Eigiotion Required? Yes ❑ No Subsequent Form Required: 41Q'7 IBDMS 'j NOV 2 5 2019 APPROVED BYTHE 1 rjt (i Approved by: COMMISSIONER COMMISSION Date: I ORIGINAL lngels Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 03-36A Sundry Application Well Type: Injector Current Status: Shut-in Request: P&A for rotary rig sidetrack Planned Pre -Rig Work Start Date: December 2019 Planned Rig Start Date: January 2019 CMIT-TxIA Passed to 2735 psi (3/24/2019) MIT -OA Pressure test to 500 psi, no fluids to surface, LLR 6.1 gpm (3/24/2019) PPPOT-T Passed to 5000 psi (3/27/2019) PPPOT-IC Passed to 3500 psi (3/27/2019) MIT -T Passed to 2634psi(8/20/2019) MASP: 2,433 psi (7.17 ppg EMW in Ivishak Zone 2 at 8,917' TVDss with 0.1 psi/ft gas gradient) Well History: 03-36A became non-operable for TxIA communication. The 03-36B well is scheduled to be drilled by Parker 272 in January 2020. The proposed 03-36B sidetrack will be a horizontal injector targeting the 26P "Victor" Package in the Sadlerochit. The planned well is a two string, ultra-slimhole design using 7" intermediate casing and 4-1/2" production liner. The intermediate casing will be set at the top of the Shublik limestone, and the injection interval will be completed with a cemented liner using sliding sleeves. Scope of Work: Prior to rig arrival the 03-36A liner will be abandoned via fullbore cement. The TOC will be verified with a drift run and pressure tested. A —1300' cement plug will then be circulated into the tubing and IA with the TOC at appx 9069'MD. The final TOC will be determined via a drift run followed by an integrity test. An MTT log will be run to determine the location of 9-5/8" collars and the 4-1/2" tubing will be cut accordingly (plan is appx 4600'MD). Wellbore integrity will again be verified after the cut. The rig will then move over the well and pull the 4-1/2" tubing. A 9-5/8" whipstock will be used to mill a window out of the existing production casing at —4550' MD. The well will be drilled as a Modified Slim Hole design, setting 7" Intermediate casing in the Shublik, The production hole will be drilled and a 4- 1/2" Liner will be run with sliding sleeves and cemented in place. A CBL will be run and then 4-1/2" injection tubing will be run. 03-36A Sundry 1 10/31/2019 Pre -Rig Prep Work: 1. S Pull PXN plug. 2. F Injectivity test 3. F Fullbore P&A 4. S Brush BPV profile. D&T TOC (AOGCC Witnessed). MTT Log. 5. F A/SL: MIT -T (AOGCC Witnessed). 6. E Tubing Punch 10369' MD. 7 F Circ Cement Plug. TOC -9069' MD. Load well with Seawater and -2000' diesel cap. 8. S Brush BPV profile. D&T TOC. Drift for Jet Cut. 9. F CMIT-TxIA. 2800psi OA Integrity Test. (500psi) _2 10. D Inflow Test. 11. E Jet Cut TBG -4585' MD. 12. F CMIT-TxIA.2800psi 13. W PPPOT-TBG and IC. Function LDS. 14. V Install Dry Hole Tree. Install Annulus Valves. Install HP - BPV Proposed Drilling Rig Operations: 7rS 1. MIRU Parker 272. 2. Test BPV from below. 3. Nipple down dry hole tree. Nipple up BOPE and test to 4,000 psi (annular to 3,500 psi). Top down configuration: annular, 4-1/2" x 7" VBRs, Blind Shear, mud cross, 2-7/8"x 5" VBRs 4. Pull BPV. Circulate out freeze protect with 8.5 ppg seawater. 5. Pull 4-1/2" tubing from the pre -rig cut at —4,600' MD. 6. Split wellhead at tubing spool / casing spool break. Change secondary (upper) 9-5/8" packoff seals. 7. Install new casing spool. Test 9-5/8" packoff to 3,500 psi. 8. Nipple up BOPE. (Nipple up old tubing spool to new casing spool). Test break. 9. Run 9-5/8" mechanical whipstock and 8-1/2" window milling assembly. Orient and set the whipstock on the tubing stub. ---------------------------------------End of Sundry / Start of Permit to Drill ---------------------------------- Drilling Engineer: Production Engineer: Geologist: Noel Nocas (907) 229-9532 Matt Summers (907) 564-5066 Stephen Crumley (907) 564-4078 03-36A Sundry 2 10/31/2019 TREE= 4-1116'OW WELLHEAD: 13-5/8" FMC ACTUATOR BAKER OKB. aEV = 60.2' BE R = NY KOP= 2700' Max Angle = 91' @ 13147 Datum MD 10888, DatumTVD= 8800' SS PROPOSED P&A Minimum ID= 3.725" @ 10423' 44/2" HES XN NIPPLE EBG, 12.6/x, L-80 TC71, .0152 bpf, D = 3.958' LNR 26#. L-80 BTC -M, .0383 bpf, D = 6.276 - 1 108' 1 PERFORATION SLOANARY REFLOG: SLBUSITCN05/02107 ANGLE ATTOP PERF: 88" 012300' AMfe:Peferto Pmdlton DBTOrHstodcal rfdata S�SPF 94#, NT60LE, NTERVAL OpriSqz D -19.124' SW -3/8" CSG, 6B#, NT --80 C = 12.415' 12300-12330 Minimum ID= 3.725" @ 10423' 44/2" HES XN NIPPLE EBG, 12.6/x, L-80 TC71, .0152 bpf, D = 3.958' LNR 26#. L-80 BTC -M, .0383 bpf, D = 6.276 - 1 108' 1 PERFORATION SLOANARY REFLOG: SLBUSITCN05/02107 ANGLE ATTOP PERF: 88" 012300' AMfe:Peferto Pmdlton DBTOrHstodcal rfdata S�SPF DATE REV BY COMMENTS NTERVAL OpriSqz SHOT SW 2-7/8' 6 12300-12330 C 0523117 06115/15 RIC 2-7/8" 6 12B17-12842 C 05/13!15 1120118 TTS/JND 2-718" 6 12842-12892 C 05/12/15 2-78" 6 12892-12917 C 05/10/15 2-7/6" 6 13230-13290 C 0224/14 2-7/8" 6 13290-13320 C 0223114 2-71W 6 13750-13850 C 09/14/12 2-718" 6 13800 -13525 C 09/13/15 2-718" 6 13825- 13850 C 09/11/12 33/8' 6 14330-14355 C 04/11/11 3318" 6 14355-14380 C 04/11/11 2-7/8" 6 14460-14490 C 02/12/09 2-7/8" 6 14490-14510 C 021061109 33/6' 6 14517-14542 C 04/11111 2-7/8" 6 15010-15110 C 06/04)07 L-80 TCI, .0152 03-36A SAFETY NOTES: H2SREADINGSAVERAGE 125 ppm WHEN ON MI ••* WELL REQUIRES A SSSV WHEN ON MI •"" W ELL ANGLE> 70° 0 11116' "' MAX DOGLEG 12.9-011365"*' 2254' 4-12°HESX NP.D=3813° 2900' 4599' J�9S/8'X7'HR ZXP LTP,D= 4622' 9-5/8' X 7' FLIX LOCK HGR MLLOUi WNDOW(03-36A) 4756'-4777' 9069' Toc RUG (_! _) X 4-12' BKR S-3 F 1/2" HES X NP, D = D=5250' D = 3.725' �7-X 5"FRZXP LTP,D=4.350' 4-12' WLEG, D= 3.958' 7' X 5' RIX -LOCK FGR, D=4.350" -12 xo.6x3 B]P TOP DPZ3 = 10569' 5-3/4" SWELL WR, D=3.958' 5-314' SWELL PKR D = 3 958' DATE REI/ BY COI.fuBWS DATE REV BY COMMENTS 04/29/93 ORIGINAL COMPLETION 0128119 Cl WJMD SET PXN FLOG (0123(19) 05106/07 N7ES SIDETRACK(03-36A)04/14/19 BB/J CORRECTION TO 1/23/19 PLUG 05/14/15 LAN P SET CEP/ ADPERF (5810.5/13) 0826/19 DM'JAD 0 POSH PBA 06115/15 RIC CSG/LNR/PH1FS CORRECTIONS 05/24/17 MSS/AC SET C13PYADPERFS (0523117) 1120118 TTS/JND CORRECTION TO TOP OF LNR SQE SWELL PKR D = 3958- r2' WFO CBP (0223/14) SWELL PKR D=3.958' '" BP(09/13/12) SWELL PKR, ID = 3.958' WFD CBP (02/08/09) SWELL PKR, ID = 3.958" PRLDHOE BAY UMT WELL: 03-36A PERMT No: /'2070200 AR No: 50.029-22340-01 SEC 11, TI OR RISE, 910' FSL 689V BP Exploration (Alaska) TFEE= 4-1/16" CIW WEIFEAD: 13 -SW FMC ACTUATOR BAKER OKB. ELEV = 60.2' BF. ELEV = 30' KOP= 2700' Max Angle = 91'@ 13142' Datum MD = 02/16/09 Datum TVD= 6 10888' 94#, Nr60LE 8800' SS D = 19.124" 13-3/8" CSG, 68#, NT --80 CYHE; D= 12.415" TOP OF 7" LNR 47#, Nr -80S NSCC, 9-51W EZSV (0411: Minimum ID= 3.725" @ 10423- 4-112" HES XN NIPPLE { 4756- -4766 1 4-12" TBG, 12.6#, L -BO TC11, .0152 bpf, D = 3.958" I L-80 HTC -M,.0353 PERFORATION SUMMARY REF LOG: SLB USIT ON 05102)07 ANGLE AT TOP PERF: 88'§12300' Nob: Referb Production DB for Nsbrical perfdata SIZE SPF KFERVAL ORIGINAL COMPLETION SHOT SOZ 2-78" 6 12300-12330 C 0523/17 02/16/09 2 718" 6 12817-12842 C 05/13/15 02125/14 2-79" 6 12842-12892 C 05/12/15 2-718" 6 12892-12917 c 05/10115 2-7/8" 6 13230-13290 C 0224114 2-7/8" 6 13290-13320 C 0223114 2-718" 6 13750 -13850 C 09/14/12 2-7/8" 6 13800-13825 C 09/13/15 2-78" 6 13825-13850 C 09/11/12 3-318" 6 14330 -14355 C 04/11/11 3-3/8" 6 14355-14380 c 04/11/11 2718" 6 14460-14490 C 02112109 2-7/8" 6 14490 -14510 c 02108/109 33B" 6 14517-14542 C 04/11/11 2-78" 6 15010-15110 C 05/04107 12.6#, L-80 TCI, .0152 bpf, 03-36A SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI *" WELL REQUIRES A SSSV WHEN ON NI "" WELL ANGLE> 70" 16' ** MAX DOGLEG 12.9" 0 11365' *** 2264' 4-12" FES X NP, ID = 3.813" 7" FR ZXP LTP, D = 7" FLD(LOCK HGR MLLOUT WINDOW (03-36A) 4756' - 4777' 13620' HES X NP, D = -12" BKR S-3 F FESS X NP. D = 12' BKR TEBACK D = 5250" I 12"PXN X5"HR 12" WLE X 5" FLE DATE I REV BY I COMMENTS DATEREV BY COMMENTS 0412993 ORIGINAL COMPLETION 05/14115 ALMI pJ SETCBP/ADPERF 58105/13 059697 N7ES SIDETRACK 03-3610 06/15/15 PJC CSG/ LNW PERFS CORRECTIONS 06/05/07 STGPJC DRLG DRAFT CORRECTIONIS 0524/17 MSS/JM SETCBPIADPERFS 0523117 02/16/09 TARISV SETCBPIADPERF 02/12109 11IM18 TTS/JMD CORRECTDNTOTOPOFLNRSIZE 09/18/12 /JM CBP&ADPERF 09113-14112 0128119 CJWJMD SET PXN PLUG 0123/19 02125/14 7TR/PJC CPB/ADPERFS 0223-24/14 04/14/19 J13tVjMDi CORRECTION 70123/19 PLUG XO, D = 3.920" LL PKR D = 3.1 LL PKR. D = 3.! SWELL PKR D = 3.958" 2" WFDCBP(0223/14) SWELL PKR, D= 3.958" " CBP (09113112) SWELL PKR, ID 3.958' WFD CBP (02/08109) SWELL PKR, D = 3.958" BP Exploration (Alaska) 41116' CNV WELLHEAD = 13-5/8' FM ACTIATOR= BAKER OKB. ELE1/ = 60.2 REF GB _ BF. ELEV = 30' KOP= 2700 Max Angle Datum MD= DatumTVD= 8800'SS PROPOSED REV 2 I, M60LEC 6OLFTOR 10i , D = 19.124' 13-3/8° CSG, 60#, NF -80 CYHE, I 3977 D= 12.415' 9-5/8' SLB WHPSTOCK L/_/� 5553' CSG, 47#, NT -80S NSOC, D=8.681°-4-553 Est TTOC 29 F Minimum ID=_'• @ LNR 4-12' TBG, 128#, 13CR-85 .0152 bpf, D= 3.958" 7' LNR 26#, L-80 VAM TOP HC, .0383 bpf, 03-36B SAFETY NOTES: H2SREADINGS AVERAGE 125 ppm WHEN ON MI *** WELL REQUIRES A SSSV -17 WHEN ON MI •"" WELL ANGLE >70'@_' "• MAX DOGLEG1/2" _" (® ' •"•CR TBG & LNR 4HES X NP, D = 3.813" MLLOUT VOMW (03-36B) - = 3.813' I I—Irx4vz•H�TNrPKR,0=3.e7o" � 41/2'HESXNP,D=3.813' i-j4-12'FESXNP,D=3.813" I O oOMsnrs ncluus -m a>E 24 0RIGINALC0MPLEHON 05108/07 WES SIDETRACK(03-36A) 2z U SIDETRACK(03-368) v AU BLILT PROPOSED 29 AD BUILT PROPOSED REV 19 JbD KILT PROPOSED REV 2 17 '6 19 11 14 14 13 2 11 10 0 e 7 6 6 3 4-12" LNR, 12.6#, 13CR-85 HTTC, I 16636' .0152 bpf, D = 3.958' D4TE REV 8Y C0MA8dT5 DOTE N V BY COMuBJTS 04/2953 0RIGINALC0MPLEHON 05108/07 WES SIDETRACK(03-36A) _I / SIDETRACK(03-368) 06/10/19 AU BLILT PROPOSED 06/13/19 AD BUILT PROPOSED REV 06/20/19 JbD KILT PROPOSED REV 2 PRLOFDE BAY LW W91: 03-368 PEFMF No: _ AR No: 50-029-22340-02 TIOR R15E, 910' FSL & 899' BP Exploration (Alaska) Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Task Res onsible initial reviewer will check to ensure that the "Plug for Redrill" box Geologist upper left corner of Form 10-403 is checked. If the "Abandon" or pend" boxes are also checked, cross out that erroneous entry and l it on both copies of the Form 10-403 (AOGCC's and operator's T�he s). "Abandon" box is checked in Box 15 (Well Status after proposed initial Geologist) the reviewer will cross out that erroneous entry and initial thenboth copies of the Form 10-403 (AOGCC's and operator's copies). d, check the "Suspended" box and initial that change. Drilling Engineer rilling engin6ers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the ^ History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the -Stat will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. U C Y CA Q v (t) _0 Q. K W CL CIO Barrels of Water per Month O O C p O C O O O O C O O N O O O O I ', O O O N N I I i i I!I I E II• HT N Q O O O O O O O O O N N 411JoW aad („jaw„) seE);o waj 3Ign:) puesnogl N 207020 BA ER 3 1 2 4 7 F UGHES PRINT DISTRIBUTION ITT a GE company COMPANY BP Exploration Alaska Inc. WELL NAME 03-36A FIELD Prudhoe Bay Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Frank Schwarzrock EMAIL frank SchwarzrockPbhge com STATUS Final COMPANY Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E Benson Blvd. Anchorage, Alaska 99506 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D-CO LOG DATE August 15, 2019 TODAYS DATE September 21, 2019 Revision Replacement: No Details: ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope, LOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rack. & Barbara Clasxmaker 1900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 'Attn: Ricky Elgarico I ATO 3-344 900 G Street 'Anchorage, AK 99501 Rev. Requested by: __ FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) #OF PRINTS #OF COPIES 17T Ur COPIES 19OF COPIES 4 JJ JJ SEP 2 4 2019 AOGCC 3 Exxonsdobil, Alaska Attn; Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 A State of Alaska - AOGCC 'Ann: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5'DNR-Divisio Art.: sr c—t r ,550 it Avenue, Suit 100 'Ancho�� .501 6 BP F,zplorntion (Alaska) Inc. Petrotechnical Data Center, LR2-1 -900 E. Benson Blvd. '.Anchorage, Alaska 99508 j Attn: David Itter 0 4 4 TOTALS FOR THIS PAGE: 0 1 4 0 0 fop 7.4 • ���y, a THE STA Alaska Oil and Gas oLASKA Conservation Commission �.. f rn � 2 =-� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.11433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Summers savite JUN 1 8 'ZU1� Production Engineer BP Exploration(Alaska), Inc. P.O Box 199612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-36A Permit to Drill Number: 207-020 Sundry Number: 318-240 Dear Mr. Summers: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Hollis S. French kl Chair DATED this C3 day of June, 2018. RBDMS ` JUN 13 2011 1-1 va.,,Ii1 V Li STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CO ION U 0 2018APPLICATION FOR SUNDRY APPR ALS 3775f.0 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0. Fracture Stimulate 0 Repair Well 0 Operations st) t aG Suspend 0 Perforate 0 • Other Stimulate 0• Pull Tubing ❑ Change Approved Program 0 Other. Mill CIBP-Set CIBP 0'. Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Contingent Acid Stim , I 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-020 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service 0. 6. API Number: 50-029-22340-01-00 7. If perforating: C.O.341E • 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 03-36A . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327&028332 J b Lz' 33/ iv PRUDHOE BAY.PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15365 ' 9043 ` 12600 9043 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 32-112 32-112 2300 520 Surface 3943 13-3/8" 30-3973 30-3728 5020 2260 Intermediate 4728 9-5/8" 29-4756 29-4230 6870 4760 Liner 5989 7" 4600-10588 4133-8662 7240 5410 Liner 4947 4-1/2" 10417-15363 I 8548-9043 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1 12300-15010 9036-9045 4-1/2"12.6#L-80 L-80 26-10436 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 10379,8523 4-1/2"MCX I-SSV 2255, 2255 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14.Estimated Date for Commencing Operations: 07/01/2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Summers,Matthew be deviated from without prior written approval. Contact Email: Matthew.Summers©bp.com Authorized Name: Summers,Matthew Contact Phone: +1 9075645066 Authorized Title: Production Engineer /� Authorized Signature: Date: 6/ ' ,) ;....7.,,,. ...........e.„.. :: �/ COMMISSION USE 0 LY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3116- – ^L�o Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 �(J( — Other: Post Initial Injection MIT Req'd? Yes 0 No 11":"/ Spacing Exception Required? Yes 0 No Subsequent Form Required: /(. " 4- v 9 r APPROVED BYTHE G I 1-2,)16l Approved by: stsj.3 ±LK—-2 COMMISSIONER COMMISSION Date: V\'9 RBDMSi JUN 132018ORIGIIVAL Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • S Plugs Attachment PBU 03-36A SW Name Date MD Description 03-36A 05/24/2017 12600 4-1/2"WFD CIBP 03-36A 05/10/2015 12980 4-1/2" CIBP 03-36A 02/24/2014 13620 4.5"WFD CIBP 03-36A 09/12/2012 14180 4-1/2" CIBP 03-36A 02/09/2009 14650 4-1/2" WFD CIBP 10- N Application A lication for Well PBU 03-36AD#207-020 Expected Start Date: July 1, 2018 Current condition of well: WAG Injection Well, Operable, Injecting: Gas Injection Rate: 12266 Mscf/Day Injection Pressure: 2646 psi Shut-in Wellhead Pressure: 2000 psi Reservoir pressure: 3356 psi Well objective(s): 03-36A has injected its target MI volume into the current bulb location. Moving uphole to the next bulb location will allow for more effective use of MI & incremental oil recovery. The first CIBP @ 12,600' MD be milled & an attempt be made to mill the CIBPs below it to reopen previous bulb locations for possible use. Proposed program: 1. Pull MCX. 2. D&T to deviation with drift for 3.56" CIBP. 3. With choke closed, attempt to mill CIBPs using junk mill. Push to deepest plug. 4. RIH to 11,300' with BHA including drift for 3.56" CIBP and GR/CCL. Flag pipe near 11,250' MD. 5. Set CIBP at 11,250' MD correlated to SLB jewelry log dated 4/26/04. 6. Adperf per perforating form using CIBP for depth control. 7. Injectivity test with non-freezable fluid. If injectivity is less than -2 BPM at 2000 psi contingent acid stim per attached program. 8. SBHPs. Set MCX (sized 20 MM/d) BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 10-Sundry Application for Well PBU 03-36AD#207-020 Perforation Summary: Aiiiii PENDING PERFORATING PROCEDURE ADM rwrrr®.e�u Well: 03-36A API e:50-029-22340-01 Date: 5712018 Prod Etrpr Matt Summers Office Ph: (907)564-5066 1125 Level: Home Ph: 0 ppm Celt/Pager: (907)952-1882 CC.or AFE: APB9tJEC WBL Entries IOR Type Work Description._...... __.._....._._._.r. i. 'See Procedure I i Well Objectives and Perforating Notes: See Procedure. Attachment: Tie-in log with pray sec pods annotated Reference Log Tie in Log Add 0 feet Log: USIT CT Flan to the tie-in log to be on Date: 512/2007 51912015 depth with the reference log. Company: SLB PDS Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone AdiReilperf 11815 11,845' 11815' 11845 30 6 Random 60' Z2 Add Requested Gun Size: 2117 Charge: &titanium STIMMin We8bore ID:...3.725_ Max Swell in Liquid: ,µ,ms �, Max Swe9 in Gas: .,» _, Is Drawdown Necessary-Desired Unnecessary During Perforating W SLlWIE to corrtrm Swell OD's due to special order Preferred Amount of Drawdown Suggestions to Achieve Drawdown Last Drift: 12600'CTM It MD on 5x23/2017 Est Res.Pres.@ 8,1300'TVOss MD is 3356 ., PSI BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 I 10- Sundry Application for Well PBU 03-36POD#207-020 Annotated Reference Log (Perf and Set CIBP): _ 0 IDA ftc..rioris,...._ COIL FLAG ''.t...i.,, 0111) 1,-- -- ..---- FINAL umT - CR - CCL 09-hidy-201 , P,..9.A.nyi...a telisiroarwiciric. sipskuilir .. c.$ Company BP EXPLORATION (ALASKA), INC, 12 Well 03 - 36A 1020459816 cn ro Field PRUDHOE BAY IIIIIIIt1111111111111111P1 = 0 ›,. Borough NORTH SLOPE state ALASKA m 8- Surface Lecaton attar Services 75.< 43 0 None 1 it g3 9059C' FSL & 899 14 I-WI ffi 8 a& 0 NI Z SEC 11 TWP ION RGE 15E Elevation o) Perrnanert Datum MS: Elevation 0.0 7 dy KB.55.67' Log Measured From RKB 55.67 FT.Above Penn. Datum D F NA t..> LZ rf'n (..) API Serial Number 50-029-22340-01 G.L.NA De* 09-IMav -2015 Run Number .rla ,P 8 T D Driler 16,274' -2 2P a 13.KC' CI P a 114:18-6' FBI D Loper Not raodect CI Ega 14,650 Bottom Lasted Interval 13,3C0 Top Log Interval 10 3-6 _Opon14eia 'Size NA 1—pe FILici produced Fluids Max,Recorded Temp.(deg, r.i •NI,A _____ Tonle Well Reedy 20 12 - FINAL PRINT . Time Lo9,9er on Bottom 23 08 Equipment Number SLR CTU#6 1:ocadon Neill Slope Service inveree No Rocorclact Ey C Goert Witessied By A McVey , 9ornhol. R OCC)fri Tublroc Record Run Number Bit r-cirr -To SizeLit ijm 4'1/2" 12.80 Surface 10,41-5'' —asma-tr-9f31Size zoFt Too Etottom Surface String 13 3/8" i -- -B-8.00 Surtec P ) fl ----I Prot.String !-57/4"---7 . It U-TTeciTi LC: r '''d' _ ob. 4 4,600' '0 sae. 17' "'2 eff449 - Liner BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ' 10-Sundry Application for Well PBU 03-36A9D#207-020 - a fry -----T' 7 — .,. " . I .> t 4Pi , Add Perfz 11,815-111M5'MD i ��'�.sy . 1111 ' r /ff I t ' . ,.. 3 , 4 F 3 i L .",a I, ,'"*".‘"*""'"."''"t 1 Ar C. i BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ' 10- andrN Application lication for Well PBU 03-36AD#207-020 s . i M �. 1 r 1 ,_ , _, _,.l v-: 4:_t_2_,1 s,. fl 2000, _. Set CI®P 0'"12.,000'MD 1 3 ..... _ ... ... 1 I. 12100 �.,,_, .,..,..-'y'____. ...._._-- - C p t I 3 C , BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TREE= 41"6"` 03- S: H2S READINGS AVERAGE 125 AN WELLHEAD 135/8"FMC36A ACTUATOR BAKER0 WHEN ON MI*** WELL REQUIRES A SSSV ---E' OKB I3EV 60.2' I *•*MAX DOGLEG 12.9° 11365'*** BF.[iEV= 30' KOP 2700' 20"CONDUCTOR, H 108' II 1� Max Angle= 91°©13142' 94# NT60L� 2254' 4-1/2"HES X NP,D-3.813" Datum MD 10888' �� *. m1V 13=19.124" iii �, 2900• HEST TOP OF CREW(06120/06) Datum TVD= 8800"-S6 13-3/8"CSG,68#,NT-80 CYHE, -i 397T D=12.415" TOP OF 4-1/2"LNR -I 4599' I 4599' -19-5/8"X 7"HR ZXP LIP,0=6.29" 9-518'WHPSTOCK(04/12/07) -{ 4756' 4622' H9-5/8"X 7"FLEX LOCK HGR,ID=6.30" 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" -I ""4756 9-5/8"EZSV(04/12/07) - 4777' MLLOUT WINDOW(03-36A) 4756'-4777' A .-:: . I .''', 10317' -I4-1/2"HES XImo,D=3.813" Minimum ID=3.725" @ 10423' 4-1/2" HES XN NIPPLE S 10379' -j7"X4-1/2"BKRS-3 PKR D=3.870" ' 10402' -441/2"FEES X NP,D=3.813" 10416' H12'BKR TEEBACK,D=5.250" TOP OF 41/2"LNR 10416' ' 10423' --14-1/2"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,L-80 TC11,.0152 bpf,ID=3.958" -I 10435' 7"LW,26#,L-80 BTC-M,.0383 bpf,D=6.276 10588' 10428' --El"X 5"HR ZXP LTP,ID=4.350" PERFORATION SIJkANARY 10435' -i4-1/2"W..EG,D=3.958" REF LOG: SLB USIT ON 05/02/07 10439' H7"X 5"FLEX-LOCK HGR,D=4.350" ANGLE AT TOP PERE 88°0 12300' , 10449' -{5"X 4-112"XO,D=3.920' Note:Refer to Rod uction DB for historical perf data SEE SPF INTERVAL Opn/Sgz SHOT SOZ _, _.4 11849' -15-3/4"SWELL FKR,D=3.958" 2-7/8" 6 12300-12330 0 05/23/17 2-7/8" 6 12817-12842 C 05/13/15 o 0 12415' -15-3/4"SWELL FKR,13=3.958" 2-7/8" 6 12842-12892 C 05/12/15 12600'CTM H4-1/2"WED MP(05/23/17) 9 -12917 C 05/10/15 2-718" 6 128 2 a' 2-7/8" 6 13230-13290 C 02/24/14 _ 12980'CTM H4-1/2"CBP(05/10/15) 2-7/8" 6 13290-13320 C 02/23/14 2-718" 6 13750-13850 C 09/14/12 - " " 13020 5-3/4 SWELL FCR,D=3.958 � 2-7/8" 6 13800-13825 C 09/13/15 I 2-7/8" 6 13825-13850 C 09/11/12 13620'CTM -14-1/2"WFD CBP(02/23/14) 3-3/8" 6 14330-14355 C 04/11/11 0 .-13624' -{5-314"SWELL PKR,D=3.958" 3-3/8" 6 14355-14380 C 04/11/11 2-7/8" 6 14460-14490 C 02/12/09 ' 14180'CTM H4-1/2"CEP(09/13/12) 2-7/8" 6 14490-14510 C 02/081/09 =' =' 14228' ---I5-314"SWELL PKR,D=3.958" 3-3/8" 6 14517-14542 C 04/11/11 I 2-7/8" 6 15010-15110 C 05/04/07 14650' H4-1/2"WFD CBP(02/08/09) e e 14830' --I5-3/4'SWELL PKR,D=3.958" RPM - 15274' I ►• 4-1/2"LNR, 12.6#,L-80 TCI,.0152 bpf,D=3.958" -I 15363' ►�••• • DATE REV BY CONVENTS DATE REV BY COIA\ENTS PRUDHOE BAY LINT 04/29/93 ORIGINAL COMPLETION 02/25/14 TTR/PJC CFB/ADPERFS(02/23-24/14) WELL: 03-36A 05/06/07 N7ES SIDETRACK(03-36A) 05/14/15 ALM/PJC SET CBPP ADPERF(5810-5/13) FERMT No:/t070200 06/05/07 STG/PJC DRLG DRAFT CORRECI10NS 06/15/15 PJC CSG/LNR/PERES CORRECTIONS AH No: 50-029-22340-01 02/16/09 TAR/SV SET CDP/ADPERF(02/12109) 05/24/17 b6S/JMD SET CBPIADPERFS(05/23/17) SEC 11,T10N,R15E,910'FSL&899'FWL 01/10/12 ThatiUM3 ADDED H2S SAFEEY NOTE 09/18/121 UJMC CBP&ADPERF(09113-14/12) BP Exploration(Alaska) • • 20�-020 WELL LOG TRANSMITTAL#904051118 2Z6 To: Alaska Oil and Gas Conservation Comm. July 20, 2017 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 AUG 0 2 2011 DATA LOGGED M.K.BENDER RE: Coil Flag Log: 03-36A AOGCC Run Date:5/23/2017 /'-� The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 03-36A Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-22340-01 Coil Flag Log(Field Print) 1 Color Log 50-029-22340-01 SCANNED AUG 1 5 2a li PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com&AKGDMINTERNAL@bp.com Date: Signed: ti A v 15_0.44.4 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Sr-I- G JB P Er" 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-020 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-22340-01-00 7. Property Designation(Lease Number): ADL 0028332 8. Well Name and Number: PBU 03-36A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 15365 feet Plugs measured See Attachment feet true vertical 9043 feet Junk measured feet JUN Effective Depth: measured 12600 feet Packer measured 10379 feet I true vertical 9043 feet Packer true vertical 8522.73 feet G"��� t .v Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#NT6OLE 32-112 32-112 2300 520 Surface 3943 13-3/8"68#NT-80 30-3973 30-3728 5020 2260 Intermediate 4728 9-5/8"47#NT8OS 29-4756 29-4230 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-10436 26-8561 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2255 2255 12.Stimulation or cement squeeze summary: Intervals treated(measured): (`°"NNE NOV Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -15158 100 1860 Subsequent to operation: -16351 38 2985 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG IZI GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-491 Authorized Name: Chamansingh,Ann Marie Contact Name: Chamansingh,Ann Marie Authorized Title: Petroleum Engineer� // Contact Email: AnnMarie.Chamansingh@bp.co Authorized Signature:,a�w0 ngidw Date: 6/07,po/7 Contact Phone: +1 9075644070 Form 10-404 Revised 04/2017 �,b,Ay/, V7] `d `` il f RBDMS _ JUL - 6 2017 Submit Original Only • i $i S Alaska Oil and Gas Conservation Commission RECEIVED 333 West Seventh Avenue Anchorage, AK 99501-3572 JUN 2 9 2017 AOGcc RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary June 27, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for the next MIST Bulb Injection in Well 03-36A, PTD # 207-020. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Plugs Attachment PBU 03-36A SW Name Date MD Description 03-36A 05/24/2017 12600 4-1/2"WFD CIBP 03-36A 05/10/2015 12980 4-1/2" CIBP 03-36A 02/24/2014 13620 4.5"WFD CIBP 03-36A 09/12/2012 14180 4-1/2"CIBP 03-36A 02/09/2009 14650 4-1/2"WFD CIBP • • w Q,o00000 R N CSD 53 53 7, cqV O N Oe- Tr CD M M01 M O CO N '4t CO N Ln Co N- 00 co O N M N oD N M Co O v_ I� N QD O CO M Tr CO CD CO CI 1 1 1 1 1 M OD N O CD M Tr Co M M N I ) N Tr OO 4:1) O CO M CO 0) Lr) co � M Tr VCI SCO OIC Q M N o 0) o ; Co _ M M N 0 N o e- M co a W o00 O O J 0 OD OD Z co J J d1- 4ZJ8 % + • OD V O aro' ZNI 01.12 M in N CD 4 4 O 0 N co O C CO O) I� CD O) JCr) LC) .4- Oa W cc• 0 Q U • W W V O u_ t ceZ Z LLI LU Lu O Z Z U U) Z J J I- • • a1 H a3 • ,- Tr CO O) C') v- d1 N. � N In T- 0 t Ln ti ,- T t . CO 00 . . CO O O up M , N..: M Tr Tr M M CO Cfl Ln Ln Ln CO Ln m co Tr Tr Tr Tr c) Tr Tr c) c) 0 Tr 0 0 0 Tr 0 Tr 0 C3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0) 0) 0) 0) 0 0 0 O O) O) 0) I- C2 O I- C') Co') Ch00MMO) — O) N. 0) N t ,r d' 1- — N Tr ,- CO CO CO O) 0) O N- n. CflMMd' MM00000LnLC) LUL0000 0 M rf V tt Tr Tr d' Tr Tr Tr Tr O W 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0) > p 0) 0) 0) O) 0) 0) O) O) O) O) O O O) O) 0) 0 2 re W 0 w Z w m ~ ~ o g55 o m N O W Y Y H e C M Tr ON) - 00) N O N LOU Ln Co � 0) Tr '- J J J a s N Z O- M 00 00 O) N M 00 00 00 M M T Tr LnLn - Q Q Q W C a N N N N co co co co co C tt V Tf Tr Tr in 0 0 0 J J J 0 -� 0 0 2 0 0 0 W W Z O Z 104( 2220c~i) C) N0) U¢03 ) 4=0 I a 0 ~ L O 1� N N 0 0 0 0 to O Ln O O O I� O c: = p, O ,- 'Tr M O) Ln O N M Ln CO N- O) •- r- a) M CO CO 00 N N I- 00 CO M M Tr Tr Tr Ln O co p N N N N M M M M M Tr Tr Tr Tr d' V Ln L a N Y 0 O cn Cr O c) c~n cai) N 0)) d a O 0 c C LL_ 00cnCnCn00U) (ncn00000000ODfnCn CL a a a a a aCLaaaaaa0_ CL d Qmm03mm030303mmmmmm00 a. O 0 a ar I- Q N- N- N- N- N- N- N- N- N- ti ti N- N- N- N- N O c O O O O O O O O O O O O O O O O w Z O N N N N N N N N N N N N N N N N Z U- < 11 W M M M M M M M M M M M M M M M M 0 W p W V N I.L. J N N N N N N N N N N N N N N N N o a W 0 1LI W W a LLLI O Ln Ln Ln Ln Ln Ln Ln Ln LU Ln lf') Ln Ln Ln Ln Ln m 0 -J W J J D Q O W W < < 0. cn L U :n a cn a d' m E Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q CO CO CO CO CO UD CO CO CO CO CO CO CO COCpCO 3 co M M M M M M CO M M M M M M M M cn M M CM M M M M M M M M MMM CM M co a a a 0 _' a s w a 0000000000000000 < < C0 CO LL LL Cn co a w , • • Packers and SSV's Attachment PBU 03-36A SW Name Type MD TVD Depscription 03-36A SSSV 2254.9 2254.59 4-1/2" MCX I-SSV 03-36A PACKER 4610.85 4139.5 7" Baker ZXP Top Packer 03-36A TBG PACKER 10378.99 8522.73 4-1/2" Baker S-3 Perm Packer 03-36A PACKER 10428.45 8555.86 5" Baker ZXP Top Packer 03-36A PACKER 11849.29 9016.38 4.5"X 5.75"TAM Swell Packer 03-36A PACKER 12415.93 9040 4.5"X 5.75"TAM Swell Packer 03-36A PACKER 13020.22 9043.92 4.5"X 5.75"TAM Swell Packer 03-36A PACKER 13624.55 9045.59 4.5"X 5.75"TAM Swell Packer 03-36A PACKER 14228.36 9045.15 4.5"X 5.75"TAM Swell Packer 03-36A PACKER 14830.5 9045.75 4.5"X 5.75"TAM Swell Packer • • a (13rn= o its 0) o.c O Q - NaarOoLn o_ � m o_-0 0) a) Cl- _ a) O awN m - NN tLL a p t U poc,, ,- cu ca V �. N N CO N 00 a) • Q ,aW W F- a o 2 .� OO a_z.-. z a)CO a co > O M O f) 0 .., f,„ 0 •N CMm � , N a) 2 • cc - = GNU L +-'3 t .0 * V D - N- C ,t ' a) - -a Cr) W NI- NM N a, Eu) OO C ct N Q O C ~ 2 O = 0 la _0"a F- \ a C a3 + ..c w a) (a a' N � W a) O ~ a) to p Q-p u) N 0) a) Q rn (n0 � 0 � •• 0 ' 5 W z Ii -U() 0'COMDY v) O u) W z c o ?Na o � V °= 0Vo a o U0 E co Q o22 = 0N � 2 )ZN .c m 3 >- a- E a) L ., J O m C r-, fn E 2 J = a 20 _ W C U C W Oi m F Q m4ENLi_ < m 0 m= p0 Nin m 0 of co > — cU oNm0 0 o � M ? ao O 0 � , 0 E .nO0 a TD M E N 2 L_ of a)L x a > o a c6 .E a a) M 1 LL CV) . © EO 'Cc ``° c 't ._ � ct ;Cr: U C > ' 0 d rn LS cv 2 0 a) d a o o `— OJ o m 0_2 U TT Lco 4t W-L 2 J .cu N WO N w N 2 � � -F,. Q M z : * UT - F- UaD2 E V H c � : 2O ?� o d * O a) I cnUo2 = o S cn .DNo Q �*WO CL > 0 > Z 00co o -p C a � a) N .No > D � 0 zcn0 0 . C c L( 0W oin ct _ Y � a) �' Et � � 0 0) W p m (0 cit O.. fn +-% < Z -� Q ' i _o2 ON vim 3 zN = 1_ a) N z - V -) Q 0. Ca ea o Two 0 0D m o a °° 5U U2inw o —' - -a 0)) 0 ' 0 ,,, * ZXXv) � O M N LL: - +., + t C In a) a) U U a.N a F- O N F- 0 � � crF- N +. a) _Ne a)� .a) E O o0 ,_ LL CJ W V- Q,- C QO ca p N- E 7 I w m U J uj 0 J V L 0)N C ._ e- "a C V 3 0 J D J o 0 W � JW 4 3 _I ami a3c co _04* Qa.c _0W V < W a) 2o � J 0 = • � tn = a) E E j N � U E0 F- ENDO a a F- OO � � WI . O • : 0a : Um UNNO a_o * 00N Q* * mU * 0InET) W F- N- r N- N- >- O O O O N , ~ N co CV N m N L) >co N N N F- 15 in in U) 0 Q TREE= 4-1/16"OW • WELLHEAD 13-5/8"FMC 03-36A 3_36A S NOTES: H2S READINGS AVERAGE 125 ACTUATOR BAKER ppm WHEN ON MI'"* WELL REQUIRES A SSSV OKB.ELEV= 60.2' I ( WHEN ON MI****WELL ANGLE>70'@ 11116' *'*MAX DOGLEG:12.9° "" BF ELEV= 30' / 11365' KOP= 2700' 20"CONDUCTOR 108' Max Angle= 91°@ 13142' 2254' H4-1/2"HES X NP,D=3.813" 94#,NT6OLE, Datum MD �1 .. D=19 124" • Datum TVD= 8800'SS I. . j—I • . 2900' EST TOP OF CEMENT(06/20/06) 13-3/8"CSG,68#,NT-80 CY FE, H 397T ff. ' D=12.415" TOP OF 4-1/2'LNR —I 4599' V 4599' -19-5/8'X 7"HR ZXP LIP,ID=6.29' 9-518^WHIPSTOCK(04/12/07) --4756' 9 4622' H9-5/8"X 7"FLEX LOCK HGR,ID=6.30" 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" —I ^4756 t• 9-5/8"EZSV(04/12/07) H 4777' ML LOUT WINDOW(03-36A) 4756'-4777' :,..4....-.4.72,111::::;1.-11,*1 I ' 10317' HES�X NP D=3.813" Minimum ID=3.725" @ 10423' 4-1/2" HES XN NIPPLE z 0.. 10379' —17"X4-112"BKRS-3 PKR,D=3.870" ' 10402' H4-1/2"FES X NP,D=3.813" 10416' —112'BKR III63ACK,El=5.250' TOP OF4-1/2"LP H 10416' 1— I 10423' H 4-112"HES XN NP,D=3.725' 4-1/2'TBG,12.6#,L-80 TC11,.0152 bpf,ID=3.958" H 10435' 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" -1 10588' 10428' —{7"X 5"HR ZXP LIP,D=4.350' PERFORATION SUMMARY 10435' �4-112"WLEG,D=3.95$" REF LOG: SLB USIT ON 05/02/07 10439' -�7"X 5"FLIX-LOCK t iGR D=4.350" ANGLE AT TOP PERF: 88°@ 12300' , 10449' H 5"X 4-1/2"XO,D=3.920" Note:Refer to Ftoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ _, „ 11849' —15-3/4"SWELL PKR,D=3.958" 2-7/8" 6 12300-12330 0 05/23/17 I 2-7/8" 6 12817-12842 C 05/13/15 er:4 _l 12415' —15-3/4"SWELL FKR,ID=3.958" 2-718" 6 12842-12892 C 05/12/15 ++ 12600'CTM II—4-1/2"WFD CBP(05/23/17) 2-7/8" 6 12892- 12917 C 05/10/15 11 2-7/8" 6 13230-13290 C 02/24/14 a' --I4-1/2"CLIP(05110115) 2-7/8" 6 13290-13320 C 02/23/14 12980'CTM 2-7/8" 6 13750-13850 C 09/14/12 7,4 C.1 13020' _—5-3/4"SWELL FKR,ID=3.958' 2-7/8" 6 13800-13825 C 09/13/15 I 2-7/8" 6 13825-13850 C 09/11/12 13620'CTM -4-1/2"WFD CUP(02/23/14) 3-3/8" 6 14330- 14355 C 04/11/11 4 '' I -----I13624' --I 5-314"SWELL PKR,D=3.958" 3-3/8" 6 14355-14380 C 04/11/11 2-7/8" 6 14460-14490 C 02/12/09 14180'CTM --I4-112"CBP(09/13/12) 2-7/8" 6 14490-14510 C 02/08//09 '-' .. 14228' 1-45-3/4"SWELL PKR,ID=3.958' 1 3-3/8" 6 14517-14542 C 04/11/11 2-7/8" 6 15010- 15110 C 05/04/07 14650' —14-112"WFD CBP(02/08109) I 0:' �' 14830' (( +5-3/4'SWELL PKR,ID=3.958' PBTD — 15274' 4-1/2"LNR, 12.6#,L-80 TCI,.0152 bpf,D=3.958' —I 15363' 1j•�•j•i DATE REV BY COPE NrS DATE REV BY COI U'4TS PRIJDHOEBAY UNIT 04/29/93 ORIGINAL COMPLETION 02/25/14 I Ift/PJC CPB/ADPERFS(02/23-24/14) WELL 03-36A 05/06/07 MES SIDETRACK(03-36A) 05/14/15 ALM PJC SET MP/ADPERF(5810-5/13) PERMT No:"2070200 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS _06/15/15 PJC 'CSG/LNR/PEWS CORRECTIONS AFI No: 50-029-22340-01 02/16/09 TAR/SV SET CIBP/ADPERF(02/12/09) 05/24/17 MaS/JMJ SET CBA'ADFERFS(05/23/17) SEC 11,T1ON,R15E,910'FSL&899'FWL 01/10/12 TMWJMD ADDED Ii2S SARI Y NOTE 09/18/12 RR1N/JMC CUP&ADPERF(09/13-14/12) _ BP Exploration(Alaska) • I 0,-, 11/7,„„., -.s.6 THE STATE Alaska Oil and Gas .}.. • 1 OfA LA S}(j\ Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov James Shrider Petroleum Engineer Challenger BP Exploration(Alaska), Inc. SCOW ^ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-36A Permit to Drill Number: 207-020 Sundry Number: 316-491 Dear Mr. Shrider: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, ;# iia --)9Lt.,7i&_ Cathy . Foerster Chair DATED this (0 day of October, 2016. RBDMS tA, OCT 1 0 2016 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMISION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0. Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 • Other Stimulate 0 . Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other r tz al,C31Ctc-'( L�� S: C 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-020 • 3• Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic ❑ Service 0, 6. API Number: 50-029-22340-01-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No 0 PBU 03-36A 9. Property Designation(Lease Number): 10. Field/Pools: :_ ADL 0028332 • PRUDHOE BAY,PRUDHOE OIL ' /D I C+' 11. PRESENT WELL CONDITION SUMMARY SEP 2 6 2016 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Jun A( � { 15365 '' 9043 - 12980 9044 See Attachment �../ V Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#NT6OLE 34-114 34-114 2300 520 Surface 3943 13-3/8"68#NT-80 33-3975 33-3730 5020 2260 Intermediate 4729 9-5/8"47#NT8OS 29-4758 29-4231 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 28-10437 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 10380,8523.72 4-1/2"MCX I-SSV 2254, 2253.67 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Shrider,James be deviated from without prior written approval. Email James.Shrider@bp.com Printed Name Shrider,James Title Petroleum Engineer Challenger Signature Phone +1 9075644755 x44755 Date 616-,V A COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No e /( Spacing Exception Required? Yes 0 No 4 Subsequent Form Required: J a — 4 b Y447 P c�/ APPROVED BYTHE Approved by: / `" ...... COMMISSIONER COMMISSION Date/0–6_ r7-i_ io/4-/) 1- ORIGIINML ..,,w RBDMS 1,i- OCT , ° 2016 4f Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate yy714 0 • Plugs Attachment PBU 03-36A SW Name Date MD Description 03-36A 05/10/2015 12980 4-1/2" CIBP 03-36A 02/24/2014 13620 4.5"WFD CIBP 03-36A 09/12/2012 14180 4-1/2" CIBP 03-36A 02/09/2009 14650 4-1/2"WFD CIBP • e p.0 0 0 0 0 0 R N CO CO r- O O t N N Cf) LC) p N Cn f— N- U i 00 O O OCV N- V O O • COCO 00 O CO N Vt V m N Cf) CO N- 00 00 V co co N • CO CO CO V O CO O CO • CO V CO CA CO 1 1 1 1 1 1 "4- 0) • 00 CJ) co Cr a0 Cr) CO N v— (0 N 00 41 CD • CO 00 O LO co `- M O, V 4-1 Q }' t0 CO ,e4-' t M 0) Oc0 C M C'0 M N V ..„7 N • co a w 8 (n co O co CO CO O z E- co J = a) ~ *k Z --� CO CO N N Z c0 4:k O U CA ED C.-?3 O N L_ co cr)C)O �t N 000 0 C 00 0) N- CA CA C) Jch C() W H C O _Q W o .7) ° U 2 LL Zz Z W W W O D F- ZJ Z_ D C.) 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Required? Yes Sundry Form 10-404 Re uired? Yes q Primary Secondary Engineer: James Shrider Contact numbers: (907)564-4755 (907) 699-2669 Well Intervention Engineer: Tyson Shriver Contact numbers: (907) 564-4133 (406) 690-6385 Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907) 360-7485 Date Created: September 13, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Date Oil Rate Inj Rate Gas Injection GOR FTP or Injection Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 9/11/2016 0 4,622 3,328 Current Status: Operable Flowing • Inclination>70°at Depth(ft) 1 1,1 16' MD Recent H2S (date,ppm) Injector Injector Maximum Deviation (Angle and — Depth) 91° 15,089' MD Datum depth,ft TVDss -8,800'TVDss Dogleg Severity(Angle and Depth) 18° 11,139' MD Reservoir pressure(date, psig) 6/24/2015 3,356 psi Minimum ID and Depth 3.725` ` 10,423' MD Reservoir Temp,F 179° F Shut-in Wellhead Pressure Known mech. integrity problems(specifics) None Last downhole operation (date, operation) 8/13/2015 Set MCX Most recent TD tag(date,depth, toolstring OD) 6/23/2015 11260' SLM ITo deviation with 3.25"CENT, 1-1/2"S.Bailer If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? Surface Equipment Checklist. Comments,well history, 03-36A is a MIST injector completed in 2007 To date 03-36A is on its 5th MI bulb Historically MIST background information, injectors have required additional stimulation after perforating in order to achieve desired injection rates. - etc: However the previous perf/MIST bulb successfully achieved injection rates and special underbalance charges where used to help clean up the perfs. Due to the costs and limitations of these underbalance cnar�e are electing to perrorate me rirst interval usin onvenuonai unaeroaiance metnoas wnicn wni forego�Fie ability to perforate the proceeding gun runs underbalance. The objective of this program is to prepare 03-36A for its 6th Ml bulb. • Target MI Rate: 20 mmscf/day • Well Intervention Details • Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 209t. Suspected Well Problem: Current pattern swept Specific Intervention or Well Objectives: 1 Set new injection pattern , 2 3 Key risks,critical issues: Mitigation plan: Underbalance perforating causing debris to pack off behind POOH immediately after guns fire,and if BHA hangs up 1 CT work back and forth instead of pulling too hard and sticking the perf guns 2 Unable to obtain reasonable injectivity with new Perforate—500psi underbalance,and contingent acid perforations stimulation (if injectivity is less than 2bpm @ 2000psi) 3 Unable to access current perforations after next MIST bulb profile modification Mill out previous CIBP Tie in CT once,and if CT needs to tie in again (had to 4 Mulitple runs with coil causing additional tie in loggingcut some pipe),please tie in using the new CIBP(which runhas a known depth) instead of running any additional logging runs 5 Weatherford nitrogen membrane causing extensive corrosion damage to CT and production tubing Use corrosion inhibitor with the N2 membrane Summary Step# Service Line Activity 1 S Pull MCX at 2254'MD 2 C D&T, mill CIBP @ 12,980'MD, Set CIBP @ 12,600'MD, Shoot 90' of perforations (12,300' - 12,390'MD), Injectivity test. Contingent mud acid stimulation (if injection rates are lower than 2 bpm @ 2000psi) 3 S Set new MCX at 2254' MD Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 See detailed procedure 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: 20 BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: POI on MI or FP if needed Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • t Injector Minilog Ei Techlog Protect PBU EWF Prot 1 5590Well: 03-36A Author Laura J.Larson Date 211612016 ktrv.x,SS Br Y 711173 kv.d+.a.,1587 Ki Y'14172 11 SPUD Oar 2007.01.140000 CO ^4h USA -_� ks.s4;;MVP 15115 Y$*N>.11$211009♦ v=.vnpat.N,L .24/7-0460000oe ..M Prudhoe gay I i r:dr ee System ..ate,1ay 70,2307203 01.601 r 6p% .sib AlesSA ------_... U.4Y to-,ups PXA H t n • BEST.GR AC I 0 API 2e•02 Y Rote 01 Pesetrotto» PE info r TVOsS MO BEST liSHAt O , 4 a[sr.ROP (FEET) (FEET) 44. 0.2 014/VIM 200 D o -F MR 500 1:5500 1:5500 Ca 1nctx,TYt?SS ®ESTADEEP 15605000 h 1600 0.2 OHM M 200 .. �. 3205 - $750 . . rem.. 3790 .• fr eels 'jil _.__ ' 3855 - 11000 ----- ---.. "' $885 — _ ... 0410` s 1910 11945 , VP 4 39 0 "11500 _. .___ 8955 t 1 1 8960.. • 8965 :12000 _. irf5 .tion) 8970- _._.._..._— : 8975: \)^ �'-+Jrf;.ti.=y t; • 8980 I ` •. Iv. t , *955. .,.'' `‘�t,Dr" 12500 __t~/ • 11000 alE.e.. . 8990. m • 'tom".• ^14000- -- '. 1990 F . 4 • :i _ 3 - - i J.....___. .'` , 8990 r8490 ' _.., -15000+---_._-- `r' I- 3990 ; SW _ r a .1 1 • • ADW PENDING PERFORATING PROCEDURE Well: 03-36A API#:50-029-22340-01 Date: 9/13/2016 Prod Engr James Shrider Office Ph: (907)564-4755 H2S Level: ..._........_..... Home Ph: _.._. ..............Injector ppm Cell/Pager: (907)699-2669 CC or AFE: APBINJEC _........................................................... WBL Entries IOR Type Work Description • • ;See Procedure •• •Well Objectives and Perforating Notes: See Procedure. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 0 feet Log: USIT/CBL/... Coil Flag -t-- --------- ..................._..................... .. to the tie-in log to be on Date: 5/3/2007................... 2/22/2014 depth with the reference log. Company: Schlumberger PDS Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 12,,30' 12,390' 12,300' 12,390' 90 6 Random 60° 2C Ad-Perf • .........._...__.... Requested Gun Size: 2-7/8" Charge: Maxforce(or equivalent) Is Drawdown Necessary/Desired/Unnecessary During Perforating 500 psi drawdown desired for 1st perforation run.Achieve byde ressin FL with N2 Preferred Amount of Drawdown/Suggestionsthe....ord's...._.embrandown to ........................................................P. 9 to Achieve Drawdown using Weatherford's membrane down to 2850'MD Last Drift: 11260'SLM ft MD on 6/23/2015 Est Res.Pres.@ -8,800'TVDss MD is 3356 psi Perforation Summary Summary Dist Well: 03-38A Town: Date: API N: 50-029-22340-01. Prod Engr: Anch Prod Engr P.D.Center PBTD General Comments: Depths ....__._.. ._... _.. Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U O/B/U • ._..__ .,,..... _... ..._... .._.. 0/B/U _...... _..... __... .. 0/B/U _..... ................ O/B/U _...... ....._ ._.. .. ...... 0/B/U - _....._.... ............... 0/B/U _.... _.. .._.....-.... _. 0/B/U - _.............. ............ • CTU: Mill Plug,Set CIBP, Perforate 1) Spear in 5 bbls of 60/40 methanol followed by 200 bbls of KCI into tbg at max rates (do NOT exceed 5000 psi) NOTE: this will knock down the WHP and fluid pack the well (methanol is to prevent hydrates) 2) RU 3 blade junk mill and RIH, Drift and tag CIBP @ 12,980'MD 3) Mill out CIBP @ 12,980' CTM and push to bottom (which will be next CIBP @ 13,620' CTM NOTE: this will allow for future access to last 2 perf intervals 4) Bullhead N2 using membrane to depress fluid level down to 2650'MD NOTE: this will create sufficient drawdown for underbalance perforating 5) RIH flag CT, and set CIBP @ 12,600'MD • 6) Bleed WHP to—0 psi 7) RIH with 2-7/8" MAXForce perforation guns and perforate from 12,360'-12,390' MD, 12,330'-12,360' MD, & 12,300'-12,330'MD • Perform a maximum of 3 gun runs • If cutting CT is required before perforating is complete, please use recently set CIBP to tie-in with (instead of completing another logging run) • Initial perforating interval will be "'500psi underbalance, use caution (other 2 perf intervals will likely be in equilibrium) 8) After perforating is complete perform injectivity test ▪ Spear in 5 bbls of 60/40 methanol first (hydrate preventions) ▪ Pump injectivity test using 1% KCI • Desired injectivity is >2 bpm @ 2000 psi, if rate is less than that please perform contingent mud acid stimulation Detailed Procedure Page 1 of 4 • • CTU: Acid Stimulation Fluid Recipes Detailed Procedure Page 2 of 4 • • CTU: Acid Stimulation Pre-Acid NOTE a) We are not planning to flowback the acid. It is critical to push the acid stimulation chemicals far enough into the formation (after the stimulation is complete) to prevent near wellbore damage. CT Mud Acid Stimulation 1) Ensure both the lateral and wing valves are SI. PT and pickle CT with 5 bbls of 12% HCL(if necessary). • Filter all fluids possible that will enter the formation to 3 microns onsite immediately prior to pumping downhole • Do not add friction reducer to stimulation fluids that will enter the perforations • Do not exceed 0.65 psi/ft gradient(1875psi WHP after fluid packed with NH4CI) during liquid packing or any other time during the job. The exception to this is if the diversion works very well at plugging up the perforations (then it is okay to go up to 5000 psi wellhead pressure if necessary to complete the job after the diversion is in place) • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR • Acid strength to be verifited and documented via titration before leaving Schlumberger. Please note the acid titrations on WSR and have results available on location • Record time, rate, wellhead pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Send electronic copy of the treatment report to James Shrider(mailto:James.Shrider@bp.com) • A production tubing pickle is not necessary because we will be acidizing with CT 2) Drift to CIBP with Ball Drop Nozzle 3) PU CT to just above perforations and fluid pack the well (ensure positive WHP) a) Pump 200 bbls of NH4CI (down CT and Tbg) -The objective is to displace all the gas from the wellbore b) Pump 133 bbls of diesel (down Tbg only-CT backside) - Results in ^'100psi WHP using last reservoir pressure 5) Before pumping acid, hold a safety meeting 6) Pump the following fluids down CT at maximum rate (below 0.65 psi/ft frac gradient) a) Obtain pre-acid injectivity test and note on job report b) Reciprocate across all perforations during the first acid stage, prior to pumping diversion c) Keep nozzle above perforations (12,300' MD) after diversion to avoid sticking the CT e) Maximum WHP of 5000 psi if necessary after diversion (if diversion completely plug up perforations) Detailed Procedure Page 3 of 4 • • 7) Obtain post-job injectivity test and note on job report 8) Freeze protect well if needed (pending time between RDMO and POPing through ASRC). POOH & RDMO. Post-Acid ACID Flush: CT 1) Pump additional 420 bbls of 1% KCI (to push acid far enough into the formation to prevent damage) 2) FP with 38 bbls of 60/40 methanol Detailed Procedure Page 4 of 4 i 0 t-1 • . to i ozz s }lo Eji..pp�mi CO0.-, Q�tfirtf 2iT tii Z.) e 1 1 1 . < c ° R J :n 0 i Q al- —� 0 4.0 .45LU Q T SIX u Ilii ail�qyd� 2 ie Q a Ce Q g L(11 , i CO Ow ODT --IQ 0307 �` ' I i ` '88881 `c 1 t--- ,hip N' Cr)X (CI d "' z61 N �.��,aaa f41)--65rl A A a I E Li. in ri }�T ih m ,-Ice p { TS w ■/�■ c T o I . Yi ( T A 1 I I j_ # jj,� w-- u. IL Ey3 it Iv E .frVI) ` 1 V W I '�t pNz LL j -i • 4 ' Q���V+ iF a O N 4? p if �1 l� 1 �i I a' , '"y��I i i O it CD •zj • $'a j °' o s g i.... Aillgl C 1!►' " eleeld Ns adois twoN Onoog 1 1 , • 11 • _1.®gaop Pia] o S ice; I - , �Ii3 v a p oI • adt� lea0 iJ pi�'1+i tilt m 0111 `(e)fseJ ) uoITeoldxB d8 Auedwo3 i §m co I o li ii �amaam)-0t-2 .ir-1w.�0aW 1 t, Di ees.t .t,-,. (.,, 00...,..e. 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M't : IREE= 41/16"CIW VVH LhEAD 13518"FMC • 0 3-3 6A ON: H2S READINGS REQUIRES 125 ACTUATOR BAKERSSSV OKB.ELEV` 60.2' WHEN ON MI"" W E1 ANGLE>70°@ 11116' BF ELEV= 30' I I I '"MAX DOGLEG:12.9°Cd? 11365'"" KOP= 2700' '20"CONDUCTOR, '-j108' 1 Max Angle= 91°@ 13142' 2254' -4-112"HFA X NP,D=3.813' 944,NT6OLE — — Datum MD 10888' 4, Datum TVD= 8800'SS 1:1= 19.124" 13-3/8"CSG,68#,NT-80 CY HE, -{ 3977' .•I I 2900' �-LEST TOP OF CEMENT(Ofi/20/06) D=12.415" TOP OF 4-112"LM4599 I� ' y- 4599' H9-5/8"X 7"HR ZXP LTP,FD=6.29" 19-5/8'W-IPSTOCK(04/12/07) h 4756' ....................... \`' 4622' -9-5/8'X 7"FLEX LOCK HGR,D-6-30" 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" I-I ^-4756 9-5/8"EZSV(04/12/07) --I 4777' MLLOUT WINDOW(03-36A) 4756'-4777' • :;:�� :� �\: I Minimum ID=3.725" @a 10423' 4-1/2" HES XN NIPPLE 1 I I 10317' H4-1/2"1 X Fes,D=3.813" Z e 10379' I-7'X 4-1/2"BKR S-3 PKR,D=3.870" I I 10402' I-4-1/2"HES X NP,D=3.813" I TOP OF 4-1/2"LAP 1-1 10416' I--{12'BKR TEBACK,D=5.250" 10416' 1 10423' I-14-1/2"I IM XN NP,D=3.725" 4-112"TBG, 12.6#,L-80 TC11,.0152 bpf,D=3.958" I- 10435' 7"LM ,26#,L-80 BTC-M, 0383 bpf,D=6.276" H 10588' r, 10428' H7"X 5"HR ZXP LTP,D=4 350" 10435' -14-1/2"WLEG,D=3.958' PERFORATION SUMMARY REF LOG: SLB USIT ON 05102/07 10439' 1--17"X 5"FLEX-LOCK HGR.13=4.350" ANGLE A T TOP FERE 90"@ 1281 T , 10449' H5'X 4-1/2-X O,D=3.920" Pbte:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ►_ 011 11849'1-I5-3/4"SWELL PKR 13=3.958" 2-7/8" 6 12817-12842 0 05/13/15 ►� 12415' _HI5-314"SWELL PKR D=3.958" 2-7/8" 6 12842- 12892 0 05/12/15 1111 2-718" 6 12892-129171 0 05/10/15 4 \- � I `12980'CTM J4 1/2"CEP 05/10115) 2-7/8" 6 13230-13290 C 02/24/14 CO3 2-7/8" 6 13290- 13320 C 02/23/14 CI C,4 13020' I—I5-314"SWELL PKR D=3.958" 2-7/8' 6 13750- 13850 C 09/14/12 ' _ 2-7/8" 6 13800- 13825 C 09/13/15 113620'CTM H4-1/2"WFD GBP(02/23/14) I 111.4 2-7/8" 6 13825- 13850 C 09/11/12 o.7,4 " 13624' -5-3/4'SWELL PKR,D=3.958' 3-3/8" 6 14330-14355 C 04/11/11 I _ 3-3/8" 6 14355- 14380 C 04/11/111 '14180'CTM ---I4-1/2"CEP(09/13/12) 2-7/8" 6 14460-14490 C 02/12/09 '� ='------1 14228' 1-5-3/4'SWELL PKR, ID=3.958' 2-7/8" 6 14490- 14510 C 02/08//09 ' 3-3/8" 6 14517- 14542 C 04/11/11 14650' -14-1/2"WFD CEP(02/08/09) 2-7/8" 6 15010- 15110 C i 05/04/07 lc. C" IIII �� 14$30' j 53/4"SWELL PKR, ID=3.958" J PBTD 15274' 4-1/2"LM, 12.64,L-80 TCI,.0152 bpf,D=3.958" H 15363' I 0;0'4•1ti DATE I REV BY COMMENTS DATE REV BY COM/EMS i F1&E*IOE BAY UNIT 04/29/931 ORIGINAL COMPLETION 02/25/14 I IR/PJC CPB/ADPFRFS(02/23-24114) WELL 03-36A 05/06/07 N7ES SIDETRACK(03-364) 05/14/15 ALM PJC SET CEA'ADPERF(5810-5/13) FERMT No:`2070200 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS 1_06/15/15 PJC CSG/LNC/PERES CORRECTIONS AR No: 50-029-22340-01 02/16/09 TAR/SV SET asp/ADPERF(02/12/09) SEC 11,TUN,R15E 910'PSL &899'FWL 01/10/12 TMyJM)ADDED H2S SAFETY NOTE '09/18/12RRW/JM:CEP&ADPERF(09/13-14/12) BP 6cplaration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission � DATE: Thursday,May 19,2016 TO: Jim 6-1z511(#lC P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 03-36A FROM: Jeff Jones PRUDHOE BAY UNIT 03-36A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-36A API Well Number 50-029-22340-01-00 Inspector Name: Jeff Jones Permit Number: 207-020-0 Inspection Date: 5/12/2016 Insp Num: miUJ160515155400 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r -__03-36A - Type Inj G 'LTVD 8523 Tubing 2297 - 2302 • 2294 2297 - PTD 2070200 Type Test SPT Test psi 2131 - IA 145 3000 • 2954 2933 • — Interval 4YRTST PAF P ✓ OA 117 � 230 221 - 211 - Notes: I well inspected,no exceptions noted. SCANNED SEP. 2 7 2016 Thursday,May 19,2016 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, May 07, 2016 6:27 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Regg,James B (DOA); AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector 03-36A (PTD#2070200) POI pre-AOGCC MIT-IA All, Injector 03-36A (PTD#2070200) passed a pre-AOGCC MIT-IA to 3700 psi on June 25, 2015 proving two competent barriers. The well had not been on injection due to flowline work which is now complete. This injector has no known integrity issues and has been made Operable. Plan forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: AOGCC MIT-IA once well is online and thermally stable Please call with any questions or concerns. Jack Lau ` � (Alternate:)Adrienne McVey Sp1 Nva BP Alaska-Well Integrity Superintendent Wells vi(tadOrganization01gan� t;on Mg 1 1 2016 907.659.5102 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIllntegrityCoordinator@bp.com> Sent: Thursday, July 16, 2015 2:53 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OIL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Pettus, Whitney; Sternicki, Oliver R Subject: NOT OPERABLE:Injector 03-36A (PTD# 2070200) Due for AOGCC MIT-IA All, Injector 03-36A (PTD#2070200) is due for an AOGCC MIT-IA by the end of July 2015. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until ready to be placed on injection and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus SEAMED JUL 2 12015 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GIN WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator(n)BP.com 1 STATE OF RECEIVED i 3KA OIL AND GAS CONSERVATION COM' 3ION REPORT OF SUNDRY WELL OPERATIONS JUN 1 6 2015 1 Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing] � wn ❑ Performed Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casin❑ Chadgar am ❑ Plug for Redrill fl erforate New Pool ❑ Repair Well n Re-enter Susp Well n Other 5C7 6149 f 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory ❑ 207-020-0 3 Address P O Box 196612 Stratigraphic ❑ Service E 6 API Number Anchorage,AK 99519-6612 50-029-22340-01-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028332 PBU 03-36A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary. Total Depth measured 15365 feet Plugs measured See Attachment feet true vertical 9043 12 feet Junk measured None feet Effective Depth measured 12980 feet Packer measured See Attachment feet true vertical 9043 92 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 26-106 26-106 1490 470 Surface 4726 13-3/8"68#NT-80 30-4756 30-4229 65 5020 2260 Intermediate None None None None None None Production 4729 9-5/8"47#NT8OS 27-4756 27-4229 65 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED U 1 7 20? True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 26-10435 26-8560 24 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"MCX I-SSV 2254 2253 69 SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 0 0 12801 0 1566 Subsequent to operation 0 0 0 0 0 14 Attachments(required per 20 MC 25 070 25 071,8 25 283) 15 Well Class after work ' Daily Report of Well Operations 0 Exploratory Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil ❑ Gas U WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays(d7bp.com Printed Name Nita Summe ,. Title Data Manager Signatu - `i7r1�� 1111, ix� Phone 564-4035 D t 6/16/2015 RBDM&At JUN 1 1 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028332 CTU 6 Scope:Set CIBP and Adperf MIRU CTU6. RIH w/memory GR/CCL and 3.70"drift nozzle. Tag at 13,295'CTM(PBTD= 13,620'). Attempt to jet through without success. Drifted deeper than desired CIBP set depth; proceed with depth control log. Log up from 13,284'-12,950'. Paint blue/orange coil flag. Continue logging up. 5/9/2015 ***Job In Progress*** CTU 6-1.75"Coil Scope:Set CIBP and Adperf POH with memory GR/CCL and 3.70"drift nozzle. Download data. +16.5'correction. MU/RIH with WFT 4.5"CIBP.Set CIBP at 12,980'.Set weight 3-5k down on plug,pressured up to 1500 psi and held.Pumped 10 bbls methanol down the backside while POOH. MU/RIH gun run#1,25'of 2.88" perforating guns with 6 SPF,60 deg phasing and 2906PJN charges.Perforated(using slick 1% KCL)from 12892'to 12917'. POOH.MU/RIH gun run#2,25'of 2.88"perforating guns with 6 SPF, 60 deg phasing and 2906PJN charges. While RIH,found damaged area of coil at 9260'below minimum wall thickness. POH. FP wellbore with 34 bbl 50/50 methanol. LD unfired Gun#2. Pumpers RU to blow down reel. 5/10/2015 ***Job in Progress*** CTU 6-1.75"Coil Scope:Set CIBP and Adperf Continued from 5/10/15. Blow down reel. RDMO to yard for pipe swap. Road back to location after pipe swap. 5/11/2015 ***Job In Progress*** CTU 6-1 75"Coil Scope:Set CIBP and Adperf MIRU CTU6. Drift coil with 1.25"ball. Perform weekly BOP test. MU/RIH gun run#2,25'of 2.88" perforating guns with 6 SPF,60 deg phasing and 2906PJ Nova charges.Perforated(using slick 1%KCL)from 12867'to 12892'. POOH.MU/RIH gun run#3,25'of 2.88"perforating guns with 6 SPF,60 deg phasing and 2906PJ Nova charges. Perforated(using Slick 1%KCL w/Safelube) from 12842'to 12867'. POOH. MU/RIH gun run#4,25'of 2.88"perforating guns with 6 SPF,60 deg phasing and 2906PJ Nova charges. 5/12/2015 ***Job In Progress*** CTU 6-1.75"Coil Scope:Set CIBP and Adperf Continued from 5/12/15. RIH w/gun run#4,25'of 2.88"perforating guns with 6 SPF,60 deg phasing and 2906PJ Nova charges. Perforated 12817'-12842'. POOH. MU/RIH w/gun run#5, 30'of 3-3/8"P3 charges at 0.5 SPF. Perform dynamic under-balance from 12890'-12920'. POOH. MU/RIH w/gun run#6,30'of 3-3/8"P3 charges at 0.5 SPF.Perform dynamic under- balance from 12865'-12895'.POOH.Cut Pipe,Change Packoffs,Inspect Chain,MU WFD MHA. MU/RIH w/gun run#7,30'of 3-3/8"P3 charges at 0.5SPF.Perform dynamic under-balance from: 12840-12870'. "*"Job Continued on 5/14/2015*** Note:Dynamic underbalance charges do not perforate the casing and are not'perforations' 5/13/2015 CTU#6 1.75"Coil Scope:Ad Pert,Injectivity Test Continued from 5/13/2015. POOH with Gun#7. MU/RIH with gun#8,30'of 3-3/8"P3 charges at 0.5spf.Perform dynamic under-balance 12815-12845'. Perform injectivity test,maintained 0.8 bpm at 2000 psi.Pumped 40 bbl 50/50 methanol FP down the backside.POOH.Break down guns.Rig down CTU 6. ***Job Complete*** Note:Dynamic underbalance charges do not perforate the casing and are not'perforations' 5/14/2015 • FLUIDS PUMPED BELS METH 88 SLICK 1%KCL W/SAFELUBF 401 50/50 METH 204 SLICK 1% KCL 693 TOTAL FLUIDS PUMPED GALS 598 N2 598 TOTAL Perforation Attachment ADL0028332 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03-36A 5/13/2015 APF 12817 12842 9043.43 9043.74 03-36A 5/12/2015 APF 12842 12892 9043.74 9044.18 03-36A 5/10/2015 APF 12892 12917 9044.18 9044.19 03-36A 5/10/2015 BPS 13230 13290 9043.23 9043.43 03-36A 5/10/2015 BPS 13290 13320 9043.43 9043.8 03-36A 5/10/2015 BPS 13750 13800 9046.19 9046.61 03-36A 5/10/2015 BPS 13800 13825 9046.61 9046.89 03-36A 5/10/2015 BPS 13825 13850 9046.89 9047.1 03-36A 5/10/2015 BPS 14330 14355 9045.61 9045.7 03-36A 5/10/2015 BPS 14355 14380 9045.7 9045.81 03-36A 5/10/2015 BPS 14460 14470 9045.9 9045.92 03-36A 5/10/2015 BPS 14470 14490 9045.92 9045.95 03-36A 5/10/2015 BPS 14490 14510 9045.95 9046 03-36A 5/10/2015 BPS 14517 14542 9046.02 9046.11 03-36A 5/10/2015 BPS 15010 15110 9047 9045.36 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • 0 O_ O O O O o CO CO 0 co to r N • f� N N- U y © 0 0 0 0 0 i 0) V CO N (N CO 3 "CrN V co O V m r N.- CO CO LC) CO °0 r co CO N O r CO O) O) O N.-- co V N N CO CO 0 N N L() CO O V V CO H 1"-- LO COnj N r` O O N M nT N CO N r LO V CO CO ML() a) CO CO CO 0 0 C`7 O tf) M r O LC) O r r r 0 co I I +, N ++ M rn 0 M CO CO N NN N = .Q O � J 9 000000 0 °0 00 V O J a0 I a) = z N CO r O) N U _ = ---.CV p0 0 CV NO co ot) co a) °O V N co O C CO 0) O) f� J LO V C V CY a)0 O - . I— w 0aCCCC Z O Z Z D D U J J d CO H Packers and SSV's Attachment ADL0028332 SW Name Type MD TVD Depscription 03-36A SSSV 2254 2253.69 4-1/2" MCX I-SSV 03-36A PACKER 4599 4132.17 7" Baker ZXP Top Packer 03-36A PACKER 10379 8522.74 4-1/2" Baker S-3 Perm Packer 03-36A PACKER 10428 8555.56 5" Baker ZXP Top Packer 03-36A PACKER 11849 9016.37 4.5" X 5.75" TAM Swell Packer 03-36A PACKER 12415 9039.98 4.5" X 5.75" TAM Swell Packer 03-36A PACKER 13020 9043.92 4.5"X 5.75" TAM Swell Packer 03-36A PACKER 13624 9045.59 4.5"X 5.75" TAM Swell Packer 03-36A PACKER 14228 9045.15 4.5" X 5.75" TAM Swell Packer 03-36A PACKER 14830 9045.74 4.5" X 5.75" TAM Swell Packer IHEE= 4-1/16'CM/ VA3_LFEAD 13518"RC 0 3-36A S. /Y NOTES: H2S READINGS AVERAGE 125 ACTLIATOf BAKER ppm WHEN ON MI A SS (AGB 7 BF.11B/= 30' WHEN ON M I"" WELL ANGLE>70'@ 11116' 1 I '"MAX DOGLEe 12.9°(®11365"" KOP 2700 20'CONDUCTOR. 108' I 2254' —4-12'HES X NP,D=3.813' Max Angle= 91'(ED 13147 94# NT60LE Ctitum ND= 10888' �� D=19.124' Datum 1\11:1;--- 8800'SS '. 2900' —EST TOP OF CEMENT(06/20/06) 13-3/8'CSG,68#,NT-80 CY HE, —I 3977' D=12.415' TOP OF 4-1/2'LNR — 4599' 4599' —9-5/8'X 7'HR ZXP LTP,D=6.29" WV 9-5/8' HPSTOCK(04/12/07) — 4756' 4622' —9-5/8"X 7'FLEX LOC(HGR,D=6.30' 9-5/8'CSG,47#,NT-80S NSCC,D=8.681' —I "-4756 [9-5/8'EZSV(04/12/07) I— 4777' AMLLOUT WAIDOW(03-36A) 4756'-4777' \ ./ Minimum 10=3.725" @ 10423' 4-1/2" HES XN NIPPLE I 1031T 4-12"HES X NP,D=3.813" z 10379' —7"X 4-12"BKR S-3 FKFl,D=3.870" I 10402' H4-12"FES Xl*,D=3.813" 10416' -I12'BKR TLBACK,0=5.250' TOP OF 4-1/2'LNR H 10416' I— 10423' —4-1/2 HES XN NP,D=3.725' 4-1/2'TBG, 12.6#,L-80 TC11,.0152 bpi,ID=3.958' H 10435' ' 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276- — 10688' \s: ' F 10428' —T X 5"HR ZXP LTP,D=4.350' 10436' —4-1/2'WLEG,D=3.958" PERFORATION SUMMARY REFLOG: SLB UM-ON 0502107 10439' —Ir X 5"FLEX-LOCK HGR,D=4.350" ANGLE AT TOP PERF: 90'@ 1281 T , 10449' —5"X 4-12'XO,D=3.920^ Note:Refer to Production DB for historical pert data ' SFZE SPF IITERVAL Opn/Sqz SHOT SQZ .I C. 11849' }'5-3/4"SWELL PKR D=3.958' 2-78'. 6 .12817-12842 0 05/13/15 C, CII 12415' —5-3/4'SWELL PKR,D=3.958" 2-78" 6 12842-12892 0 05/12/15 I 2-7/8' 6 12892- 12917 0 05/10/15 112980'CTM —14-12'CEP(05/10/15) 2-7/8' 6 13230 13290 C 02/24/14 2-78" 6 13290- 13320 C 02/23/14 :. _� 13020' —5 3/4"SWELL PKR D=3,958' 2-7/8" 6 13750- 13850 C 09/14/12 I 2-7/8' 6 13800- 13825 C 09/13/15 13620'CTM —4-1/2"VVF D CEP(02/23/14) 2-7/8' 6 13825- 13850 C 09/11/12 •'- 13624' —15-3/4"SWELL PICK D=3.958' 3-38' 6 14330- 14355 C 04/11/11 338" 6 14355- 14380 C 04/11/11 14180'CTM i4 1/7 C8P(09l13/1z) 2-78" 6 14460- 14490 C 02/12/09 �r 14228' H53/4'SWELL PKR.D=3.958' 2-7/8' 6 14490-14510 C 02/08//09 I 3-3/8" 6 14517-14542 C 04/11/11 14660' H4-1/2'WFD GBP(02/08/09) 2-7/8" 6 15010- 15110 C 05/04/07 1'14 CI 14830' —5-3/4'SWELL PKR,D=3.958' I PBTD I— 15274' ]_ I [4-12'LNR, 12.6#,L-80 TCA.0152 bpi,D=3.958" — 15363' 1 F:::::: DOTE REV BY COHABITS DATE REV BY CI:A BITS PRt1]-DE BAY LPIT 04/29/93 _ORIGINAL COMPLETION 02/25/14 TTR/PJC C)F8/ADFERFS(02/23-24/14) WCL 03-36A 05/06/07 N7ES SIDETRACK(03-36A) 05/14/15:ALM PJC SET CSP/ADFE F(5810-5/13) FERMI-No:' 070200 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS 06/15/15 PJC CSG/LW/FER S CORRECTIONS AR No: 50-029-22340-01 02/16!09 TAR/SV SET CEP/ADPERF(02/12/09) SEC 11,T1ON R15E 910'FSL 8 899'F WL 01/10/12 TMWJM)ADDED IIZS SAFETY NOTE 09/18/12 RRW/JAk CEP 8 ADPL(09/13-14/12) 1, BP Exploration(Alaska) Image jest Well History File Cc~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~' ~ - ~~~ !~ Well History File Identifier Or anizing (done) ^ Two-sided III (I'III II III II III ^ Rescan Needed III II~III II II III III g RE/SCAN C for Items: Greyscale Items: ~ ~'~ ^ Poor Quality Originals: ^ Other: NOTES OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: DIGITAL DATA ~iskettes, No. ^ Other, No/Type: BY: Maria Date: ~' /s~ ~ Pro-ect Proofing J 6Y: Maria III 111111 IIIII II III Date: ~ /s/ Scanning Preparation ~ x 30 = BY: Maria Date:. ~^ ~ ~ Production Scanning Stage 1 BY: Stage 1 BY: + ~_ =TOTAL PAGES / ~' ~ ~~ (Count does not include cover sheet) /s/ Page Count from Scanned File: (Count does include cov neet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~j~ ~ ~~"~ /s/ ~~ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: ~s ~ ~~ ~ ~ ^~ u~ u u i ~ n Scanning is complete at this point unless rescanning is required. ReScanned III 111111 IIIII II III BY: Maria Date: ~s~ Comments about this file: Quality Checked III II'lll III II'I III 10/6/2005 Well History File Cover Page.doc OF T�� 0w\����y7.-e4 THE STATE Alaska Oil and Gas of ALASKA ommissi®n ALAS1KA GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS r ,,., Main: 907.279.1433 switiED 1 , � tJ �� : Fax: 907.276.7542 Higino Dos Santos Petroleum Engineer , D AC}._ BP Exploration (Alaska), Inc. �® P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-36A Sundry Number: 313-579 Dear Mr. Santos: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, PL- Cathy P. , oerster Chair, ommissioner tkit DATED this�day of November, 2013. Encl. 1 ' FREE 7E1 ::... STATE OF ALASKA `,I`i 2.013 • ALASKA OIL AND GAS CONSERVATION COMMISSION , � /,� APPLICATION FOR SUNDRY APPROVALS OTGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 g-,..i3 Perforate 0 Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Avigil Stimulate[0 Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 207-020-0 3.Address: Stratigraphic ❑ Service 0 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22340-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 3419 PBU 03-36A Will planned perforations require a spacing exception? Yes El ajJ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028332 ' PRUDHOE BAY, PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 15365 ' 9043 - 14180 9045 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 26-106 26-106 Surface 4726 13-3/8"68#NT-80 30-4756 30-4229.65 5020 2260 Intermediate None None None None None None Production 4729 9-5/8"47#NT8OS 27-4756 27-4229.65 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 26-10435 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(It): See Attachment for Packer Depths 4-1/2"MCX I-SSV 2254',2253.69' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory ❑ Development ❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG 0 ' Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Higino Dos Santos Email Higino.Dos Santos©BP.Com Printed Name Higin• Dos S.y7. Title Petroleum Engineer ■ /n Signature 0111/1, one 564-4342 Date Prepared by Garry Catron 564-4424 4A U 05. 13 / p, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. --SkS " S`1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ RBDMS NOV 25 16, Other: mil" Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0- y o-1 APPROVED BY Approved by: P 9a494___ COMMISSIONER THE COMMISSION Date: �� _/3 /(Z/-/3 ( \�1 Form 10-403 Revised 10/2012 OARofe9ilffAvIlI for 12 month rom the date of approval. Submit Form and A ment in Duplicate �. • • Plug Attachment ADL0028332 Well Date MD Plug Type TVD 03-36A 9/12/2012 14180 4-1/2" CIBP 9045 03-36A 2/9/2009 14650 4-1/2"WFD CIBP 8991 A Casing Summary ADL0028332 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade CONDUCTOR 80 20"91.5# H-40 26 106 26 106 1490 470 H-40 LINER 5989 7"26# L-80 4599 10588 4132 8662 7240 5410 L-80 LINER 4947 4-1/2" 12.6# L-80 10416 15363 8548 9043 8430 7500 L-80 PRODUCTION 4729 9-5/8"47#NT8OS 27 4756 27 4230 6870 4760 NT8OS SURFACE 4726 13-3/8"68#NT-80 30 4756 30 4230 5020 2260 NT-80 TUBING 10409 4-1/2" 12.6# L-80 26 10435 26 8560 8430 7500 L-80 ID Perforation Attachment ADL0028332 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03-36A 9/14/12 APF 13750 13800 9046 9047 03-36A 9/13/12 APF 13800 13825 9047 9047 03-36A 9/11/12 APF 13825 13850 9047 9047 03-36A 9/11/12 BPS 14330 14355 9046 9046 03-36A _ 9/11/12 BPS 14355 14380 9046 9046 03-36A 9/11/12 BPS 14460 14470 9046 9046 03-36A 9/11/12 BPS 14470 14490 9046 9046 03-36A 9/11/12 BPS 14490 14510 9046 9046 03-36A 9/11/12 BPS 14517 14542 9046 9046 03-36A 9/11/12 BPS 15010 15110 9047 9045 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028332 Well Facility Type MD Top Description TVD Top 03-36A SSSV 2254 4-1/2" MCX I-SSV 2254 03-36A PACKER 4599 7" Baker ZXP Top Packer 4132 03-36A PACKER 10379 4-1/2" Baker S-3 Perm Packer 8523 03-36A PACKER 10428 5" Baker ZXP Top Packer 8556 03-36A PACKER 11849 4.5"X 5.75"TAM Swell Packer 9016 03-36A PACKER 12415 4.5"X 5.75"TAM Swell Packer 9040 03-36A PACKER 13020 4.5"X 5.75"TAM Swell Packer 9044 03-36A PACKER 13624 4.5"X 5.75"TAM Swell Packer 9046 03-36A PACKER 14228 4.5"X 5.75"TAM Swell Packer 9045 03-36A PACKER 14830 4.5"X 5.75"TAM Swell Packer 9046 • by Memorandum To: Len Seymour/Clark Olsen Date: October 25th, 2013 Wells Service Team Leaders Jerry Middendorf& Robert Liddelow D&C Wireline Team Leaders From: Higino dos Santos AFE: APBINJEC DS-03 Production Engineer Reviewed: Michael Hibbert, 10/30/2013 Est. Cost: Approved: Steve Kiorpes, 10/30/2013 IOR: 200 Subject: 03-36A CIBP and Add Perf Type Desc. Comment D Perform TIFL to verify tubing integrity S Retrieve 4-1/2" MCX and drift to deviation F Schmoo-B-Gone treatment C Drift/Flag/Log, Set CIBP, Add 90' perforations, Injectivity Test, Acid Stimulation(P) S SBHPS, set 4-1/2" MCX Current Status: WAG injector, SI MI on 11/1/13, will be on water-11/15/2013. Last Injection Rate: 16,055 Mscf/d MI @ 3,082psi on 10/24/2013 Max Deviation: 91° @ 14,115' MD Min. ID: 3.725" @ 10,423' MD (4-1/2" HES XN Nipple) Last Tag: 09/12/2012 -Tagged CIBP at 14,180' MD Last Downhole Ops: 09/25/2012- Performed SBHPS, set 4-1/2" MCX @ 2,254' MD & ran check set Last SBHP: 09/25/2012: 3,339 psi and 177F @ 8,800' TVDSS Latest H2S level: N/A - Injector Last MIT: 03/24/12: MIT-IA passed @ 2,800psi Job Objective: The objective of this procedure is to set a CIBP to isolate all current perforations and to add 90' of new perforations for the fourth MI bulb in the well. If required, an acid stimulation will be performed on coiled tubing to increase injectivity. Also, an opportunistic static bottom hole pressure will be obtained when slickline returns to re-set the MCX safety valve. Well History: • Well 03-36A was side-tracked in May 2007 as a horizontal MI injector. The 4-1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals. The first MI cycle was completed in 2008 and the second Ml cycle began in the first half of 2009. Injectivity in the second set of perforations was always low and the effectiveness of the MI bulb was compromised. The first bulb was successr displaced in 100' of open performs from 15,010'-15,110'. The second zone originally only perforated 50', 14,460'-14,510', and did not successfully get the MI bulb away. Both sets of initial perforations were done without the use of a tie-in run with a memory log so it was possible that the last set of perforations were in a mud stone, directly above the recommended perforation depth. The two most likely explanations for the poor injectivity are poorer rock quality in the current set of perforations and/or damage due to drilling. Additional perforations (75') and an acid • stimulation were carried out in April 2011 to address both potential problems. In addition, a primary depth control jewellery log was run to allow for better depth control for shooting perforations and setting future plugs. When the well was returned to MI injection post add perforations and acid treatment injectivity was a lot higher and comparable to what was achieved during the first bulb. Profile modification for the third MI bub was done on 09/17/2012. 100' of perforations were added from 13,750'-13,850' MD and the well started injecting MI on 09/29/2012 after staying SI for 10 days for SBHPS. Before the acid stimulation the well injectivity with diesel was 0.3 bpm @ 2,000 psi and increased to 0.6 bpm @ 2,000 psi after the stimulation, so is very likely that acid stimulation will be necessary for the fourth MI bulb. Discussion and Justification Swell packers were used in the completion of this well and set at the following depths: 14,380', 14,228', 13,624', 13,020', 12,415', and 11,849'. Avoid shooting perforations in one of the swell packers. When designing this weliwork procedure it was discussed if an acid job should be injected into the fourth set of perforations right away to guarantee good injectivity from the start. Considering the HSE risk that's involved with pumping acid, as well as the initial cost, it was decided to first add 90' of perforations and if this does not result in high enough injectivity to achieve the target of 25 MMscf/d of MI we will follow up with an acid treatment with coil to stimulate the new perforations. The well has been on MI injection since 09/29/2012 and will be swapped to produced water injection approximately on 11/15/2013. Please allow for a minimum of one month of water injection before carrying out this procedure to ensure that all the gas has been displaced away from the well. Once the well has been swapped to diesel, please pump only diesel to maintain diesel fluid column. Higino dos Santos @ 564-4342 (W), 713-269-3879 (C). Cc w/ att: Well File Cc: Well File 2 Note: This program was desSd with the intention that it would req•6 coil runs: 1. Drift/Log/Flag 2. Set CIBP 3. Add 30'perforations 4. Add 30'perforations 5. Add 30'perforations 6. Acidize perforations to increase injectivity(pending injectivity test) 03-36A DHD Procedure 1. Perform TIFL to verify tubing inegrity. • Well has passed MIT-IA passed @ 2,800psi on 03/24/12 03-36A SL Procedure 2. MIRU Slickline. PJSM. 3. Pull MCX from 4-1/2" HES X Nipple @ 2,254' MD. 4. Drift to max deviation with drift large enough for 4-1/2" CIBP and 30' 2-7/8" dummy gun. OD CIBP: 3.562". Drifted to 11,119' SLM September 24th 2012 with 2-1/2" sample bailer. 5. RDMO. 03-36A Fullbore-Schmoo-B-Gone Treatment 1. MIRU. PJSM. 2. Pressure test. 3. Pump 5 bbl of methanol spear 4. Pump 250 bbl of SBG mix. 5. Wait six to twelve hours. 6. Hand well back to operations to put well back on injection. 03-36A Coil Procedure 1. MIRU CTU. PJSM 2. Displace wellbore with -1.2 tubing volumes of diesel at ambient temperature. Bullhead -260 bbl diesel down tubing. Spear in with 5 to 10 bbl of methanol prior to pumping the diesel. 3. MU drift assembly with nozzle and GR/CCL. Drift to -13,700' MD, log to 10,300', paint flag and POOH. Tie in log: PDS Coil Flag 10-Sep-2012 OD of Weatherford CIBP to be run: 3.562" ��P 4. Pick up CIBP, RIH tie into flag and set CIBP a 13,620' MD. POOH. Ensure good depth control so we can use the CIBP to tag for future tie in if needed. When pumping balls to seat use diesel to maintain diesel fluid column. 5. Pick up 30' of 2-7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 6. RIH, tag CIBP for depth control and perforate 13,290' - 13,320' MD. POOH. n Note any tubing pressure changes in AWGRS summary. ,/ ./14 3 7. Pick up 30' of 2-7/8" 16 PowerJet m p Omega HMX, 6 SPF, 60,phasing guns. 8. RIH, tag CIBP for depth control and perforate 13,260' - 13,290' MD. POOH. 9. Pick up 30' of 2-7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 10.RIH, tag CIBP for depth control and perforate 13,230' - 13,260' MD. POOH. 11.Pick up 200' and perform injectivity test with diesel down backside of coil. If injectivity is less than 2 bpm @ 2,000 psi, perform the following acid stimulation. Otherwise, RDMO. Please record injectivity results in AWGRS r e ort. PENDING Acid Stimulation C6//LA Comments: • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • In general, pump job at maximum allowable or achievable rate/pressure. • Attempt to not exceed 2,000 psi while acid is entering the perforations if possible. It is ok to go up to 3,000 psi surface pressure if the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Higino dos Santos at: higino.dos@bp.com Perforation Details Zone MDT MDB H Status Z2c 13,230' 13,320' 90 Open Design Details: Wellbore Volume 202 bbls to top of pelf at 13,230' MD, 207 bbls to CIBP at 13,620' MD Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Oilseeker Design 12 bbl per diversion Oilseeker (2 diversions) Pres 09/25/2012: SBHP 3,339 psi at 8800 tvd, SBHT is 177 F Treatment Procedure 12.Ensure the following before starting the job: a. Ensure current MSDS for this job is onsite and acid safe handling procedures are followed b. Ensure that the acid shower trailer is on site and functional c. Keep out all personnel not associated with this job d. Ensure Sundry for performing acid stimulation is on location. e. Well has L-80 liner. Ensure correct additives are used. SBHT 177 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90-110 F 13.MU coil tool string with jet swirl nozzle and RIH to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel -500ft away from top of perforations to prevent diesel and acid 4 getting into contact wAbeach other (500 ft - 6.5 bbl). Close in•kside and keep on injecting ammonium chloride until steady injection is achieved. If needed to establish injection, go to 3,000 psi WHP, but drop immediately back to 2,000 psi WHP so as to not fracture the well during the acid wash. 14.Pump fluids per attached pump schedule while reciprocating nozzle across newly perforated interval (13,230' - 13,320'). When acid is on the perforations, maximum WHP should be 2,000 psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stimulation should take -9.5 hours to pump. Please record oilseeker rates and total volumes pumped in AWGRS report. 15.POOH with coil and perform another injectivity test with diesel down the backside and make note of stabilized rate and pressure in daily report. 16.RDMO Coil. s Fluid Fluid Description •\. . Fluid Type; ti Vol � � �titi �� ` � ,, � � ,, , �� ,.� bbl `'`��. � - 1 Load/ Overflush/ Pre-Flush 3% NH4CI + F103 503 503 2 Acid 12% HCI 64 568 3 Mud Acid 9:1 Mud Acid 64 632 4 Diverter Oilseeker 24 656 O;'° � a '= . ' 2 0 6 on centre,ti �, Temperature Medium (175°F to 225°F) Medium (175°F to 225°F) Completion Metallurgy: L80 Total Chem Total Chem Loading for: 12% HCL 9:1 Mud Acid 12% HCI 9:1 Mud Acid Product Code Function Units A264 Acid Corrosion gal/Mgal 6 6 16 16 A201 Inhibitor Aid gal/Mgal 15 15 41 41 A153 Intensifier Ib/Mgal 0 0 0 0 F103 Flowback Aid gal/Mgal 2 2 5 5 L058 Iron Control Ib/Mgal 20 20 54 54 W054 Antiemulsifier gal/Mgal 5 5 14 14 U067 Mutual Solent gal/Mgal 0 50 0 135 5 • • Stage Cum , Fluid Fluid` u :`: Description Fluid Vol Vol y� � � �� � � ,� bbl bbl 1 Load 3% NH4CI + 0.2% F103 311 311 2 Acid 12% HCI 21 332 3 Mud Acid 9:1 Mud Acid 21 353 4 Overflush 3% NH4CI + 0.2% F103 32 386 5 Diverter Oilseeker 12 397 6 Pre-Flush (Spacer) 3% NH4CI + 0.2% F103 32 430 7 Acid 12% HCI 21 451 8 Mud Acid 9:1 Mud Acid 21 472 9 Overflush 3% NH4CI + 0.2% F103 32 505 10 Diverter Oilseeker 12 516 11 Pre-Flush (Spacer) 3% NH4CI + 0.2% F103 32 549 12 Acid 12% HCI 21 570 13 Mud Acid 9:1 Mud Acid 21 591 14 Overflush 3% NH4CI + 0.2% F103 64 656 15 Tubing Displacement Dead Crude 207 863 03-36A SL Procedure 1. MIRU Slickline. PJSM. 2. SBHPS as per attached form. 3. Run MCX and set in 4-1/2" HES X Nipple @ 2,254' MD. 4. Run check set to ensure MCX is set. 5. RDMO SL. 6. Hand well back to operation to POI. 6 ■ • 'TREE' 41!16"CAA/ • SAFETY NOTES: H2S READINGS AVERAGE 126 • • WELLHEAD= 13 5/8"FMC 03-36A ppm WHEN ON MI.WELL REQUIRES A SSSV ACTUATOR= BAKER KB.EL j= 6D' WHEN ON MI.WELL ANGLE>70°to 11115'. BF.REV= 30' KOP= 2700 I I I 2264' —I4-1/2"HES X MP,D=3.813' 1 Mu Angie= 91"@ 15057 2800' Hen TOP OF CE1.634i(06/20/08) I Datum MD= 10888' *4 Datum1VD= 8800'SS 4 13-3/8'CSG,68#,NT-80 CV I-E, —I 3977' D=12.415' —" 1 41100' H9-5/8"X r I-R ZXP LIP,D=6.29' I Minimum ID=3.725"@ 10423' 1 r"..." 1 4622' H9-5r6"X 7"FLEX LOCK HG R,D=6.30" 4-1/2"HES XN NIPPLE MLLOUT WI DOW(03-38A) 4756'-4777' 1 5/8"WHPSTOCK(04/12/07) H 4756' I 9-5/8"EZSV(04/12/07) H 477r I .. ...►fir ,:1.4 11"4-• , 1 10317' 1-14-1/2")438 X MR D=3.813" I omi '1'•••1.1 4.4'+,4+4,4�r I 9-5/8"CSG,47#,NT-80S, —) 11901 °"1♦♦1 i NSCC,D=8.681" �1�f ro �•f►j �4 �1 10379' H7"x 4-1/2"BKR S-3 FKR,D=3.870" I ••..41,-, ••'y ' 10402' H4-1/2"HESX MP,O=3.813" 1 10416' H12'T183ACK,D=5.250" t 10423' H4-1/2"HES XN MP?D=3.725" 10428' H7'X5'hRZXPLIP.ID=4.350" I 4-12"TSG,12.64,L-80 TC11,.0152 bpf,ID=3.958" H 10435' . 10456, H4-1/2"1/2"WLEG,D=3.958" 10439' —7"X 5"FLEX-LOCK LPR HGR,D=4.350' 10449' IH5'X4-12"XO,D=3.920'I 7"LTC,26#,L-80 BTC-M,.0383 bpf,D=6276" H 10688' • PERFORATION SUMMARY 11649' 5-3/4"SWELL PKR,D=3.958" REF LOG: SLB USIT ON 05102/07 ANGLEAT TOP PE RE: 90' 13750' _ 12416' —I5-3/4"SWELL FKR D=3.958" Note:Refer to Roduction C13 for historical pert data 13020' 5-3/4"SWELL PKR,D=3.958' SIZE SPF NVIBRVAL Opn/Sgz DATE C.1.-15P '-' -' 5-3/4"SWELL PKR,D=3.958" 2-718' 6 13750-13850 0 09/14/12 13624' 2-7/8" 6 14460-14510 C 02/12/09 412"CBP—1_ 14180• 1 14228• 15314'SWELL P KR,1D-3.958' 2-7/8" 6 15010-15110 C 5142007 (09/13/12) -.L.- 1 14650' H4-1/2'WFD CIBP(02/08109) Ill14830' - 53/4'SWELL PKR,D=3.958" PBTD 16274' .❖4 14-1/2"LNR,12.88,L-80 TC$,.0152 bpf,13=3.958" H 15363' DATE REV BY CONSENTS ' DATE REV BY COMMENTS N/TS FR DHOE BAY UNIT 04129/93 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED lOS SAFETY NOTE WELL 03-36A 04/29193 N28E RYVO 09/18/12 RRW/JM)SET CEP&ADPE RF(09113.14/12) PERMIT No:"1070200 05107/07 NWES SIDETRACK(03-36A) API Fb: 50-029-22340-01 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS SEC 11,MN,R15E,899'BAIL&906'FSL 02/16/09 TAR/SV SET OBP/ADPERF(02/12/09) 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) 8 • S 0 Mini-Log Injector Minilog '" Techlog Project: PBU_WF Well: 03-36A Author: Laura J. Larson Scale: 1:5000 Date: 3/6/2013 Elevation 55.67 X 714172 SPUD Date 2007-04-14 00:00:00 Country USA Elevation datum.KB Y'.5936971.99 Completion Date 2007-05-06 00:00:00 Field.Prudhoe Bay Total Depth:15365 Longitude-148.2710804 Status State.Alaska Coordinate System Latitude 70.2307203 Operator BPX Cornpany.BPXA GRMM- MWD t- = Rare uJ r✓enetrunun of BEST.ROP = u 0 F/HR 500 PE Info 3 -t GR TVDSS MD TVDSS RES_DEP tn Ali VI a a MWD.GRMM MWD (FEET) (FEET) cc BEST .RDEEP O O 0 GAPI 200 1:5000 1:5000 a — "-0.2 OHMM 200 a -: - 8730 - , -SAD _.... - 8830 — _... 1 11000 ---- -----._.___- ----� --- TCGL 31P t :::: -, ii, r — - 8960 _ 12000-- - 8970 — - 8980 1 _ -12500 -13000 6CGL Add Perf @ 13,230' - 13,320' m• - 8990 —13500 28,., `- C I B P t� 13,620 and - -14000---- -.. - 8990 -- 8990 -- aBIE- 14500---- - ---_..-_-- - 8990 — - k - . -15000 S P BPS t-___-,t' - - 8990 - Q. 9 • • 14' .<0 DIAgNosy s c q COIL FLAG e. 3 UMT-GR-CCL i• PROACTIVE IDIAgNosTIC SERVICES 10^Sep'2012 Ci Company BP EXPLORATION (ALASKA), INC. N Well 03 - 36A a Field PRUDHOE BAY s > Borough NORTH SLOPE State ALASKA o m Q Surface Location Other Services O Q N j c se 906.38' FSL & 898.93' FWL None a_ co 2 O to 1 1 m o a. Z < SEC: 11 TWP: 10N RGE: 15E >, _ Elevation nPermanent Datum MSL Elevation 0.00' K.B. 60.0' E `m 2 2 m Log Measured From RKB 60.0 FT.Above Perm.Datum D.F. N/A U 5. ii m API Serial Number 50-029-22340-01 G.L. N/A Date 10-Sep-2012 Run Number One P B T D Driller 15,274' FINAL P B T D Logger Not Tagged — Bottom Logged Interval 14,224' Top Log Interval 10,274' Open Hole Size N/A Type Fluid Produced Fluids _ Max.Recorded Temp.(deg.F.) N/A Time Well Ready 0830 FINAL PRINT Time Logger on Bottom 12:10 Equipment Number SLB CTU#8 Location North Slope _ Service Invoice No 11656 Recorded B y T.Thompson D.Sparks Witnessed By D.Montgomery T.Roschinger Borehole Record Tubins Record Run Number Bit From To Size LB/Ft From To 4 1/2" 12.60 Surface 10,435' __J Casing Record Size LB/Ft Top Bottom Surface String 13 3/8" 68.00 Surface 3,977' Prot.String 9 5/8" 47.00 Surface 11,901' Liner 7" 26.00 4,600' 10,588' Liner 41/2" 12.60 10 428' 15,363'_-.-__-. i 10 ■11111■ . • • • • • . _ , _ - -1 , . -- PDS -- ......_ Coil Flag _ -1--- ' 1- 10-Sep-2012 ;_. 1 , t , - 7- -t 13200 I I 1 ....' 1 ....-.... A ---f I • ....... __„.4 , , , , ,• ,, 1 0 1 ... I. ., ....._ ' , tt • t - -t- 1, . 4,,•_ I f , _ 1 - -1-- +ER I -' r 1 , _J + '-'-. ' 1 ' ... -.-. 't 1- I - ...-.-- . . , 1 - . ■•••••■- ----•• ■ . , r•■■ , ■ 1 lb t t- I ■...■, i- . .■•■. 1 I - +- ••■-•••• • , - -4- i - t • ■ [ , I -r- , 1 :: H ti 1 , - I- I , _. ..— I . Add Perf @ 13,230' — 13,320' md -r-- I I • , , '--- "I----t.. i -.1 _. -.4.-----, . _.... , _. 13300 - -. 1 , I , - - 1 , , , ±. , ---- , . _._ 1 -,- f .-t- 1 - _ _ _ i -- . _ 1 --- . ____ __ . . - , - - i , - 1 4-- -- --- . . I I -- . I - . I , , ; 1 •-; ---- 4- 7,--- - ,--- ■ -t 4-- 5 . , - - I - - _ e , . , _ ______ I i -.--..............I ....-.... ..-- .. .-. i H.- f 5 _ 5 . ----1.. - 5 . . .... .... .._..:...._ 11 • • { a.__._. .__:__ .:___.m .___ �._.__.. _._ •_ - _.._ } I I _ I -- — -'_- - I - '-- __ _ • Il - -_ I. 13500 , / _ f- ---"T t • ...• j I I i -----. t --,-- .-r 1 _. -T ( r ___ I _ +-- r- -s... } t , 1 -+ 11 .._ i ,_ ,13600 t j ! -., , + .. ., _.. CIBP 1>< ' _ ; I 1 �__ .: 'lilt.- 13,620' rrid - - t • 12 t{ • • ja PERFORATING PROCEDURE Now MINISEINIIIINSIIIRIS Well: 03-36A API#: 50-029-22340-01 Date: October 25,2013 Prod Engr Higino dos Santos Office Ph: 907-5644342 H2S Level: Home Ph: NA N/A-Injector Cost Est: $150,000 Cell/Pager: 713-269-3879 CC or AFE: APBINJEC WBL Entries IOR Type Work Description S Pull 4-1/2"MCX and drift to deviation 1 100 1 C Drift/Flag/Log,set CIBP,perforate 90' E Set 4-1/2"MCX Well Objectives and Perforating Notes: The objective of this procedure is to set a CIBP to isolate all current perforations and to add 90'of new perforations for the fourth MI bulb in the well. Note: Min ID=3.725"@ 10,423'MD(4-1/2"HES XN Nipple) Attachment: Tie in log with proposed new perforation intervalls annotated. Reference Log Tie in Log Add feet Log: MD Log Coil Flag to the tie-in log to be on _ .. ... Date: 4/30/2007 9/10/2012 depth with the reference log. Company: SLB PDS Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Rellperf 13,290' - 13,320 13,290' - 13,320' 30' 6 Random 60° 2 Addperf 13,260' - 13,290' 13,260' - 13,290' 30' 6 Random 60° 2 Addperf 13,230' - 13,260' 13,230' 13,260' 30' 6 Random 60 2 Addperf Requested Gun Size: 2-7/8" Charge: 2906 PJ Omega HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessary ..._ Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Tag: 14,180 ft MD on 9/12/2012 Est Res.Pres.@ 8,800 TVD is 3,339 psi Perforation Summary Summary Dist Well: 03-36A Town: Date: API#: 50-029-22340-01 Prod Engr: Anch Prod Engr P.D.Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U 0/B/U - 0/B/U - 0/B/U I 13 , w • STATIC BOTTOM-HOLE PRESSURE SURVEY Verl 4,Rev 08/12/2004 MDM) Well: 03-36A API#: 50-029-22340-01 Date: 10/29/2013 Prod Engr Higino dos Santos Office Ph: 564-4342 H2S Level: Cost Est: $5,000 Home Ph: N/A—Injector CC or AFE: APBINJEC Cell/Pager: 713-269-3879 WBL Entries Type Work Description Comments S Pull MCX,Drift to dev C :Set CIBP,Add Perf 100' S .SBHPS,set MCX Well Objectives.Logging Notes.and Special Instructions: Opportunistic static due to coil tubing intervention. Datum: 8800'SS I Well Data Procedure: Last Tag: 14180 MD Tag date: 9/12/2012 1.Make 10 min pressure stop in lubricator Max Deviation 91 Degs Depth: 14,115'MD 2.Drop below the first pressure-stop requested. Pull-up to specified depth. 3.E/L:Measure pressure until it varies less than 1 psi in 20 min. Min.SI Time: 7 Days Logging Data S/L:Hold guages at depth for time specified 4.E/L:Measure pressure until it varies less than 1 psi in 20 min. S/L:Hold guages at depth for time specified Requested Stops: MD SS Time 5.E/L:Measure pressure until it varies less than 1 psi in 20 min. First 10579' 8600' 15 mm S/L:Hold guages at depth for time specified Second 10727' 8700' 15 min 6. E/L:Test tool in lubricator at 3000 psi with calibrated test gauge Third 10888' 8800' 15 mm S/L:Hold guages in lubricator for 10 min stop.Compare to test guage Fourth 11115' 8900' 15 min 7.Return well to operations to PO1. Summary Dist Well: 03-36A API#: 50-029-22340-01 PE Town: Date: Anch Prod Engr Service Co. New Tag: 'MD P.D.Center Upper Lower Date Time MD SS Gauge Gauge Temperature Test Gauge Pre-Job Lubricator Pressure 231.1 232.2 10579' 8600' 3270.3 3270.4 10727' 8700' 3305.1 3305.1 10888' 8800' 3338.8 3339.3 11115' 8900' 3372.9 3372.8 Post-Job Lubricator Pressure 228.7 229.3 Type of Pressure Tool SI-P(Tubing): psig SIC P(9-5/8): Shut In Date: Comments: and Time: Total Shut In Time(hrs) 14 RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMM ON 0 C f 1 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other El Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: BP Exploration (Alaska), Inc Development Exploratory ❑ " 207 -020 -0 3. Address: P.O. Box 196612 Stratigraphk>❑ Service la 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22340 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number. . ADL0028332 PBU 03 -36A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted ^ PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15365 feet Plugs measured 14180, 14650 feet true vertical 9043 feet Junk measured None feet Effective Depth measured 14180 feet Packer measured See Attachment feet true vertical 9045.49 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 86 20" 91.1# H-40 30 -116 30 - 116 1530 520 Surface 3948 13 -3/8" 68# NT -80 29 - 3977 29 - 3730.76 5020 2260 Intermediate None None None None None None Production 4749 9 -5/8" 47# NT8OS 28 - 4777 28 - 4242.5 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet 13800 - 13825 feet 13825 - 13850 feet 14330 - 14355 feet 14355 -14380 feet 14460 - 14470 feet 14470 - 14490 feet 14490 - 14510 feet 14517 - 14542 feet 15010 - 15110 feet True Vertical depth See Attachment feet 9046.61 - 9046.89 feet 9046.89 - 9047.1 feet 9045.61 - 9045.7 feet 9045.7 - 9045.81 feet 9045.9 - 9045.92 feet 9045.92 - 9045.95 feet 9045.95 - 9046 feet 9046.02 - 9046.11 feet 9047 - 9045.36 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 26 - 10435 26 - 8560.24 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" MCX I -SSV 2254 2253.69 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 2 3 GU q{1�9 J 13750' - 13850' Treatment descriptions including volumes used and final pressure: 224 BBLS 1% KCL, 641 BBLS 3% NH4CL, 72 BBLS 9:1 MUD ACID, 72 BBLS 12% HCL, 8 BBLS 7Q FOAM, FINAL WHP 2000 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2552 0 b 1804 Subsequent to operation: 0 23255 0 0 3178 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development ❑ Service o Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG el GINJ ❑ SUSP ❑ SPLUC-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -293 Contact Nita Summerhays Email Nita.Summerhays(bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician ' , Signatu 1 �r i_�� �;Tre;i94�� / /i�i�.r";� Phone 564 -4035 Date 10/10/2012 OCT �, S 1 ZQtZ c Iik Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028332 ACTIVITYDATE 1 SUMMARY T /I /0= 1800/560/300 Temp= INJ Schmoo -B -Gone Treatment ( Pre CT ) Speared into Tbg w/ 5 bbls neat methanol followed by 270 bbls Schmoo- B -Gone. Pumped 5 bbls neat methanol to flush surface lines. Let soak 9/2/2012 for 3 hours. * * *WSR continued on 09- 03 -12 * ** ** *WELL INJECTING ON ARRIVAL ** *(pre ctu -cibp /adperf) PULL 4 1/2" MCX FROM 2233' SLM/ 2254' MD. DRIFT TUBING WITH 3.7" CENTRALIZER & SAMPLE BAILER. SLOW TO A STOP DUE TO DEVIATION @ 11333' SLM. BAILER RETURNED EMPTY. DRIFT TUBING WITH 22' OF 2.875" DUMMY PERF GUN. SLOW TO A STOP DUE TO DEVIATION @ 11300' SLM. ** *DSO BROUGHT WELL ON INJECTION & WALKED THROUGH 9/2/2012 UPON DEPARTURE * ** * * *WSR continued from 09- 02 -12 * ** Schmoo -B -Gone Treatment ( Pre CT) Pumped 224 bbls 1% KCL to displace Schmoo -B -Gone. Pumped 5 bbls neat methanol to flush surface lines. FWHP's= vac /vac /40 SV, WV= S/I SSV, MV= 0 IA & OA= OTG. DSO to POI 3 hours after 9/3/2012 shutdown. MIRU CTU #8 w /new 1.75" coil. Objective: Set CIBP, Addperfs, contingent acid job. Performed BOP test, chain inspection and changed out packoff. MU Weatherford 2 3/8" MHA. MU /RIH w/ PDS 2 7/8 w/ GR /CCL and 3.64" JSN for drift. Log CCL /GR from 14200' - 10250'. Flag CT @ 14130' yellow. Fluid pack wellbore with Encounter injector /weight issue while logging & POOH. Pulled 38K# to 9000'. Backside loaded w/ 270 bbl diesel. 9/10/2012 « <Job in progress. »> MIRU CTU #8 w /new 1.75" coil. Objective: Set CIBP, Addperfs, contingent acid job. Performed BOP test, chain inspection and changed out packoff. MU Weatherford 2 3/8" MHA. MU /RIH w/ PDS 2 7/8 w/ GR /CCL and 3.64" JSN for drift. Log CCL /GR from 14200' - 10250'. Flag CT @ 14130' yellow. Fluid pack wellbore with Encounter injector /weight issue while logging & POOH. Pulled 38K# to 9000'. Backside loaded w/ 270 bbl diesel. Process depth log, ( +24'). Cut 1' of pipe off, inspected chains, brass, UTIM, and packoff. Changed out packoff and brass after finding metal shavings in packoff and brass severely worn on one side. MU Weatherford 4 1/2" CIBP and RIH. 9/10/2012 Job continued on 9/11/12 WSR. MIRU CTU #8 w/ 1.75" coil. Objective: Set CIBP, Addperfs, contingent acid job. At SLB yard swapped from 1.5" to 1.75" coil. Performed BOP test, chain inspection and changed out packoff. 9/10/2012 « <Job in progress. »> • • Daily Report of Well Operations ADL0028332 MIRU CTU #8 w /new 1.75" coil. Objective: Set CIBP, Addperfs, contingent acid job. RIH w/ Weatherford 4 1/2" CIBP. Set 4 -1/2" WFD CIBP at 14180'ctmd. 9/11/2012 PT plug to 1000psi for 15 min. Plug is holding. POOH. Continued from WSR 09 -11- 12 Objective: Set CIBP, Addperfs, contingent acid job. MU and RIH w/ BHA; 2.38" ctc, dfcv, disco, blank sub, two 2" magnets, 2.13" firing head, 2 "x 25' perf gun. (oal= 36.63') 9/12/2012 * *job in progress ** Continued from WSR of 09/12/12. Coil 8, 1.75" coil. Job Scope: add perfs. POH to check BHA. PJSM. Close swab and SSV. Lay out BHA. M/U 3.0" down jet nozzle BHA. PT lube. RIH. RIH clean to 11700'. Circ and RIH Clean to CIBP. Tag at 14157'. Pick up to 13700'. ** *Job in Progress * ** 9/13/2012 Continued from WSR of 09/13/12. CTU 8, 1.75" coil. Job Scope: Add perfs. POH with second set of fired perf guns. PJSM. Lay out guns. All shots fired. Perforated interval: 13800 - 13825'. M/U third 25' perf gun BHA. 9/14/2012 PT lube. RIH with perf guns. * ** Job in Progress * ** Continued from WSR of 09/14/12. CTU 8, 1.75" coil. Job scope: Add perf. lnjectivity test. Lay out BHA. Stand back BOPE. N/U tree cap and PT. Perform injectivity test down 4 -1/2" tubing. Injectivity stable at 1.0 bpm at 3070 psi. Acid job is required. Close swab and SSV. Rig down CTU. Check chains and change out packoffs. Move CTU to shop for maintenance while loading acid. ** *Job incomplete * ** 9/15/2012 * *NOTE; due to heavy pickup weights, slick fluids must be used ** CTU 8 w/ 1.75" CT-Scope; Acid stimulation. Rig up. Function test BOPs. RIH w/ BHA; 1.95" ctc, 2" dfcv, 2" stinger, 2.12" crossover, 2.1" crossover, two 2.5" magnets, 2" crossover, 2.5" JSN (oal= 9.95'). Tag CIBP and correct depth to 14180'. PUH and park at 14130'. Have pumpers come online down coil w/ NH4CL with returns to tank. Pump 12% HCL acid and Mud acid stimulation as per program. Displace acid 9/16/2012 with 3% NH4CL. * *job in progress ** Continued from WSR of 09/16/12. CTU 8, 1.75" coil, Job Scope: Acid stimulation. Continue with NH4CL overflush of acid stimulation. POH. Pump injectivity test down tubing with diesel, 0.6 BPM with 2000 WHP. L/O 9/17/2012 JSN BHA. PJSM. Pressure / function test BOPE. ** *Job complete * ** FLUIDS PUMPED BBLS 15 METH 607 DIESEL • • Daily Report of Well Operations ADL0028332 728 DIESEL WITH 776 FRICTION REDUCER 224 1% KCL 641 3% NH4CL 72 9:1 MUD ACID 72 12% HCL 8 7Q FOAM 2367 TOTAL --Ref# ration A me - - °__�._� -__ �� S -'�� , ----- 028332 �/ J t W Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03 -36A 9/14/2012 APF 13750 13800 9046.19 9046.61 \, 03 -36A 9/13/2012 APF 13800 13825 9046.61 9046.89 03 -36A !/11/2012 , PF _ 13825 13850 9046.89 _ 9047.1 �3- 1 36A - 9 ". B' ='�— 43 �I�cL a' � .: -9045: 03 -36A 9/11/2012 BPS 14355 14380 9045.7 9045.81 03 -36A 9/11/2012 BPS 14460 14470 9045.9 9045.92 03 -36A 9/11/2012 BPS 14470 14490 9045.92 9045.95 • 03 -36A 9/11/2012 BPS 14490 14510 9045.95 9046 03 -36A 9/11/2012 BPS 14517 14542 9046.02 9046.11 03 -36A 9/11/2012 BPS 15010 15110 9047 9045.36 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • 0 Packers and SSV's Attachment ADL0028332 SW Name Type MD TVD Depscription 03 -36A SSSV 2254 2198.02 4-1/2" MCX I -SSV 03 -36A PACKER 10379 8467.07 4 -1/2" Baker S -3 Perm Packer 03 -36A PACKER 10428 8499.89 5" Baker ZXP Top Packer 03 -36A PACKER 11849 8960.7 4.5" X 5.75" TAM Swell Packer 03 -36A PACKER 12415 8984.31 4.5" X 5.75" TAM Swell Packer 03 -36A PACKER 13020 8988.25 4.5" X 5.75" TAM Swell Packer 03 -36A PACKER 13624 8989.92 4.5" X 5.75" TAM Swell Packer 03 -36A PACKER 14228 8989.48 4.5" X 5.75" TAM Swell Packer 03 -36A PACKER 14830 8990.07 4.5" X 5.75" TAM Swell Packer Casing / Tubing Attachment . ADL0028332 Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 20" 91.1# H-40 30 - 116 30 - 116 1530 520 LINER 5989 7" 26# L -80 4599 - 10588 4132.17 - 8661.81 7240 5410 LINER 4947 4 -1/2" 12.6# L -80 10416 - 15363 8547.54 - 9043.13 8430 7500 PRODUCTION 4749 9 -5/8" 47# NT8OS 28 - 4777 28 - 4242.5 6870 4760 SURFACE 3948 13 -3/8" 68# NT -80 29 - 3977 29 - 3730.76 5020 2260 TUBING 10409 4 -1/2" 12.6# L -80 26 - 10435 26 - 8560.24 8430 7500 • • TREE= 4 -1/16" CIW WELLFEAD = 13 5/8" FMC S NOTES: H2S READINGS AVERAGE 125 ACTUATOR = ` BAKER 03-36A ppm WHEN ON MI. WELL REQUIRES A SSSV KB B.E _ 60, L WHEN ON MI. WELL ANGLE> 70° @ 11115'. BF ELEV = 30' KOP = 2700' ._. I 2254' H4 - 112" HES X NP, D = 3.813" Max Angle = 91° @ 15057 I 2900' - I EST TOP OF CEMENT (06/20 /06) Datum MD = 10888' 4 Datum 1VD= 8800' SS 4 4 13 -3/8" CSG, 68#, NT-80 CY HE, H 397T *Al D= 12.415" _ I 4600' I-I9 518" X 7" HR ZXP LW, ID = 6.29' Minimum ID= 3,725" a@ 10423' 4622' H9 -5/8" x 7" FLEX LOCK HGR, D = 6.30" 4 -1/2" HES XN NIPPLE MLLOUT WINDOW (03 -36A) 4756' - 4777' I I9 -5/8" WHPSTOCK (04 /12/07) -1 4756' I 9-5/8" EZSV (04/12/07j 4777' li 1, i �' 10317' --{4- 112 " HES X NP, D = 3.813" 1 9-5/8" CSG, 47 #, NT -80S, -1 11901' I-∎ 71 4 4 • r 4 X A PO NSCC, ID = 8.681" V 1 / 4 4 4 4 4 4 1 4 � � i X I 10379' -- 1 7" X 4 -1 /2" BKR S-3 PKR D = 3.870" 1.x.11. M.16 46:4:I , 10402' -14 -112" HES X NP, D = 3.813" 10416' H17 Tll$ACK, D = 5.250" 10423' -I4- 112" HES XN NP, D = 3.725" 10428' H 7" X 5" HR ZXP LTP, ID = 4.350" 4- 112" TBG, 12.6#, L -80 TC11, _0152 bpf, D = 3.958" I-1 10435' _ e 10436' H 4- 112" W1LEG, D = 3.958" 10439 - 7" X 5" FLEX -LOCK LNR HGR, D = 4.350" , 10449' -{ 5" X 4 -112" XO, D = 3.920" I 17" LNR, 26#, L -80 BTG-M, .0383 apt, D = 6.276 - 1 10588' PERFORATION SUMMARY 11849' H5-3/4" SWELL PKR, D = 3.958" REF LOG: SLB USIT ON 05/02/07 1.■ lc. ANGLE AT TOP PERF: 90° @ 13750' C.4 �_ 12415' - 15 - 3/4" SWELL PKR D = 3.958" Note: Refer to Production CB for historical pert data • a . 1 :" AL • r a i z [RA 1- ! -. 0 0 13020' 1 - {5 SWELL PKR D = 3.958" l 4,61, 2 - 7/8 - ' 6 13750 0 09/14/12 /� ►_ ► -� 13624' -1 - 314" SWELL PKR, D = 3.958" 7 ' 6 T44>i0 - 1 510 , _/C� '\ 1 ' 1 • J 4-1/2' CBP - 14180' _ — I 2 -7/8" 6 15010 - 15110 C 5/4/2007 (09/13/12) '= _� 14228' 1 - _5 -3/4' SWELL PKR, D = 3.958' Ill 14650 " - -- 41/2" WFD CIBP (02/08/09) 1111,4 14830' H5 -3/4" SWELL PKR, ID = 3.958' PBTD -1 15274' ,(r. -�� _ 14 - 1/2' (AR, 12.6#, L -80 TCI, .0152 bpf, D = 3.958" - 15363' DATE REV BY COIVIVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/29/93 ORIGINAL COMPLETION 01/10/12 TMNYJMD ADDED 142S SAFE! Y NOTE WELL: 03-36A 04/29/93 N28E RWO 09/18/12 RRW /JMD SET CBP & ADPERF (09/13-14/12) PERNIT No: `2 070200 05/07 /07 NIES SIDETRACK (03 -36A) API No: 50 029 - 22340 - 01 06/05/07 STG/PJC DRLG DRAFT CORRECTIONS SEC 11, T1ON, R15E, 899' FWL & 906" FSL 02/16/09 TAR/SV SET (2BP/ ADPERF (02112/09) 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) T • • smitE ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Higino Dos Santos �, d Production Engineer o�O BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03 -36A Sundry Number: 312 -293 Dear Mr. Santos: 5;t.,M414ED AUG 0 8 2,Q1 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. 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 reconsideration. A request for reconsideration 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. Sincerely, Cathy . Foerster Chair DATED this ? day of August, 2012. Encl. Ili E EIVED • STATE OF ALASKA JUL 31 01 ' ALASKA OIL AND GAS CONSERVATION COMMISSION I . / Z APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 ,i.i• r'' 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend [I] Plug Perforations ❑ Perforate [ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0 • Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 207 -020 -0 - 3. Address: Stratigraphic ❑ Service ©. 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 22340 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 PBU 03-36A ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0028332 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15365 . 9043 ' 14650 9046 14650 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H -40 36 - 116 36 - 116 Surface 3942 13 -3/8" 68# NT -80 35 - 3977 35 - 3730.76 5020 2260 Intermediate None None None None None None Production 4745 9 -5/8" 47# NT8OS 32 - 4777 32 - 4242.5 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# L -80 26 - 10435 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 4 -1/2" © MCX I -SSV 2254', 2253.69' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Development n Service (✓] • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ 7 ( . ..... WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ L, , v i.L WAG Yr Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact �� Prepared by Garry Catron 564 -4424 Printed Name Higino Dos Sant. - .,,, 564 -4342 Title Production Engineeer r Signature Phone Date —v _ 0 -7 - 2k,' IZ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t 2....2.q, Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / 0 - il p L/ APPROVED BY Approved by: /f / I i COMMISSIONER THE COMMISSION Date: 8 2- / 0R1GI iiiikt§ Form 10 -40 - Revised 1/2010 b - 1 AUG 0 (� i i Duplicate ` ` ti • • Casing Summary ADL0028332 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.1# H -40 36 116 36 116 1530 520 H-40 LINER 5989 7" 26# L -80 4599 10588 4132 8662 7240 5410 L -80 LINER 4947 4 -1/2" 12.6# L -80 10416 15363 8548 9043 8430 7500 L -80 PRODUCTION 4745 9 -5/8" 47# NT8OS 32 4777 32 4243 6870 4760 NT8OS SURFACE 3942 '13 -3/8" 68# NT -80 35 3977 35 3731 5020 2260 NT -80 TUBING 10409 4 -1/2" 12.6# L -80 26 10435 26 8560 8430 7500 L -80 • • Perforation Attachment ADL0028332 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03 -36A 4/12/11 APF 14330 14355 9046 9046 03 -36A 4/11/11 APF 14355 14380 9046 9046 03 -36A 2/12/09 APF 14460 14470 9046 9046 03 -36A 2/12/09 APF 14470 14490 9046 9046 03 -36A 2/8/09 APF 14490 14510 9046 9046 03 -36A 4/11/11 APF 14517 14542 9046 9046 03 -36A 2/8/09 BPS 15010 15110 9047 9045 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF II • • Packers and SSV's Attachment ADL0028332 Well Facility Type MD Top Description TVD Top 03 -36A SSSV 2254 4 -1/2" MCX I -SSV 2254 03 -36A PACKER 10379 4 -1/2" Baker S -3 Packer 8523 03 -36A PACKER 10428 5" Baker ZXP Top Packer 8556 03 -36A PACKER 11849 4.5" X 5.75" TAM SweII Packer 9016 03 -36A PACKER 12415 4.5" X 5.75" TAM SweII Packer 9040 03 -36A PACKER 13020 4.5" X 5.75" TAM SweII Packer 9044 03 -36A PACKER 13624 4.5" X 5.75" TAM SweII Packer 9046 03 -36A PACKER 14228 4.5" X 5.75" TAM SweII Packer 9045 03 -36A PACKER 14830 4.5" X 5.75" TAM SweII Packer 9046 • • bp 4 ok in M '��_i� Memorandum To: Clark Olsen & Tyler Norene Date: June 11 2012 ADW Well Service Team Leaders From: Bernhard Stechauner AFE: APBINJEC DS- 03Production Engineer Reviewed: Josh Allely, 6/28/2012 Est. Cost: Subject: 03 -36A CIBP and Add Perf IOR: 200 Type Desc. Comment S Retrieve 4 -1/2" MCX and drift to deviation F Schmoo -B -Gone treatment C Drift/Flag /Log, Set CIBP, Add 100' perforations, Injectivity Test, Acid Stimulation (P) r S SBHPS, set 4 -1/2" MCX Current Status: WAG injector, SI MI on 6/12/12, will be on water -7/1/2012. Last Injection Rate: 19,381 Mscf /d MI @ 3,183psi on 6/10/2012 Max Deviation: 91° @ 14,115' MD Min. ID: 3.725" @ 10,423' MD (4 -1/2" HES XN Nipple) Last Downhole Ops: 04/19/2011 - Set 4 -1/2" MCX @ 2,254' MD and ran check set Last SBHP: 02/08/2009: 2,916 psi @ 8,800' TVDSS Latest H2S level: N/A - Injector Job Objective: The objective of this procedure is to set a CIBP to isolate all current perforations and to add 100' of nPw perforatinns fnr the third MI bulb in the well. If required, an acid stimulation will be performed on coiled tubing to increase injectivity. Also, an opportunistic static bottom hole pressure will be obtained when slickline returns to re -set the MCX safety valve. Well History: Well 03 -36A was sidetracked in May 2007 as a horizontal MI injector. The 4 -1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals. The first MI cycle was completed in 2008 and the second MI cycle began in the first half of 2009. Injectivity in the second set of perforations was always low and the effectiveness of the MI bulb was compromised. The first bulb was successfully displaced in 100' of open perforations from 15010'- 15110'. The second zone originally only perforated 50', 14460'- 14510', and did not successfully get the MI bulb away. Both sets of initial perforations were done without the use of a tie -in run with a memory log so it was possible that the last set of perforations were in a mud stone, directly above the recommended perforation depth. The two most likely candidates for the poor injectivity are poorer rock quality in the current set of perfs and /or damage due to drilling. Additional perforations (75') and an acid stimulation were carried out in April 2011 to address both potential problems. In addition, a primary depth control jewellery log was run to allow for better depth control for shooting perforations and setting future plugs. The 50' of perforations we•learly visible on the CCL track and tfand looked clean according to ' the GR log. When the well was returned to MI injection post add perf and acid treatment injectivity was a lot higher and comparable to what was achieved during the first bulb. Discussion and Justification Swell packers were used in the completion of this well and set at the following depths: 14,380', 14,228', 13,624', 13,020', 12,415', and 11,849'. Avoid shooting perforations in one of the swell packers. When designing this wellwork procedure it was discussed if an acid job should be injected into the third set of perforations right away to guarantee good injectivity from the start. Considering the HSE risk that's involved with pumping acid, as well as the initial cost it was decided to only add perforations at this time. However, we will increase the perforation interval back to 100', twice as ✓ long as the initial second set of perforations. If this increase in open perforations does not yield enough injectivity to achieve the target of 25 MMscf /d of MI we will follow up with an acid treatment on full -bore to stimulate the new perforations. The well has been on MI injection until 6/12/2012 and will be swapped to water post the FS -2 shut- down (6/15 -6/19 2012) as soon as enough produced water is available at the facility. Please allow for a minimum of one month of water injection before carrying out this procedure to ensure that all the gas has been displaced away from the well. Once the well has been swapped to diesel, please pump only diesel to maintain diesel fluid column. For questions or comments please call Bernhard Stechauner 564 -4594 (work) or 360 -7485 (mobile). Cc: Well File 2 Note: This program was Jilted with the intention that it would refe 7 coil runs: ' 1. Drift/Log /Flag 2. Set CIBP 3. Add 25' perforations 4. Add 25' perforations 5. Add 25' perforations 6. Add 25' perforations 7. Acidize perforations to increase injectivity (pending injectivity test) 03 -36A SL Procedure 1. MIRU Slickline. PJSM. 2. Pull MCX from 4 -1/2" HES X Nipple @ 2,254' MD. 3. Drift to max deviation with drift large enough for 4 -1/2" CIBP and 25' 2 -7/8" dummy gun. OD CIBP: 3.562 ". Drifted to 11,270' SLM April 7 2011 with 2 -1/2" sample bailer. 4. RDMO. 03 -36A Fullbore - Schmoo -B -Gone Treatment 1. MIRU. PJSM. 2. Pressure test. 3. Pump 5 bbl of methanol spear and 260 bbl of SBG mix. (17% concentration, 44 bbl of concentrate in 216 bbl of hot water) followed by 5 bbl of methanol. 4. Wait three hours. 5. Pump 220 bbl of 1% KCI displacement flush followed by 5 bbl of methanol. 6. Wait three hours. 7. Hand well back to operations to put well back on injection. 03 -36A Coil Procedure 1. MIRU CTU. PJSM 2. Displace wellbore with -1.2 tubing volumes of diesel at ambient temperature. Bullhead -270 bbl diesel down tubing. 3. MU drift assembly with nozzle and GR /CCL. Drift to -14,200' MD, log to 10,300', paint flag and POOH. Tie in log: PDS Coil Flag 10- Apr -2011 i - i '- OD of Weatherford CIBP to be run: 3.562" L X60 ? 4. Pick up CIBP, RIH, tie into flag and set CIBP a 14,180' MD. POOH. Ensure good depth control so we can use the CIBP to tag for future tie in if needed. When pumping balls to seat use diesel to maintain diesel fluid column. 5. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 6. RIH, tag CIBP for depth control and perforate 13,825 - 13,850' MD. POOH. Note any tubing pressure changes in AWGRS summary. 7. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 8. RIH, tag CIBP for depth control and perforate 13,800 - 13,825' MD. POOH. 9. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 10. RIH, tag CIBP for depth control and perforate 13,775 - 13,800MD. POOH. 3 11. Pick up 25' of 2- 7/8106 PowerJet Omega HMX, 6 SPF, 6•g phasing guns. 12. RIH, tag CIBP for depth control and perforate 13,750 - 13,775' MD. 13. Pick up 200' and perform injectivity test with diesel down backside of coil. If injectivity is less than 2bpm @ 2,000 psi, perform the following acid stimulation. Otherwise, RDMO. Please record injectivity results in AWGRS report. PENDING Acid Stimulation Comments: • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • In general, pump job at maximum allowable or achievable rate /pressure. • Attempt to not exceed 2000 psi while acid is entering the perforations if possible. It is ok to go up to 3000 psi surface pressure in the following cases: a. If the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Bernhard Stechauner at: Bernhard.stechaunera.bp.com Perforation Details Zone MDT MDB H Status Z2c 13750 13850 100 Open Design Details: Wellbore Volume 209 bbls to top of pert at 13750' MD, 216 bbls to CIBP at 14180' Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Foam Design 15bbI per diversion 70Q Foam (2 diversions) Pres 02/08/2008: SBHP 2916 psi at 8800 tvd, SBHT is 206 F Treatment Procedure 14. Ensure the following before starting the job: a. Ensure current MSDS for this job is onsite and acid safe handling procedures are followed b. Ensure that the acid shower trailer is on site and functional c. Keep out all personnel not associated with this job d. Ensure Sundry for performing acid stimulation is on location. e. Well has L -80 liner. Ensure correct additives are used. SBHT 206 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90 -110 F 15. MU coil tool string with jet swirl nozzle and RIH to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel -500ft away from top of perforations to prevent diesel and acid getting into contact with each other (500 ft - 6.5 bbl). Close in backside and keep on injecting ammonium chloride until steady injection is achieved. 4 If needed to estab• injection, go to 3,000 psi WHP, buop immediately back to 2,000 psi WHP as to not frac the well during the acid wash. 16. Pump fluids per attached pump schedule while reciprocating nozzle across newly perforated interval (13,750' — 13,850'). When acid is on the perfs, max WHP should be 2,000 psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stim should take —9.5 hours to pump. Please record N2 rates and total volumes pumped in AWGRS report. 1 17. POOH with coil and perform another injectivity test with diesel down the backside and make note of stabilized rate and pressure in daily report. 18. RDMO Coil. Fluid Type Vol (bbl) Vol (gal) o aa) 3% NH4CI + F103 418 17,562 To E 12% HCI 71 3,000 I—° 75 9:1 Mud Acid 71 3,000 Foam (3% NH4CI +F103 +N2) 8 336 Foam Mixing Rates Liquid Rate N2 Rate bbl /min scf /min 0.25 314 0.5 629 0.75 943 1 1257 1.25 1571 1.5 1886 Temperature: Medium (175 °F to 225 °F) Completion metallurgy: L80 total chem total chem Loading for: 12% HCI 9:1 mud acid 12% HCI 9:1 mud acid Product Code: Function: Units: A264 ACI gal /Mgal 6 6 18 18 A201 Inhibitor Aid gal /Mgal 15 15 45 45 A153 Intensifier Ib /Mgal 0 0 0 0 F103 Flowback aid gal /Mgal 2 2 6 6 L058 Iron Control Ib /Mgal 20 20 60 60 W054 Antiemulsifier gal /Mgal 5 5 15 15 U067 Mutual Solvent gal/Mgal 0 50 0 150 03 -36A SL Procedure 1. MIRU Slickline. PJSM. 2. SBHPS as per attached form. 3. Run MCX and set in 4 -1/2" HES X Nipple @ 2,254' MD. ✓ 4. Run check set to ensure MCX is set. 5. RDMO SL. 6. Hand well back to operation to POI. 5 Stage Cum Foam vol, I N2 vol, Stage Step Description Fluid Fluid Fluid bbl scf /bbl Pre -Flush 1 Pre - Displacement 3% NH4CI + F103 60 60 2 Acid 12% HCI 24 84 3 Mud Acid 9:1 Mud Acid 24 108 o 1 4 Overflush 3% NH4CI + F103 36 143 d 5 Diverter Foam (3% NH4CI + F103 + N2) 4 147 15 12571 r 6 Spacer 3% NH4CI + F103 20 167 n N 7 Acid 12% HCI 24 191 c 8 Mud Acid 9:1 Mud Acid 24 215 ° 2 9 Overflush 3% NH4CI + F103 36 251 a Foam (3% NH4CI + F103 + N2) 7. 10 Diverter ( ) 4 255 15 125 11 Spacer 3% NH4CI + F103 20 275 12 Acid 12% HCI 24 298 3 13 Mud Acid 9:1 Mud Acid 24 322 14 Overflush 3% NH4CI + F103 36 358 Overflush 15 Displacement 3% NH4CI + F103 211 ' 569 c\ • I 0 TREE . 4.1115" CAM WaLI-EAD * 13-SEr FMC -36A SAFETY AK/TES. H2S READINGS AVERACE 125 03 p#61 WHEN ON MI, WELL REQUIRES A SESV ACTUATOR = BAKER Ka ELEV . ea WIIBV ON M I, WELL ANGLE> TO' eg 111 16'. BE a Elit ... 37 I .. 1 2 22 90 54 0 : 1 --1 1 4- Es 1 1. TO ' H P FS OF X c N Ewocr P 0 = ( 111 I I KOP = 2743 Mix Art* . 91 15057 0 E:Slum MO . 106.8ft • - — _ DaturnlVD = NCO SS • I I 13-343' CSC; 68#, NT-60 CY I-E, H 3977' ID= 12 416' 4 °°' I LO Minimum ID= 3325" 1§. 10423' I E. I 11 H 9 " ' 47.' X 7 T f 4622' 143 ZXP LTP 0.6 2sr 9-540- x r FLEX CK HER, 6 0 ..= 4-1/2'l HES XN NIPPLE AILLOUT WINDOW to3444) 1 6-5,15' WHIPSTOCK404,12,07) H 4766 I 19 USN/ (0402, I--F I '.''''''' 3MIC 1 l Y14.44.4,71 u 1 1031 T H4-I tr HES X AIP ID = 3 St 3" 9 CSC 471, NT WS H 11901' 01 ' 1—...... Oa' Vei it._ ."- V. 0..4 NSCC ID 0 681" 41.404 0 10370' 7' X 4112' SKR 6 PKR 0* 3 870" 1 )11••••4 • t 4 Xt - . _" 4 . # ....."........ 111 10402' 41,2" tES X HP 0.3613 1041W H 12° TIEBACK, ID o* 5 250' I I L 110423' H 4112" HES XN AIP 10420' 1-17 x v IM ZXP .,„TP ID # 36Ir { 417 T130, 12 1-(10 T011 0152 tipt ID = 3 06' 104,S5 : ll , I I -',,,,..._ 10436" i 4,1 IT ALES, ID . 3 966' 1 - . 1. 1043W I 7' X 5 FLEX-LOCK \ \\i... L KR KM, 0' 4. 350' 1044, I 5" X 4 a* XEt CI *3 9212* 7" LNR, 260, L-80 EITC-M 6383 bpi, 0 = 6276" -1 10688 1-4Il II ■ FERFORA TWIN Fut IMAA Rf I fir', .. 1.4.4 Ar 1,1 1104W 6-314" SWELL PK 0 = 3 658" H 9 ' I REF LOG SLB OBIT ON 66102707 1 375 - 4 -8 S i;t0 ■IN 12416 53i4 SWELL PKR 0 = 3 958' ANGLE AT TOP PERF 90' I§ t4.46O c. , 13CtUF - 15 , 14° SWELL PKR, o . 3. I •:::. Note Prtfor to Produckton 06 for twit:algal pod Sias SIZE 5R INTERVAL 00n CATE .7 13624' H6-3,`.4" SWELL MR, 0 = 3.9W i 2-718" ®6 ' 14403- 14510 0 col 249 C lee& ips --,...._ _ 831 -1 14228' _ - 54A' SWELL PAR, 0 . 3 658" 1 2 /' 6 15010 15110 C 514120:17 ...;:. I 14050' ---11t-1ir ATA0 Cl8P 03383343311 =-- 1C21 .... I 144,30 ,.-16-16 PKIIt in . ise17 WO -1 16274 4,4•01 - . 4-172' LNTL 12 6# L-80 MT 0152 tyr 0= 3 956" 16383' DATE REV BY COMMENTS DATE REV BY COMMENTS • FRLOHOE BAY UHT 04f26133 ofitGINAL COMPLETION 01,1011 2 TAT#.1ma Al om K25 SAFETY NOTE WELL 03-36A 0403193 Felif EYA0 MENET No t070200 , 051071117 NMI SIDETRACK I03-3141 AF1ND 50.029 60507 STOPJC tiRLG DRAFT CORRECT1ONS SEC 11 TI ON R15E 8S8' PAL & 906" FSL C12.1113,09 TARIM, SET GBP I ADPERF (02t1211111 02111111 1493AJItt) ACCED SSSV SAFETY NOTE 8P Expiorstion (Alaska) 7 Mini -Log • • bp Tec 0 hl®g for Well T e c 9 Project P BU _ 03 -36A WF ;= '. trt K�r. f LAURA J. LARSON Scale 1 5000 Date 4/16/2012 Injector Well: 03 -36A UWI: 500292234001 Elevation: 55.67 X: SPUD date: 2007 -04- 1400:00:00 Country: USA Short name: 03 -36A Elevation datum: KB Y: Completion date: 2007 -05- 0600:00:00 Field: PRUDHOE Long name: DRILLSITE 03 NO 36A Total depth: 15365 Longitude: - 148.2710804 Status: State: Alaska Coordinate system: NAD27 AFT Latitude: 70.2307203 Operator: BPXA Company: BPXA Z GRMM_MWD z BEST K[ RDP PE Info u 0 P cnn TVDSS MD 3 i 1 GR (FEET) (FEET) TV055 a "' o ° --1:11=.4141. . 1 saoD 1:5000 �,,.,� ,,, ':. ,,, ti . - 8725 TSAR 43P - 8820 -, .... .- 11000 — -- ' l 31P - 8890 1 r , ti - 8935 ••' - 8950 11500 27P • L . r . 8960 -' _ • - 12000 - - 8970 • lir' _ - 8980 - . - 8985 t , 12500 — 1 . • Y • • - ` . ■ 13000 C - 8990 -- 13500 260 - , '� - Add Perf @ '� - 13,750' - 13,850' and .?___3-- - 14000 : CIBP . I I I ,_4.7-. - 8990 1 14,180' and - 8990 r 14 500 "= - 8990 j - • —Y - 15000 T sap BPS . - 8990 1- - 8 • ! PDS Coil Flag 10- Apr -2011 14190 4 5 CIBP 14,180'md 14200 sJJJ _ Packer 9 • Packcr 13700 Add Perf @ 13,750' - 13,850' and 13,800 4 10 . • . • „ . . 4400 Weil . COIL FLAG MI 4 t-iii, ow S um-r. C R , CA P 110k n IN Diadsmit 5iO3, ll'a - 10 - Ap - 219 1 Company BP EXPLORATION (ALASKA), INC. --; a Well 03 - 35A < Field PRUDHOE BAY Couny NORTH SLCPE State ALASKA 0 . 2 Surface Locaticn O tter mmes 1 R-‹ 0 .c *3 906.38' FSL & 8S8.93' FINL Jevoilry WS . v E ;p 11 C3 CL 2 G:( SEC 11 MP. 104 WE 15E ›. Ele.rebn i . g. Permanet Dawn IASI Derrab3n 0.0 (1 , 55,67 g f 1 R g Log Measured F rem Rli..9 55.67 FT. AboNe Perm Darn ) F 55.93' 3 ii (3 ez API Send tenter 5O-C4 9-22;40-0 1 G L 27.00. Dee 10 - Apr - 2011 Run Nurybe Ore PB 7 D Driller 1 5.274' PB 7 0 Lower Nol Tagged Brec Lowed lo1vIrt 1 14 674' bp Log Intenril 10 149' Cicen Hale Sue NA Tme Fluid Ireedied Fkids 003x Recorded Tem Ow F } N/A T - 110 1 1 1 011 Rue, 11 00 FINAL PRINT r 'fieLower on Mori 14 43 Emmet number SLB ON Ira Lmr.zion North &nye &woe Invocel* 7473 Recia By Wn. LleCroesai K. Wier Vitnesset1 Ey Mr. kiletho Mr. 1rt rn Br reo Re-axa 7 Lawn Rmord Run Numtes I 4 From ro SR: LW FI From /0 4 tr 1; 60 &1a� 10.435' 1 i Cymru %cud See 13 'Ft Toy Bottom 1 i See Siring 13 3.03' 68 0 Sirtem 3 97' i 7: P Sting 9 5,4" 47 (2 SArts7e 11 901' Leer 7' 213 CO A 503' 1(1.566' I : Leer 4 1r: 12 0 1).449' Leer . 11 • • A ll" PERFORATING PROCEDURE RIM Well: 03-36A API #: 50- 029- 22340 -01 Date: June 12, 2012 Prod Engr Bernhard Stechauner Office Ph: 907 - 564 -4594 H2S Level: Home Ph: 907- 677 -0860 N/A - Injector Cost Est: $150,000 Cell /Pager: 907- 360 -7485 CC or AFE: APBINJEC WBL Entries IOR Type Work Description S Pull MCX, drift to deviation 200 C Drift/Log, set CIBP, perforate 100' S SBHPS, set MCX Well Obiectives and Perforating Notes: The objective of this procedure is to set a CIBP to isolate all current perforations and to add 100' of new perforations for the third MI bulb in the well. Note: Min ID = 3.725" @ 10,423' MD (4 -1/2" HES XN Nipple) Attachment: Tie in log with proposed new perforation intervalls annotated. Reference Log Tie in Log Add feet Log: MD Log Coil Flag to the tie -in log to be on Date: 4/30/2007 4/10/2011 depth with the reference log. Company: SLB PDS Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re /lperf 13,825' - 13,850' 13,825' - 13,850' 25' 6 Random 60° 2 Addperf 13,800' - 13,825' 13,800' - 13,825' 25' 6 Random 60° 2 Addperf 13,775' - 13,800' 13,775' - 13,800' 25' 6 Random 60° 2 Addperf 13,750' - 13,775' 13,750' - 13,775' 25' 6 Random 60° 2 Addperf Requested Gun Size: 2 - 7/8" Charge: 2906 PowerJet HMX Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown /Suggestions to Achieve Drawdown Last Tag: 14,665 ft MD on 4/12/2011 Est Res. Pres. @ 8,800 TVD is 3100 psi Perforation Summary Summary Dist Well: 03 -36A Town: Date: API #: 50- 029 - 22340 -01 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U - O /B /U - O /B /U - 0/B/U - • 12 • • STATIC BOTTOM -HOLE PRESSURE SURVEY Ver14, Rev 08122004 (JOM) Well: 03 -36A API #: 50- 029 - 22340 -01 Date: 6/12/2012 Prod Engr Bernhard Stechauner Office Ph: 564 -4594 H2S Level: Cost Est: $5,000 Home Ph: 677 -0860 N/A -- Injector CC or AFE: APBINJEC Cell /Pager: 360 -7485 WBL Entries Type Work Description Comments S Pull MCX, Drift to dev C Set CIBP, Add Perf 100' S SBHPS, set MCX Well Objectives, Lowing Notes, and Special Instructions: Opportunistic static due to coil tubing intervention. Datum 8800' SS I Well Data Procedure: Last Tag: 14665' MD Tag date: 4/12/2011 1. Make 10 min pressure stop in lubricator Max Deviation 91 Begs Depth: 14,115' MD 2. Drop below the first pressure -stop requested. Pull -up to specified depth. 3. EJL: Measure pressure until it varies less than 1 psi in 20 min. Min. SI Time: 7 Days I Logging Data S /L: Hold guages at depth for time specified 4. E/L: Measure pressure until it varies less than 1 psi in 20 min. S /L: Hold guages at depth for time specified Requested Stops: MD SS Time 5. E/L: Measure pressure until it varies less than 1 psi in 20 min. First 10579' 8600' 15 min S /L: Hold guages at depth for time specified Second 10727' 8700' 15 min 6. E /L: Test tool in lubricator at 3000 psi with calibrated test gauge Third 10888' 8800' 15 min S /L: Hold guages in lubricator for 10 min stop. Compare to test guage Fourth 11115' 8900' 15 min 7. Return well to operations to POI. Summary Dist Well: 03 -36A API #: 50 -029- 22340 -01 PE Town: Date: Anch Prod Engr Service Co. New Tag: 'MD P.D. Center Upper Lower Date Time MD SS Gauge Gauge Temperature Test Gauge Pre -Job Lubricator Pressure 10579' 8600' 10727' 8700' 10888' 8800' 11115' 8900' Post -Job Lubricator Pressure Type of Pressure Tool SITP (Tubing): psig SICP (9-5/8"): Shut In Date: Comments: and Time: Total Shut In Time (hrs) 13 wye +! v+.4* =tom .. k t < y „ ?'' • ■rimm rm ;.. sraa^ry . w s^ antree_ . .*` :1'�d r s+ 'sm.';as•; ^, "n . rr.x*>.s'l•;a m.,;,z - 7 ,. ^•3..1,:. ,4 ., • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 a 0 7 - O°9-'62 6A Mr. Tom Maunder C Alaska Oil and Gas Conservation Commission 1 1 °1 �� 333 West 7 Avenue $W Anchorage, Alaska 99501 %Y `r R Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 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, API and PTD numbers, 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, Gerald Murphy, at 659 -5102. Sincerely, 1‘; FEE 2 2 'eul Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS -03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date ft bbls ft gal 03-01 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03 -02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03 -03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03-06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03 -07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03 -08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03 -09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03 -10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03 -11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03-12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03 -14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03 -15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03 -16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03 -17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03 -19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03-20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03 -21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03 -22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03-24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/120011 13.6 7/17/2011 03 -26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03 -27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03 -28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 03 -29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 , 03-33B 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03-34B 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03-35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 +9 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/282010 03 -37 2091390 50029234210000 2.5 NA 2.5 NA 16.2 8/2/2010 • MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, August 08, 2011 TO: Jim Regg 2 / <' P.I. Supervisor 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03 -36A FROM: Bob Noble PRUDHOE BAY UNIT 03 -36A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 5re— NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 -36A API Well Number: 50- 029 - 22340 -01 -00 Inspector Name: Bob Noble Insp Num: mitRCN110711141132 Permit Number: 207 -020 -0 Inspection Date: 7/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03 -36A ' Inj. G ' TVD I 8523 - IA 686 2491 2456 2440 - P.T.D 2070200 TypeTest SPT Test psi 2491 - OA 202 255 251 247 Interval P/F P " Tubing 2692 2695 2698 2711 Notes: r'dsF 2l3c AliAQ,) St Monday, August 08, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 13, 2011 TO: Jim Regg -7 P.I. Supervisor r 14 1( I t SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03 -36A FROM: Bob Noble PRUDHOE BAY UNIT 03 -36A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 - 36A API Well Number: 50 029 - 22340 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110711141132 Permit Number: 207 - 020 - Inspection Date: 7/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 03 -36A " Type Inj. W TVD I 8523 - IA 686 2491 - 2456 2440 - P.T.D 2070200- TypeTes_SPT Test psi — _ 2491 - OA 202 255 251 247 Interval 4YRTST P/F P ` Tubing 2692 2695 — 2698 2711 Notes: M A r d 4 e5-1- ? t)�a Wednesday, July 13, 2011 Page 1 of 1 Injector 03 -36 (PTD #2070200) 4 -Year AOGCC MIT -IA Page 1 of 1 • • Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, June 24, 2011 2:54 PM To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: Injector 03 -36 (PTD #2070200) 4 -Year AOGCC MIT -IA Mehreen, Jim and Tom are both out of town. Your proposal is acceptable, just give the inspectors advance notice of the upcoming MIT -IA so they can schedule. Guy Schwartz, It; "�) Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, June 24, 2011 10:58 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: Injector 03 -36 (PTD #2070200) 4 -Year AOGCC MIT -IA Hi Jim, Injector 03 -36 (PTD #2070200) was due for a 4 -year AOGCC MIT -IA on 6/24/2011. On 6/8/2011 we conducted a pre -AOGCC MIT -IA to 2500 psi with the well on injection that passed. The well was shut in on 6/10/2011 and has remained shut in due to planned shut down work. Based on the initial shut down schedule this well was expected to be back on injection on 6/22/2011 after which we had planned to do an AOGCC witnessed MIT -IA. During the shut down, additional corrosion has been found on process piping that has caused this well to remain shut in. At this time we are expecting the repair work to be completed on 6/30/2011 after which this well will be brought back on injection. As soon as the well is back on injection and stabilized, we will schedule the witnessed MIT -IA with the AOGCC Slope inspector and submit the results. Please let me know if this will be acceptable or if you have any further quesitons. Thank you. Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 6/28/2011 f STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 ACID Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate In Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ - 207 -0200 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 -6612 + 50- 029 - 22340 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028332 — PBU 03 -36A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 15365 feet Plugs (measured) 14650 feet true vertical 9043.12 feet Junk (measured) None feet Effective Depth measured 15274 feet Packer (measured) SEE BELOW feet true vertical 9043.39 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 36 - 116 36 - 116 1490 470 Surface 3942' 13 -3/8" 68# NT -80 35 - 3977 35 - 3731 5020 2260 Production 4745' 9 -5/8" 47# NT8OS 32 - 4777 32 - 4243 6870 4760 Liner 5989' 7 "26# L -80 4599 - 10588 4132 - 8662 7240 5410 Liner 4947' 4 -1/2" 12.6# L -80 10416 - 15363 8548 - 9043 n �84�30ry �d 7500 Liner A`` , U 1 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ • _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L -80 26 - 10435 26 - 8560 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 10379 8523 5" HR ZXP LTP 10428 8556 5 -3/4" SWELL PKR 11849 12415 9016 9040 5 -3/4" SWELL PKR 13020 13624 9044 9046 5 -3/4" SWELL PKR REC EIV 14228 14830 9045 9046 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2 0 20 Treatment descriptions including volumes used and final pressure: ikiesk��, &$� pp QU$$IOn 13. Representative Daily b9g�� or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 4,469 2,966 Subsequent to operation: SI 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 '' Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -057 Contact Joe Lastufka Printed Na - , e Last fk Title Petrotechnical Data Technologist Signatu = lain 1 Ffione 564 -4091 Date 4/20/2011 — RB HAAS 2O1 Form 10-404 Revised 10/2010 APR y Z �' ` Submit Original Only Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -36A 5/4/07 PER 15,010. 15,110. 9,047. 9,045.36 03 -36A 2/8/09 APF 14,490. 14,510. 9,045.95 9,046. 03 -36A 2/8/09 BPS 14,650. 15,110. 9,046.22 9,045.36 03 -36A 2/12/09 APF 14,460. 14,470. 9,045.9 9,045.92 03 -36A 2/12/09 APF 14,470. 14,490. 9,045.92 9,045.95 03 -36A 4/11/11 APF 14,355. 14,380. 9,045.7 9,045.81 I 03 -36A 4/11/11 APF 14,517. 14,542. 9,046.02 9,046.11 03 -36A 4/12/11 APF 14,330. 14,355. 9,045.61 9,045.7 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 03 -36A 207 -020 PERF ATTACHMENT • • 03 -36A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/10/2011 CTU #9 w/ 1.75" OD CT. Job scope: Perforating & acid treatment . Perform weekly BOP test. MU and RIH w/ PDS memory GR/CCL logging tool inside 2 -7/8" OD 'carrier w/ 3.70" OD JSN. Log up from 14624' to 10100' at surface confirmed good DATA. Job in progress... 1 4/11/2011 € CTU #9 w/ 1.75" OD CT. Job scope: Perforating & acid treatment RIH w / 3 3/8" x 25' PJ3406 -HMX 6 spf per perf guns. Gun run #1 14517' - 14542' Gun run #2 14355' - 1 14380' «< Job in progress >» 4 l 4/12/2011 CTU #9 w/ 1.75" OD CT. Job scope: Perforating & acid treatment. RIH w / 3 3/8" x i25' PJ3406 -HMX 6 spf per perf guns. Gun run # 3 top shot 14330' - 14355' OOH w/ all shoots fired. MU 2" JSN RIH Load & Kill well with 330 bbls 3% NH4CL, 80 bbls Diesel & cap with 5 bbls 60/40 meth. RIH tag CIBP to correct depth for acid I placement Pump down CT 40 bbls 10% DAD while recipricating across perforations I from 14550'- 14320' MD pump acid as per pump schedule. «< Job in progress »> 4/13/2011 CTU #9 w/ 1.75" OD CT. Job scope: Perforating & acid treatment. Pumping displacement fluid as per pump schedule. At surface blow reel down for reel swap. 1 <<< Job complete »> E 1 • • FLUIDS PUMPED BBLS 330 3% NH4CL +F103 80 DIESEL 36 10% DAD ACID TRITATIONS 9.5 90 12% HCL TRITATION 12.5 90 9:1 MUD ACID TRITATIONS 9.8 & 1.08 S.G. 151 60/40 METH 777 TOTAL TREE = 4- 1/16" CM/ . WELLHEAD = 13 -5/8" FMC .0 3 - 3 6A SAFETY OS: WELL REQUIRES A SSSV ACTUATOR = BAKER WHEN ON MI. WELL ANGLE > 70 @ 11115'. KB. ELEV = 60' BF. ELEV = 30 KOP = 2700' ' 1 I 2254' H4-1/2" HES X NIP, ID = 3.813" I Fl Max Angle = 91° @ 15057 I 2900' I - I EST TOP OF CEMENT (06/20/06) I Datum MD = 10888' • Datum TV D = 8800' SS • .41 13 -3/8" CSG, 68 #, NT -80 CY HE, - 3977' ID = 12.415" 7 ,, I 4600' H9-5/8" X 7" HR ZXP LTP, ID = 6.29" I Minimum (D= 3.725" @ 10423' 4622' H9 -5/8" X 7" FLEX LOCK HGR, ID = 6.30" 1 4 -1/2" HES XN NIPPLE MILLOUT WINDOW (03 -36A) 4756' - 4777' 19 -5/8" WHIPSTOCK (04/12/07) 1 - I 4756' I9 -5/8" EZSV (04/12/07) I - 1 4777' I 3W Mal AV 110-Mal % / 4 .4 .. 9 -5/8" CSG, 47 #, NT -80S, - 11901' I ■ 1031 T 4 1 /2" H ES X NIP, ID = 3.813" ,....... - 1 � NSCC, ID = 8.681" + • I � I i 0 kj I 10379' 1 X 4 -1/2" BKR S -3 PKR, ID = 3.870" i•eg6:.:. :4 7 /2" HES X NIP, ID = 3.813" I 10416' 1 -I12' TIEBACK, ID = 5.250" I I 10423' 1 - 1 4 -1/2" HES XN NIP, ID = 3.725" I 10428' 1 X 5" HR ZXP LTP, ID = 4.350" 1 4 -1/2" TBG, 12.6 #, L -80 TC11, .0152 bpf, ID = 3.958" 1-1 10435' 11 10435' -14 -1/2" WLEG, ID = 3.958" I 10439' I - 1 7" X 5" FLEX -LOCK LNR HGR, ID = 4.350" 10449' 1 X 4-1/2" XO, ID = 3.920" I 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1-1 10588' 1 - 4 _, 1.::4 11849' I - 15 - 3/4" SWELL PKR, ID = 3.958" I PERFORATION SUMMARY REF LOG: SLB USIT ON 05/02/07 _. 1111 12415' . 1 - 15 - 3/4" SWELL PKR, ID = 3.958" I ANGLE AT TOP PERF: 90° @ 14460' _, �_ 13020' H 5 -314" SWELL PKR, ID = 3.958" 1 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 0. _■ 13624' , - - 3/4" SWELL PKR, ID = 3.958" I 2 -7/8" 6 14460 - 14510 O 02/12/09 2 -7/8" 6 15010 - 15110 C 5/4/2007 ■■1 _1 14228' J-- 15 SWELL PKR, ID = 3.958" I 14650' -14 -1/2" WFD CIBP (02/08/09)1 14830' H5 -314" SWELL PKR, ID = 3.958" I I PBTD H 15274' �.�.p.� • . .. , . 4 I 4 -1/2" LNR, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" 1-1 15363 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/29/93 ORIGINAL COMPLETION WELL: 03 -36A 04/29/93 N28E RWO PERMIT No: 2070200 05/07/07 N7ES SIDETRACK(03 -36A) API No: 50- 029 - 22340 -01 06/05/07 STG /PJC DRLG DRAFT CORRECTIONS SEC 11, T1 ON, R15E, 899' FWL & 906' FSL 02/16/09 TAR/SV SET CIBP/ ADPERF (02/12/09) 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) SIEFE Cl[F ALLMIKKA SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Josiah Igwe Petroleum Engineer BP Exploration (Alaska), Inc. © ' P.O. Box Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03 -36A Sundry Number: 311 -057 WOOED Dear Mr. Igwe: MAR 0 2 U 11 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. 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 reconsideration. A request for reconsideration 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. Sincer • 4110 O n K. Nor - a o • sioner DATED this S day of March, 2011. Encl. STATE OF ALASKA .� ALASKA" AND GAS CONSERVATION COMMISSI J - APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 , Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0 _ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 207 -0200 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22340 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ❑ PBU 03 -36A - Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028332 PRUDHOE BAY Field / PRUDHOE BAY Pool ` 11. 1 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15365 • 9043.12 • 15274 - 9043.39 - 14650 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 31 111 31 111 1490 470 Surface 3947' 13 -3/8" 68# NT80 30 3977 30 3732 5020 2260 Production 4723' 9 -5/8" 47# NT80S 32 4756 32 4230 6870 4760 Liner 5989' 7" 26# L -80 4599 10588 4132 8662 7240 5410 Liner 4947' 4 -1/2" 12.6# L -80 10416 15363 8548 9043 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 SURFACE 10435 Packers and SSSV Tvoe: 7" X 4 -1/2" BKR S -3 PKR Packers and SSSV MD and TVD (ft): 10379 8523 1 5 -3/4" SWELL PKR 11849 9016 5 -3/4" SWELL PKR 12415 9040 5 -3/4" SWELL PKR 13020 13624 9044 9046 5 -3/4" SWELL PKR 14228 14830 9045 9046 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG E // Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah lgwe Printed Name r - Josiah lgwe Title PE Signature W ._ - Phone Date i o, � 564 -4753 3/1/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ \ ` —05-1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED! Other: /- R 0 1 2 f 0 Alas Qu a G C Ca Subsequent Form Required: / o - 41 lij "�l1�M illri APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3-3—/( Form 1 4 3 tkl � \ RJGINAi Submit in Duplicate 03 -36A 207 -020 . ' PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -36A 5/4/07 PER 15,010. 15,110. 9,047. 9,045.36 03 -36A 2/8/09 APF 14,490. 14,510. 9,045.95 9,046. 03 -36A 2/8/09 BPS 14,650. 15,110. 9,046.22 9,045.36 03 -36A 2/12/09 APF 14,460. 14,470. 9,045.9 9,045.92 03 -36A 2/12/09 APF 14,470. 14,490. 9,045.92 9,045.95 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 03 -36A Adperfs /Mud Acid AFE #: APBDO3WL36 To: J. Bixby/T. Norene GPB Ops Team Leaders Date: Feb. 21, 2011 Ross Huebel Petroleum Engineer From: Josiah Igwe Wells Engineer AFE: APBDO3WL36 -C Est. Cost: Subject: 03 -36A Coil Adperfs and Mud Acid Stimulation ✓ IOR: 500 Operation Sequence: 1. S Slick Line retrieve 4.5" MCX plug and drift to max deviation 2. C Coil Flag, Adperfs and Mud Acid Stimulation 3. 0 Put on PWI 4. S Set 4.5" MCX plug and POI Current Status: WAG injector Last test: 02/15/2011: 5,697 MCFPD, Injection Pressure at 3,250 psi Max Deviation: 91 deg @ 15,057' MD Last Downhole Op: 02/13/2009: S /Line set 4.5" MCX plug Last Tag 02/12/2009: CT set CIBP at 14,650' Minimum ID 3.725" @ 10423' 4 -1/2" HES XN Nipple Last SBHP /SBHT: 02/08/2008: 2916 psi at 8800 tvd Latest H2S Value: N/A Obiective: The objectives of this job are to obtain a Primary Depth Control (PDC) and Jewelry Log for 03- 36A, perforate 14330'- 14380' and 14517'- 14542', acid stimulate the open perforated interval, and put the well on water injection. Well History: Well 03 -36A was sidetracked in May 2007 as a horizontal MI injector. The 4 -1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals. The first MI cycle has been completed. The second MI cycle began in the first half of 2009, but injectivity was always low and the effectiveness of the MI bulb was compromised. 1 • 03 -36A Adperfs /Mud Acid AFE #: APBD03WL36 The first bulb was successfully displaced in 100' of open perforations from 15010'- 15110'. The second zone was originally only perforated in 50', 14460'- 14510', and did not successfully get a MI bulb away. Both sets of existing perforations were done without the use of a tie -in run with a memory log so it is possible the last set of perforations were in a mud stone, directly above the recommended perf depth. The two most likely candidates for the poor injectivity are poorer rock quality in the current set of perfs and /or damage due to drilling. Additional perforations and an acid stimulation should address both potential problems. The forward plan is to run a jewelry log, conduct the perf job and acid stimulation, inject water to displace the last MI bulb and then go back to MI injection at higher rates. Risk Discussion: Swell packers were used in the completion of this well and set at the following depths: 14,830', 14,228', 13,624', 13,020', 12,415', and 11,849'. It is very important that the perforations are not shot into one of the swell packers. Contacts: Ross Huebel Production Engineer Office / Cell: 564- 5779/832- 455 -0275 Josiah lgwe Wells Engineer Office / Cell: 564 - 4753/590 -0610 S -Line Procedure 1. Pull MCX from 4 -1/2" HES X Nipple @ 2254' 2. Drift to maximum deviation w/4 -1/2" Dummy WRP. Attachments: o Perforating procedure — page 7 o Tie -in Log: SLB SCMT log dated 05/31/2007 - Page 8 o 03 -36 Well Bore Schematic — page 9 o Tie -in Log cover copy — page 10 Coil Procedure: Drift 1. MIRU CTU • Ensure that coil has up to 16,000' feet length of coil 2. If debris may be in coil after previous jobs, consider pumping 1.25" ball (in 1.75" CT) w/ 60/40 meth. Note the displacement volume. 2 • 03 -36A Adperfs /Mud Acid AFE #: APBD03WL36 3. Make up BHA with PDS logging tool and 3.70" bull nose. • This will serve as a coil flag and a drift for 3 -3/8" gun 4. Open tree valves and RIH checking CT weight as required 5. Tag CIBP @ 14,650', PUH to 10 and begin log up hole at 60 fpm 6. Flag pipe as required and continue logging up to 10,750'. • The reason for logging up to 10,750' is to get a good tie in at a major shale. 7. Wait 5 minutes for logging break. 8. POOH pumping CT displacement down backside 9. At surface LD logging tools, check for good data and calculate depth correction to shoot perfs. • Tie in Log : SLB SCMT log dated 05 /31 /2007(check for final print) CT Procedure: Adperfs. 1. MU tool string and RIH Gun #1 SLB 25' gun 3406 PowerJet HMX, 6 SPF 60 deg phasing. o Note Max. diameter of gun in liquid/gas after shot is 3.6673.70 ". ( Make sure there is enough fluid at the shooting depths) 2. Run in Hole to flag for depth control. PUH and correct to top shot depth 3. Perforate interval (14,517' — 14,542') o Note any tubing pressure change in the AWGRS summary 4. At surface, makeup BHA #2 SLB 25' gun 3406 Powerjet HMX, 6 SPF 60 degree phasing 5. RIH to flag for depth control. PUH and correct to top shot depth 6. Perforate interval (14,355' — 14,380') 7. At surface, makeup BHA #3 SLB 25' gun 3406 Powerjet HMX, 6 SPF 60 degree phasing 8. RIH to flag for depth control, PUH and correct to top shot depth 9. Perforate interval (14,330' — 14,355') 10. POOH. 3 • 03 -36A Adperfs /Mud Acid AFE #: APBD03WL36 Acid Stimulation comments; • Filter all fluids that will enter the perforations to 3 microns absolute. • Obtain oil sample from offset producer and deliver to Schlumberger Well Services Lab for pre -job emulsion /sludge testing. Allow 5 days prior to treatment due to tests that need to be done before pumping commences. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • In general, pump job at maximum allowable or achievable rate /pressure. Scheduled rates are estimates only. Perforation Details Zone MDT MDB H Status Z2c 14330 14380 50 Open Z2c 14460 14510 25 Open Z2c 14517 14542 50 Open Total Footage: 125' Design Details: Wellbore Volume 220 bbls to top of pert at 14460' MD Acid Design 30 gpf of 12% HCL and 30 gpf or 9:1 Mud Acid Foam Design basis 0.10 bpf, 70% foam quality Pres 02/08/2008: SBHP 2916 psi at 8800 tvd, SBHT is 206 psi CT Acid Treatment Procedure 1. Ensure the followings before starting this job: • Current MSDS for this job is onsite and acid safe handling procedures are followed • Ensure that the acid shower trailer is on site and functional • Keep out all personnel not associated with this job 4 • 03 -36A Adperfs /Mud Acid AFE #: APBD03WL36 2. MU CTU tool string with 2.00" JSN. 3. Pickle CT with 10 bbls of 12% HCL (if coil is new and has not been pickled). 4. Load well by pumping down backside with -330 bbls (1.5 x wellbore volume) of 3% NH4CL (80 -110 degF) at 4 -5 bpm if possible while RIH. 5. Pump - 100 bbls of diesel to achieve a positive wellhead pressure. , (based on 2916 psi SBHP). • Diesel must be pumped down the backside only as it will destroy the foam. 6. RIH CT to tag CIBP at 14,650'. PU 10' and flag pipe. Establish injection test using 50 bbls of 3% NH4CL not exceeding 2000 psi WHP. 7. RU acidizing equipment. PT surface lines to 4500 psi. 8. Jet acid as per pumping schedule across the perforations down CT at maximum rate below 0.65 psi /ft gradient. • Reciprocate coil between intervals as per program. 9. Exceed frac. gradient if necessary to establish injectivity or complete the job, reduce pressure after injection is established. • Note: Maximum allowable treating pressure is 2000 psi. 10. Once over flush is out of the nozzle, displace tubing with 100 bbls of 3% NH4CL down backside. o Note any increase in injection rate while over displacing. 11. POOH and freeze protect top of well with 38 bbls of 60/40 meth 12. RDMO. Mixing Recipe 90 bbls 9:1 Mud Acid Composition A264 Corrosion Inhibitor 6 Gal /Mgal A201 Inhibitor Aid 15 GaI /Mgal F103 Surfactant 2 GaI /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal U067 Mutual Solvent 50 gal /Mgal 90 bbls 12% HCI Composition A264 Corrosion Inhibitor 6 Gal /Mgal 5 • • 03 -36A Adperfs /Mud Acid AFE #: APBD03WL36 A201 Inhibitor Aid 15 Gal /Mgal F103 Surfactant 2 Gal /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal Note: 3% NH4CL, 0.2% F103 and 2% U067 3% NH4CL, 0.2% F103 40 bbls 90:10 DAD 10% Composition H036 Hydrochloric Acid 10% A026 Xylene 10% A264 Corrosion Inhibitor 6 Gal /Mgal A201 Inhibitor Aid 15 Gal /Mgal F103 Surfactant 2 Gal /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal Note: Well has L -80 liner. Ensure correct additives are used. BHST 206 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90 -110 F. 3. Pad Operator: To be monitored by WOE. • POI 4. Slick Line: • MIRU • Set MCX plug at 2254' • RDMO 6 • • • 03 -36A Adperfs /Mud Acid AFE #: APBDO3WL36 7 . • 03-36A Adperfs/Mud Acid AFE #: APBDO3WL36 PERFORATING PROCEDURE , I 1 -A.- -,, ----- -- Well: 03-36A API #: 50-0292-2340.91 Date: 02/21/2011 Prod Engr: Ross Huebel Office Ph: 584-5779 1 H2S Level: . I Home Ph: 832-485-0275 Cont Fax: RUA CC or AFE: .., WBL Entries IOR Type Work Desciption 500 i S Retrieve MCX plug and drift to deviation 500 C rAdperfs / Mud Acid Stimulation 500 ' S :Set MCX plup Well ObiectIves and Perforating Notes: The objective of this procedure is to shoot perfs and perform mud acid stimulation to increase injection. Attachment: Reference log with proposed perfs annotated, 57100' scale. Reference Log Tie in Log Add/Subtract 0 feet Log: MD SCMT tie-In log to be on Date: iiiiiiI2597:: 18781729:9:77 depth with the reference log. Company: air — ST8 ''' Depths (from-to) Depths (from-to) Feet SPF Orient Phasing Zone Ad/Reaped - 14,330 14,356 25' 6 random ox ADPERFS - 14356 - 14,380' 2T 6 umdom .. ADPERFS - 14,51T - 14,542' 25 . 6 mmdom ev ADPERFS . - . - MmwmWdGunSimin 34M" Charge: PJ 34(X) HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessay Preferred Amount of Drawdown/Suggestlons to Achieve Drawdown N/A Last Tag: 14,650 ft MD on 2/12/2009 Est Res. Pres. (!) 8800' MD is 2,916 psi ............,_. , Perforation Summary Summa Dist Well: 03-36A , Town: I Date: API 4: 50-0292-2340-01 Prod Engr: , ' . Prod Engr I P.D. Center .,..... PBTD General Conwnents: Depths Balance Referenced to BHCS Gun Dia. Orient. 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I : { swim■ _sw im_ $* < �" � Nommi mum me € __ __♦♦I _a__�_ NM mom AV :.' z = _ ____sw81.a _.rt__3 _ ®_ ®.bi__ BE _ : i. i r . n ::,e,`' a _.I. swim . on ..l__ 'T f. . __.��__a so ___ _ eY9!® ® swim _; 'w, �� ` iiliit:�iII■„1 ____IB 0A� ® ® ia '✓ �' 1 swim► , __..I r. wA___ ti sw��_sw..a ■.—___ _w..�___u1 ■.,__ C n=Zii _1A ..swim__ It lo mom Imill um IMMAIIIIIIIIIIMMIMMIMMWIONIN 14500 re I= NM INN �__..I _ __1.I .�____ n swim ■w____ r F 3^e _I_ ME _ ..____ _Irm a __..t u___ I NM MOM __m.E ____._____ ■.____ 0 MI 1.111111111111=11111111111111 Mil MIMI1 :Z _ swim Inn INN Iri — _I_�__..I . ...m.......•. alma_ milmmil - - Y,y Tt�SJ ■.___a � �. r t 1111 IIIil ::aa == ���� i mom wire a r.__mit 14517'-14542' ■.swim__ m a { 3 _ ._ _ ■ ... __ ,,. , ,, , t e r ■.swim__ ?n I Milli ...rI._111•111__ ■ ■I alma___ r ■.swim__ C M'!e ° �✓'' ' alma___ 2 _ u____ ■.swim__ z '-1 3 .m____ 4 MI ■.swim__ _Ir immlw___mw1 aa__.■ %caaaa 2,. y ■■■■et u____ -sW im mil mil MM. . MN� �.. _ "; _ _ .._ —sw im ? ',fix 11.1■�i11iil,i1 _a alma - -_ r, ` __MINIIMININII__..i MIIIIAIIIIIIIIIIIIIONIINM __m.I ■1C____ t = ___ MIIMII•__..e ■.____ fi t, } __/'__m.I •_III _ ___I ■!swim__ { __I - UUI _ a i:aC�a ___�__imi ■. _ ___I swim_ __r__..1 _.Tr a / swim __w.I ■,=1.11111■■„1 ■.__swim __� __..e sw ___t ii — w aaa , , ES ■11111E 14600 C __Iw, __..aaaa _ a rf -- ---— -- ----- = ._ mid � .."S..k C3 ■ �r _ __ -___ sw im_ 9 , • 0 03-36A Adperfs/ Mud Acid AFE #: APBDO3WL36 T. 44118V :111-ill. i, ,: .• 0336A SAFETY NOTES: WELL REQUIZES A SSW - - ACTUATOR . . .:: -, WHEN ON Mi. WM. ANCLEt Ir 41) 111119`, I NIL 11.13/ . W BF_ REV w 3O KOP . 27W 1 • • 1 225C Hr FESX PPR D w3.913 I xiii, I goo' HEST TOP OF mate ReiZiKK9 I ... nililin 193. IONS 21 1 Oaken 1VD w SSW SS 13.3m- csa, ow Nr-se ME, H 397r D.12.416" I hEnimuni Et= 3.725* (D) 10427 1 A 1 4ew H9.11,11 r FEtZXPLIP, ID. r mar HD.filrxr mac LODI 1411‘ D. gm- 1 411r HES XN HIV LE 1 ILIJOUT WED 013.1111A) 476ff • 4777 1 196E7 WFIFSTOCK (04/124117) H 4715f 1 lo-cir SEW (oaf TD foa I-1 477T ."14•1014■44" IMI fr- ior 4 1111' + 0 o• #4, — our Fen- FES X tat ID. 71917 I WO 4 0 0 4 )444400 9.6A1" CSG, 470, NUM, WNW 440404' MCC, 10. LBW F + 1 4 1:01 99..3], lir x 4-DT BKR SS PAR D .31170" V MA 4 2 PI 1 iisi_?, UMW El a- weAcK, 'D. Lair I ViLtr HA i dr Fes xpa RP, ID. 2.72S I 1)9429 Hai 51R_ZXP LIR a .4iscr 1 440 IBS. 12119, LAD Teti, .0E2 bpf,113.1991* -1 r17. - . I .. I j 'ILLI..7 A 4A2 %LEG, D .29517 I -. r X 6" FLEXLAXIX U91413R D . 42517 um. HEr X4-92* VD, ID . 3W fr LM 2131. 6118 ETIC4A, .131290., ID. LEV H leer I-1 IL tlaillf 6-314" SWELL PKR, D . SSW Q V. PD‘FORA1IC00 SLAMMARV .L PEF Wee SUL UT atisamir k m b...2 1241$ . 1-15-air sortat ma v • aser I ANGLE AT 10P PEFF: 97 49 MAW 13412, &sr savammit D • agar i •:, ...I K. Mita Rehr ioPealuaket L is Failaikal dila SEE SPF INIEFSAL Opealkir DATE c le 43404' &sr savem Rat D • 3,95r zwr 6 14E10. 14510 0 WON 1422, 1 SWELLPKR ID . mom 1 ZITS ft IBM ti. El* C 5740007 Q. lc imer 1-44.112 mu CEP WAN% I .7..% Mr wr IT -ISSN` SNELL Pia 0 . ILWIr I FWD ZA „.... ._ I Veil 44.4 144 Cr UR 12.69, LSO TOL EIS2 bpf , ID. 3.95f7 14503 ... DATE REV BY OCASENTS DATE FEV BY COLGENIS PRINCE BAY MT 04(20093 DRIGIKAL cot W ION WELL_ 021.20A 041871IS ME RWD FERIBT Ha: 01/97717 AIRES SIDETRACK (23 AR 01w 92.029 99916107 STSTRIC DR.G DRAFT CCORECTICIE SEC it. TPA WEE FEW PAIL & 907 FSL 03 WOE TAP/Sii SET CRP 7 AOPERF (027 12102) 0211 i 71 1 MAO ADM SESV SAFETY NOTE MP flip 'oration (Ahab a) 10 co J Company: o z o BP EXPLORATION ALASKA, INC. (0 ° p Well: 03_36A ! ll11111117141/.119 SKA 7 Field: PRUDHOE BAY co Q Borough. NORTH SLOPE skit ALA co SLIM CEMENT MAPPING TOOL WELLTEC TRACTOR CONVEYENCE N. Z 31- MAY -2007 905.9' FSL & 898.73' FWL Elev.: K.B. ri ,5g * z A SURF G.L. 27 ft u D.F. 55.5 ft 1 1 2 a 8 Permanent Datum: MSL Elev.: 0 ft IIP Log Measured From: DF 55.5 ft above Perm. Datum s�� c Drilling Measured From OF 8 _ ea - API Serial No. Section Township on Range r L. 8 50-029-22340- Ot 11 t ON 15E �; " Ltlgginq Date 31 -May X007 :F ' n n6i ONE ,-":A Depth Ru Dri 15274 ft Schlumber Depth ��: Bottom Log Interval 15150 ft Top Log Interval 9734 ft " •s Casing Fluid Type SEAWATER Salinity Density 9.6 lbm /qal Fluid Levef 1100 ft • � BIT /CASING/ TUBINCr STRING Bit Size 8.000 in e From * To Casin /Tubing Size g 4.500 in Weight a e Ibm /ft Grd L -80 ' J From 10435 ft 15365ft s � To Location Maximum Recorded Temperatures 189 degF Logger On Bottom Time 1 Jun -2007 0:30 Unit Num corded 2150 PRUDHOE BAY I �� ��u ; R e By WIBLE /DICKINSO . t `; Witnessed B BOYLES / LYNC M ._ M 0 1~ ,- ~' .. ~ w~ R ~ <~,. .~ ~x ~~ .. i'g~f. ~ ~.sY'~~`F. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc QA vL -~- DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070200 Well NamelNo. PRUDHOE BAY UNIT 03-36A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-22340-01-00 MD 15365 TVD 9043 Completion Date 5/6/2007 Completion Status WAGIN Current Status WAGIN UIC Y - REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATgN Types Electric or Other Logs Run: MWD DIR / GR /RES / PWD /Vibration, MWDDIR / GR /RES / ABI, (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iy meairrmt rvumoer Name acme meaia No start stop ch Keceroea comments og Corrosion 5 Col 1 0 5050 Case 5/16/2007 USIT, CBL, CCL, GR 12- ~ Apr-2007, og Cement Evaluation 5 Col 1 0 5050 Case 5/16/2007 USIT, CBL, CCL, GR 12- Apr-2007 i g Cement Evaluation 5 Col 1 0 4600 Case 5/31/2007 USIT, GPIT, GR, CCL ~ Corrosion Eval 3-May-2007 ~ Log Cement Evaluation 5 Col 1 0 4600 Case 5/31/2007 USIT, CBL, VDL, GPIT, GR, CCL Cement Eval Log 3-May-2007 D D Asc Directional Survey 0 15365 Open 6/5/2007 ~t Directional Survey 0 15365 Open 6/5/2007 ^'f2pt Directional Survey 0 15365 Open 6/5/2007 Different Format ' og Cement Evaluation 5 Col 1 9734 15150 Case 6/20/2007 SCMT Welltrac Tractor ~ Conveyence 31-May-2007 , ~ ~ C Lis 15783 Sonic 4586 10329 Open 12/21/2007 LIS Veri, USIT, CCL, GR ~ w/PDS and Tif graphics og Induction/Resistivity 25 Blu 4792 15365 Open 1/22/2008 MD Vision Resisitivity 30- Apr-2007 ~g Induction/Resistivity 25 Blu 4792 15365 Open 1/22/2008 TVD Vision Resisitivity 30- Apr-2007 C Lis ~ 15898 "Induction/Resistivity 4656 15372 Open 1/22!2008 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070200 Well Name/No. PRUDHOE BAY UNIT 03-36A Operator BP EXPLORATION (ALASI4y INC MD 15365 TVD 9043 Completion Date 5/6/2007 Completion Status WAGIN Current Status WAGIN Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ,_\ v Chips Received? \Y / Nv/ Analysis V7N Received? Daily History Received? ~" Formation Tops ~ N API No. 50-029-22340-01-00 UIC Y Comments: -------------- Compliance Reviewed By: __.__-_ Date: ~__ _ ~, i .~ ~~CE~~ ~d~ /* ~~'~~ ~ STATE OF ALASKA ~ o?-~~~~ ,~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION FEB Y , REPORT OF SUNDRY WELL OPERATIOI~ISka ®,rR ~~_ r; 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Othe~ ~, ,~; , Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory 207-0200 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service - 6. API Number: Anchorage, AK 99519-6612 50-029-22340-01-00- 7, KB Elevation (ft): 9. Well Name and Number: 55.67 KB _ PBU 03-36A- 8. Property Designation: 10. Field/Pool(s): ADLO-028332 _ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 15365 ~ feet Plugs (measured) ne ~,~`~Q`L ~ 1(D~ true vertical 9043.12- feet Junk (measured) None ' ~'I i:A~ Effective Depth measured 15274 ~ feet aC a v true vertical 9043.39 - feet Casing Length Size MD TVD Burst Collapse Conductor 111' 20" 91.5# H-40 31' - 111' 31' - 111' 1490 470 Surface 3977' 13-3/8" 68# NT80 30' - 3977' 30' - 3732' 5020 2260 Production 4756' 9-518" 47# NT80S 32' - 4756' 32' - 4230' 6870 4760 Liner 5989' 7" 26# L-80 4599' - 10588' 4132' - 8662' 7240 5410 Liner 4947' 4-1 /2" 12.6# L-80 10416' - 15363' 8548' - 9043' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE -10435' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 10379' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 13998 1649 Subsequent to operation: 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory r Development Service - Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas ~ WAG ~- GINJ fiP WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl , ~? Title Data Management Engineer J~ r' Signature CJ /:° ~ _-~,.- Phone 564-4944 Date 2/18/2009 Form 10-404 Revi~ed 04/2006 ` ~` ~ ~ ~'~ ~"E r ~ ~- ~ ~ v-' f'la~ .Submit Original Only 03-36A 207-020 PERF ATTACHMENT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-36A 5/4/07 PER 15,010. 15,110. 9,047. 9,045.36 03-36A 2/8/09 APF 14,490. 14,510. 9,045.95 9,046. 03-36A 2/8/09 BPS /' 14,650. ~/' 15,110. 9,046.22 9,045.36 03-36A 2/12/09 APF 14,460. /' 14,470. 9,045.9 9,045.92 03-36A 2/12/09 APF 14,470. 14,490. 9,045.92 9,045.95 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n w ~: 03-36A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/7/2009 GTU#6 1.75" CT Job scope: Drift, Set CIBP and perf. «<InterAct is Publishing»>_ MIRU ""*" Continue on WSR on 2/7/09 **"* ~2/7/2009~ F/P F/L of well 03-36 for CTU from manifold Bldg Pumped 107 bbls '60/40 meth water for F/P. F/L PSI=1500 DSO notified upon departure of manifold valves normaled up and tag hung on WV at well. 1 2/8/2009 CTU#6 1.75" CT Job scope: Drift, Set CIBP and perf. «<InterAct is Publishing»> ***Continue from WSR on 2/7/09"*" RIH w/ 3.70 CIBP Drift. Stopped at 14750 CTM. POOH. RIH w/ 4.5"CIBP. Set CIBP (c7 14650' CTM. Test CIBP to 3000 psi GOOD TEST. RIH with two 2906 3 PJO guns 6 spf shoot from 14510' to 14490'. POOH. Go on weather standby. -37 and temp is dropping. 2/11/2009'CTU#6 1.75"CT Job scope.: Set CIBP and perforate. «<InterAct is Publishing»>. End weather standby. Prepare to pickup perf guns _ ~_w~__ __.~ _.~~ ._._~. 2/12/2009~CTU#6 1.75"CT Job scope.: Set CIBP and perforate. «<InterAct is Publishing»>. Continue from WSR on 2/11/09. Failed LPT test. 3 Change-out packoffs. RIH w /two 10'.2906 PJO guns and perforate from 14470' top shot to 14490 bottom shot. All shots fired and recovered 'aluminum ball. POOH. RIH w /two 5' 2906 PJO guns and perforate from 14460' top shot to 14470 bottom shot. All shots fired and recovered 1/2" aluminum ball. POOH. Establish Injection rate. Rate was 1.8 bpm at 1940#'s. Freeze protect well with 38bb1's of 60/40 Methanol. '"""*Continue on WSR on 2/13/09. w_~w_. _____~._._~ ~ ~ ~ _~__.__.~ ~. ~ ,.___,__. 2/13/2009 **"WELL S/I ON ARRIVAL*"* (post ad-pert) ~ SET 4.5 MCX W ITH 4 EA. 1 /8 "AND 4 EA. 3/16" EQ. PORTS W ITH 1.30 BEAN. SER. # M56B.AT 2,233' SLM (2254' MD). RAN 4.5 CHECK SET TO 2,235' SLM. (sheared ) "*'`WELL LEFT S/I*** DSO NOTIFIED OF VALVE POSITIONS. __~_. ._ w _ _ __ ~ _ __ 2/13/2009~CTU#6 1.75"CT Job scope.: Set CIBP and perforate.. Continue from WSR on 2/12/09. RDMO """Job Complete*"" FLUIDS PUMPED BBLS 529 60/40 METH 283 1 % KCL 812 Total 12/28/07 ~ch[~mberg~r Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII _Inh it NO. 4542 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Orion 1 nn flncn Min.. nM,, of n_i__ Z-15 11968824 PROD PROFILE 12/17/07 1 L1-02 11982424 PROD PROFILE 12/12/07 1 GNI-04 N/A DIGITAL SHEAR SONIC TOOL Qom-- 11108/07 1 N-27 11962771 SCMT ~ - ~ 11/28/07 1 A-12 11975740 USIT U- ~ ~ 12/03107 1 03-36A 40015115 OH MWD/LWD EDIT ~ ~-- (~ ('~" ~j' 04130/07 2 1 V-210 11963075 MEMORY INJECTION PROFILE 12118/07 1 • ---•-~~ ~~••••~+•-~-~-~~+~ ~~~-~+~-~~ ~ a,., Vw1~u~V /91~4J nGl Vn1911\V VI\G VVr"i CANfI I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. -- Anchorage, Alaska 99508 " ` Date Delivered: n ~ F~ P~,d ~~ ~ _ ~~ Alaska Data & Consulting Services 2525 Gambeli Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 12/19/07 ~~,~f'~m~e~~~~' N0. 4525 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne Wrall Inh $ 1 nn nn~r.infinn n~fn Qi r..t... rn 15-39A 11661174 MCNL '3 ~'" 09/24/07 1 1 14-32 11676961 RST 09/14/07 1 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOGS'} t y 10/06107 1 03-36A 11745217 CH EDIT PDC GR (USIT) ~ ( U1'C- 05/03/07 1 15-30A 11767139 MCNL - / 09/05/07 2 1 18-12B 11216204 MCNL ~ - 07/04/06 2 1 E-21 B 11133205 MCNL -/G~ $ 12/07/05 2 1 P2-56 11686777 RST - ~ 08/08/07 2 1 H-33 11686792 RST CjL _ ~ 10/20/07 2 1 06-16 11686797 RST - _ < 11/15/07 2 1 L2-16 11626482 RST 05/10/07 2 1 D-226 11661167 MCNL ~ - i5 08/26/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USIT- ~~ ~ d8 ~g ~ 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) ~f --~3 ~`~ 4 j?, 01/15107 2 1 C-22A 40013486 OH MWD/LWD EDIT (~ -p ? ~-~/ 05110/06 2 1 E-15C 40013555 OH MWD/LWD EDIT O - (o (~ ~ °¢~~ 06/03/06 2 1 r~.cra~ /1li nlYlJ VVLCUVC KCI.CIr ~ 6T JWIV IIVV AIVU KtiUKIVIIVV VIVt I.VYI' tAlirt I V: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 " ' . 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth Date Delivered: "' ~ Received by: MEMORANDUM • To: Jim Regg ~~ , 7{17~C'~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Src: Inspector Well Name: PRUDHOE BAY UNIT 03-36A API Well Number: 50-029-22340-01-00 Inspector Name: Bob Noble Insp Num: mitRCN070625075312 Permit Number: 207-020-0 Inspection Date 6/24/2007 Rel Insp Num: MITOP000001786 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ Well ~ 03-36A ,,Type Inj. ~ W ~ TVD 8522 ~ IA II30 ~~~ 2500 ~ 2470 2460 ~ P.T.D X070200 ~TypeTest I SPT ~ Test psi I ~~ zsoo I OA Iso j z6o ~ -T 26o zbo~ ~~ p~ Interval Initial Test Pass '~ Tubing !, Iaoo 'i Iaoo Iaoo j Iaoo j - - - - Notes: ~~~ d~ -4e5t- ~~SSi~~ ~ i 3C {~s e State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 17, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-36A PRUDHOE BAY UNIT 03-36A Tuesday, July 17, 2007 Page 1 of 1 ~~~~~~ r-, ~ STATE OF ALASKA ,1UN ~ ~ 1~4 tALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil ~ Gas f;i~n~EL~iCOMPLETION OR RECOMPLETION REPORT AND LOG ~~41SS.~f i]~'v G~~~;~.~ Revised 06/27/07: Put on Injection 1a. Welt Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5/6/2007 ~ 12. Permit to Drill Number 207-020 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/14/2007 ~ 13. API Number 50-029-22340-01-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/30/2007, 14. Well Name and Number: PBU 03-36A FSL, 4381 FEL, SEC. 11, T10N, R15E, UM 906 Top of Productive Horizon: 564' FNL, 137' FEL, SEC. 15, T10N, R15E, UM 8. KB (ft above MSL): 55.67' Ground (ft MSL): 27' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1561' FNL, 3139' FEL, SEC. 14, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 15274 9043 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 714172 y- 5936972 Zone- ASP4 10. Total Depth (MD+TVD) 15365 ~ 9043 16. Property Designation: ADL 028332 - TPI: x- 713180 y- 5935473 Zone- ASP4 Total Depth: x- 715487 y- 5934542 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No ubmit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR / GR /RES / PWD /Vibration, MWD DIR / GR /RES ! ABI, USIT 22. CASING, LINER AND CEMENTING RECORD CASING -SETTING DEPTH MD' SETTING DEPTk TVD" HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM' SIZE CEMENTING RECORD PULLED 2 91.5# H-40 31' 111' 31' 111' 3 281 cu ft Ar icset 13-3/8" 68# NT80 31' 3977' 31' 3732' 1 1517 sx CS III, 400 sx'G', 165 sx CS II 9-5l8" 47# NT80S 32' 47 32' 4230' 12-1/4" 1210 sx Class'G' 7" 2 L- 0 4599' 10588' 4132' 8 8-1/2" 579 sx Li rete 16 sx I 'G' 4-1/2" 12.6# L-80 10416' 15363' 8548' 9043' 6-1/8" 605 sx Class'G' 23. Open to production or inject ion? ®Yes ^ No 24, TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gurr Diameter 6 spf 4-1/2", 12.6#, L-80 10435' 10379' , MD TVD MD TVD 15010' - 15110' 9047 - 9045' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 2200' Freeze Protect w/ 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 19, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. CaSing PfeSS: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~'~~ ..~... ~, ,1111` (! 6 2~~7 Form 10-407 Revised 02/2007 ~ ~(~ITI~UED ON REVERSE SIDE ~~ ~~~~~'~~ G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 5751' 4961' None Top HRZ 10289 8463' Base HRZ 10569' 8649' LCU 10605' 8673' Shublik C 10650' 8703' Sadlerochit 10703' 8739' 45N 10726' 8755' 45P 10729' 8757' 44N 10757' 8776' 44P 10767' 8783' 43N 10812' 8811' 43P 10818' 8815' 42N 10871' 8846' 42P 10906' 8866' 31 N 10954' 8890' 31 P (Top CGL) 10968' 8897' 27P (Base CGL) 11144' 8965' 26P 11900' 9018' Formation at Total Depth (Name): 26P 11900' 9018' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~~~ ~"7~~ Signed Terrie Hubble Title Technical Assistant Date PBU 03-36A 207-020 Prepared By NameAVumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Shane Gagliardi, 564-5251 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITea~ 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITenn 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert~admin.siate.ak.us; Bob_ rrrNn_stale~t.us; .8m Regg~nin.slateak.us; Tom Maunder~admin.state.ak.us OPERATOR: BP E~bratiort (Alaska), Inc. FIELD /UNIT !PAD: Prudhoe Bay / GPB ! Drr~ Site 3 DATE: 06/247 OPERATOR REP: Andrea Hughes AOGCC REP: Bob Nobk; Packer Depth Pretest Initial 15 Min. ~ Min. Well 03-36A Type Inj. W TVD 8,523' Tubing 1400 1400 1400 1400 Interval 1 P.T.D. 2070200 Type test P Test 2131 1130 2500 2470 2460 P!F P Notes: MIT-IA post initial injedron. OVA 180 260 260 260 Well T Inj. TVD T Interval P.T.D. T test Test psi P/F Notes: OA Well T Inj. W TVD T Interval P.T.D. Type test P Test psi Casing P/F Notes: OA Well Type Inj. W TVD Tubing Interval P.T.D. Type test P Test psi Caseg P!F Notes: OA Well Type Inj. TVD Tu " Interval P.T.D. Type test Tess psi Cas"sg P!F Notes: QA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus 9 P = Sland~d Ressure Test R = Ire6ernal Radi~tiue Tracer Survey A =Temperature Arwmaly Survey D = D1 Temper~ve Ted INTERVAL Codes I =Initial Test 4 =Four year cycle V =Required by Variance T =Test during Workover t3 =Other (describe in notes) ~~ c, (as-off MIT Report Form BFL 9/1/05 biT P82103-~A OB-24-07ads 06/15/07 I ~, ..1 Schfumberger NO. 4304 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite a0o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~~+\\ 333 West 7th Ave, SuitE~ 100 Q~" " ~~ V Anchorage, AK 99501 Field: Prudhoe Bay Well Jnh d! Lnn I1acr_rinfinn rhfn RI Rnlnr CA P1-16 11637331 WARMBACKS 8 SBHPS 05/04107 1 P1-14 11637332 WARMBACKS &SBHPS 05!05107 1 01-05 11626486 USIT (CEMENT) 05/13/07 1 01-05 11626486 USIT (CORROSION) 05/13/07 1 MPH-14 11638633 INCLINOMETER-DIRECTION LOG 05113!07 1 MPS-01A 1159454 MDT 05/28107 1 11-18 11626097 USIT 05/26/07 1 09-15A 11629015 SCMT 06/01107 1 12-12A 11695061 CEMENT IMAGE & BOND LOG 05/28107 1 03-36A 11629014 SCMT 05/31107 1 S-401 11626492 SCMT 06/11/07 1 rLCHJC Hl.nrvvvYLCUVC RtlatYl 1ST JIliIVllVli AMU KtIUKNI1Vl9 VNt GUPY EACH TV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ _ 900 E. Benson Blvd. ~ , ~ -- i Anchorage, Alaska 99508 "~ t~ ~~ ~oJ t~--~ '~ Date Delivered _ n,i! ~. J tE , s ~ , ~:,t~11"!t'fBlc~"c?3~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 /, ATTN: Beth Received by: ~„_~~°~ L '•! C:i.4NICAI, T?~TEGRITY RPORT ~~~'~r~~ :.~c ~.~~~:..~. ~1~-~r1 ~~~LL NUMEER ~5 ~3-~~ A n~LL DAT~_ TD : \'S~,~S .?~. ~11;~i3 TVD ; BTD : ~~1'~( ?ID ~~y3 TVD ~~~~,: '1`~ shoe: 1~S£~~S ~ ~~~- TV~;_tv~~ ~S '-~ ~-il~- T~~ ...,er : ~~(~'~ Shoe: t~~~~ 50`-13 T`T'J ; .CP : i0y1~ ?•~ ~`I~'S .';D _uo'~v ~~~~ Packer i~3~~ ~ TVD; Set at ~~~~35 ole S~ce ~`~~~.. and ~r~~ Perks 1~O`~ to 1S~11~ ~b~'Z ~i0 4 5 ~C"r'~?~ TC~.T. IVTEGR! T`~T - !~ A.RT # 1 r_nruLus Press Test• _~ 15 min ~0 min Comments : ~-J~c,~~. -~CS~~tc~ ~a ~'lSC7® r~s ~ ~ ~ ~ ~c~ ~~V?S~ ~ ` r '~'CHP?~ICry Il`ITEGRTTY - PART # 2 ~~ Cement Voles :- Amt. miner ~~~~h~S ; L~ t~C~hh`~ ; DV ~l.) ~ Cmt -rol to cover oers c-ct~+-~.~-L~c~~-J`~.~~ ~r•~~ T:-: e o r e t i c a 1 T 0 C Lc~M~. r~-~' ~~c-~`~`t~. T'C~ '~C~~ `~•~-~ `~h~ V~ °~r'fl ~~ 3 ro Cement Bond Log (Yes or No) `lC~ In AOGCC Eile C9L Evaluation, gone aoove perfs Sc~~\~t~~ b0~`c~c c~3\c)E r- ~~ -~ ~ Production Log: Type Evaluation a COI~{LLJSIONS : Part 11 ~ar~ 1L ~ ~~7 `~~ ~. i S, - - - - - STATE OF ALASKA 6 ALASKA~IL AND GAS CONSERVATION COM~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or AbaA~,f, 5/6/2007 ..~~~~ 12. Permit to Drill Number 207-020 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/14/2007 ~ 13. API Number 50-029-22340-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/30/2007' 14. Well Name and Number: PBU 03-36A ' FSL, 4381 906 FEL, SEC. 11, T10N, R15E, UM Top of Productive Horizon: 564' FNL, 137' FEL, SEC. 15, T10N, R15E, UM 8. KB (ft above MSL): 55.67' Ground (ft MSL): 27' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1561' FNL, 3139' FEL, SEC. 14, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 15274 9043 P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 714172 y- 5936972 Zone- ASP4 10. Total Depth (MD+TVD) 15365 = 9043 ~ 16. Property Designation: ADL 028332 TPI: x- 713180 y- 5935473 Zone- ASP4 Total Depth: x- 715487 y- 5934542 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR / GR /RES ! PWD /Vibration, MWD DIR / GR /RES / ABI, USIT ~i1/jyDOiJ C~~7.S6i~1.0 ~a;.r'~,~$''>yd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD 1-10LE AMOUNT Wr. PER FL GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 31' 111' 31' 111' 30" 281 cu ft Arcticset 13-3/8" 68# NT80 31' 3977' 31' 3732' 16" 1517 sx CS III, 400 sx'G', 165 sx CS II 9-5/8" 47# NT80S 32' 47 32' 4230' 12-1/4" 1210 sx Class 'G' 7" 26# L-80 4599' 10588' 4132' 8662' 8-1/2" 57 sx Li rete 166 sx Class 'G' 4-1/2" 12.6# L-80 10416' 15363' 8548' 9043' 6-1/8" 605 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING R~coRD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10435' 10379' MD TVD MD ND 15010' - 15110' 9047 - 9045' 25. AeID, FwaCTURE, ICEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KINO OF MATERIAL USED 2200' Freeze Protect w/ 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE.• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results (per5520 AAC!_2y5~ 0.071. ~ .1lVl~'f ~' L { \; iii € None S BFI JUL 16 20D7 tF ~ "row - Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE l~ECEIVEt]~ JUN 0 5 2007 .:Alaska Cil & Gas Cons. Commissip ' wen class: nc Drags ~, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 5751' 4961' None Top HRZ 10289 8463' Base HRZ 10569' 8649' LCU 10605' 8673' Shublik C 10650' 8703' Sadlerochit 10703' 8739' 45N 10726' 8755' 45P 10729' 8757' 44N 10757' 8776' 44P 10767' 8783' 43N 10812' 8811' 43P 10818' 8815' 42N 10871' 8846' 42P 10906' 8866' 31 N 10954' 8890' 31 P (Top CGL) 10968' 8897' 27P (Base CGL) 11144' 8965' 26 P 11900' 9018' Formation at Total Depth (Name): 26P 11900' 9018' 30. List of Attachments: Summary of Daily Drilling Reports, Welt Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Si d ~ ~ ~ ~S/ ~ ~ ~ gne (,r` I f Title Technical Assistant Date ! ~ Terrie Hubble PBU 03-36A 207-020 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Shane Gagliardi, 564-5251 Permit No. / A royal 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: 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). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 03-36 Common Name: 03-36 - -_ Test Date Test Type Test Depth (TMD) Test Depth (TVD) ~ AMW Surface Pressure Leak Off Pressure (BHP) ; EMW - __ 4/15/2007 FIT 4,783.0 (ft) .4,240.0 (ft) 9.50 (ppg) 325 (psi) 2,417 (psi) 10.98 (ppg) 4/20/2007 FIT (ft) (ft) (ppg) (psi) (psi) 10.98 (ppg) 4/23/2007 FIT 10,588.0 (ft) 8,664.0 (ft) 8.40 (ppg) 722 (psi) 4,503 (psi) 10.00 (ppg) • ~~ Printed: 5/7/2007 11:16:44 AM ~ ~ BP EXPLORATION Page 1 of 16 ~ Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date i From - To Hours Task Code NPT Spud Date: 4/3/1993 Start: 4/5/2007 End: Rig Release: 5/7/2007 Rig Number: Phase Description of Operations 4/8/2007 ~ 00:00 - 09:00 9.001 MOB P 09:00 - 00:00 ~ 15.00 MOB P 4/9/2007 00:00 - 09:30 9.50 MOB P 09:30 - 11:00 1.50 RIGU P 11:00 - 12:00 1.00 RIGU P 12:00 - 14:00 2.00 RIGU P 14:00 - 20:30 6.50 RIGU P 20:30 - 23:30 3.00 RIGU P 23:30 - 00:00 0.50 RIGU P 4/10/2007 00:00 - 02:00 2.00 WHSUR~ P 02:00 - 04:00 2.00 BOPSU P 04:00 - 07:00 3.00 BOPSU P 07:00 - 12:30 I 5.501 BOPSUp P 13:00 - 15:00 2.00 BOPSU~P 15:00 - 19:30 I 4.501 PULL I P 19:30 - 21:45 2.25 PULL P 21:45 - 23:00 1.25 PULL P 23:00 - 00:00 I 1.001 PULL I P 14/11/2007 100:00 - 02:00 I 2.001 PULL I P 02:00 - 07:00 I 5.001 PULL I P PRE Release rig from P2-15A @ 00:00. Move Iliamna Camp, truck shop, and pit module from P2-15A to DS 03-36. Back substructure off well, lay down derrick. Prepare substructure to move, and wait on security to complete escorting Camp to 03-36. PRE Move rig substructure from P2-15A to 03-36. As of 00:00, substructure is on spine road near DS-02. PRE Move rig onto DS-03 well # 36. Spot sub over well. PRE Inspect derrick and prepare ro raise the derrick. Raise the derrick. PRE Spot pits on sub, prepare rig floor to bridle down. PRE Pre-spud meeting w/ BP WSL, NAD TP, Mud man & rig crew. Rig down bridle lines, rig up Top drive, lines and tongs. PRE Change draworks brake bands. Accept rig 20:30 hrs. PRE DSM pull BPV & install TWC w/lubricator. Test TWC f/ above to 1000 psi - OK. PRE FMC function LDS and bleed void on adaptor. Hold pre-spud w/ morning crew, BP WSLs, NAD TP, night mud engineer. DECOMP Nipple down tree. DECOMP Nipple up BOPE. DECOMP Change out lower pipe rams to 4.5" - 7" variable pipe rams. Adjust bell nipple length. DECOMP Rig up and test BOPs to 250 psi low pressure, 4000 psi high pressure w/ 4" and 7" test joints. Test 5" TIW and dart valves 250 psi low pressure, 4000 psi high pressure. Perform accumulator test. Test annular preventer to 3500 psi. Test witnessed by BP WSL Duncan Ferguson & Nabors tool pusher Larry W urdeman. Jeff Jones waived AOGCC presence for test. DECOMP RD test equipment and BD choke and kill lines. DECOMP RU Drill Site Maintenance and pull two way check valve w/lubricator. RD DSM. DECOMP PJSM. Rig up E-line 5 1/2" shooting nipple and pack-off with pump in sub and jet cutting equipment. DECOMP RIH w/jet cutter. DECOMP Log and locate GLM at 11601'. Position jet cutter and cut 5-1/2" tubing at 11570'. Saw good line movement when tool was actuated. Well bore'U' tubed when tubing cut. 105 psi on tubing side. Wireline shooting nipple pack-off began leaking. Annulus on vacuum. Pull E-line out of hole. Packoff on shooting nipple continued leaking while pulling wireline out of hole. 1 bbl diesel leaked down outside of shooting nipple. Disposed of diesel from leak down tlowline and out to cuttings box. DECOMP Rig down Schlumberger E-line and pressure control equipment. DECOMP Reverse circulate diesel out of tubing into Tiger tank until clean. 126 gpm, 140 psi. total 96 bbl. DECOMP Circulate methanol and seawater out of 5-1/2" x 9-5/8" annulus w/1 bbl of Safe Surf'O' in 40 bbls 9.8 ppg brine ahead of Printed: 5!7/2007 11:78:48 AM • • BP EXPLORATION Page 2 of 16 ~ Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date i From - To i Hours ~ Task~Code NPT Phase Description of Operations 4/11/2007 02:00 - 07:00 5.00 PULL P 07:00 - 07:30 0.50 PULL P 07:30 - 08:00 0.50 PULL P 08:00 - 08:30 0.50 PULL P 08:30 - 12:00 3.50 PULL P 12:00 - 12:30 0.50 PULL P 12:30 - 13:45 1.25 PULL P 13:45 - 23:30 9.75 PULL P 23:30 - 00:00 0.50 PULL P 4/12/2007 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:00 1.00 CLEAN P 03:00 - 08:00 5.00 CLEAN P 08:00 - 10:30 2.50 CLEAN P 10:30 - 13:00 2.50 EVAL P 13:00 - 18:30 5.50 EVAL P 18:30 - 19:30 1.00 EVAL P 19:30 - 20:30 1.00 DHB P 20:30 - 22:30 2.00 DHB P 22:30 - 23:00 0.50 DHB P 23:00 - 00:00 1.00 EVAL P 4/13/2007 00:00 - 01:00 1.00 EVAL P 01:00 - 03:30 2.50 EVAL P 03:30 - 06:30 I 3.00 I EVAL I P DECOMP displacement taking returns into Tiger tank until clean. 126 gpm, 490 psi. 775 bbl DECOMP Monitor well. Well on slight vacuum. Taking fluid at 9 bbls/hr. Spot and RU Camco spooling unit on rig floor. FMC backout LDS and makeup jt. in tubing hanger thread to pull tubing. DECOMP Back out lock down screws and pull tubing hanger to floor w/210K, SO 185K. DECOMP LD tbg. hanger. Pump dry job. RD/BD lines. DECOMP POH laying down 7" tbg. f/11570' U9356'. PU 160K, SO 135K. LD SSSV. DECOMP RD control line spooler and clear floor. DECOMP LD total 79 jts 7" tbg. (/9356' to 8290'. DECOMP LD 7" x 5-1/2" XO, 204 jts 5-1/2" tbg, 9 GLMs, and 9.13' of 5-1/2" tbg stub f/8290' to surface. Retrieved 55 SS bands. 5-1/2" tubing had no pits or obvious corrosion damage. DECOMP RD tbg handling equipment. DECOMP RU to PU drill pipe and RIH w/9-5/8" scraper. Install wear bushing. Function test rams. DECOMP PU cleanout BHA #1 w/8.5" milltooth used bit, two boot baskets, bit sub and RIH. DECOMP PU 5" drill pipe f/ pipeshed and RIH to 5286' w/no indication of any obstruction. DECOMP POH (/5286' to surface and LD scraper and boot baskets. Boot baskets empty. DECOMP PJSM w/WSL, toolpusher, Schlumberger, all hands on rig up and running of USIT logs. RU E-line to run USIT. DECOMP RIH. Run USIT log in 9-5/8" casing f/5000' to surface. DECOMP RD USIT log. Found cement top 3850' on USIT. No cement found above 3850'. DECOMP PJSM and RU E-line to run 9-5/8" EZSV CIBP. DECOMP Correlate GR and set top of EZSV CIBP at 4777' above collar at 4783'. CCL located 10' above top of plug at 4767' when EZSV set. DECOMP POH w/E-line setting tool. RD wireline. DECOMP RU and attempt 4000 psi test on 9-5/8". Use rig pumps to 3000 psi. Switch to test pump and bring pressure to 3650 psi. At 3650 psi pressure bleeding off. Bleed pressure to 0 psi. Check surface equipment. Attempt to test 2nd time with same result. Could not get test pump to take pressure above 3650 psi. Mobilize Halliburton RTTS to hunt for possible hole in casing. DECOMP Mobilize RTTS. PJSM. RU to RIH w/RTTS. DECOMP RIH with RTTS and set at 547'. Test 9-5/8" casing below RTTS to bridge plug at 4777' to 4000 psi. Dropped 50 psi in 35 min. DECOMP RU and test 9-5/8" casing above RTTS at 547' to surface to 4000 psi. Bled off 200 psi in 20 min on 1st attempt. Pressure back up to 4000 psi and hold for 30 minutes. Pressure dropped off 25 psi in 30 minutes. Pull RTTS up and set at 517'. Test 9 5/8" casing from below RTTS at 517' to bridge plug at 4777' to 4000 psi for 30 minutes. Pressure dropped off 50 psi on 30 minutes. Printed: 5/7/2007 11:16:48 AM ~ ~ BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date From - To i Hours ~ Task ~ Code NPT Phase Description of Operations - -_ - ~ - . _L- _ _ _. -- -- _ _ - _ --- - __ 4/13/2007 06:30 - 07:30 1.00 EVAL P DECOMP PU to 517' and retest below RTTS to 4000 psi/30 min. Test above RTTS to 4000' psU30 min. 07:30 - 08:15 0.75 EVAL P DECOMP POH and LD RTTS. 08:15 - 10:15 2.00 STWHIP P WEXIT PJSM. PU window milling BHA #2 w/ 9-5/8" Baker Gen II Whipstock/starter mill/window mill assembly, MWD, bumper sub, XO, 9 6.25" drill collars, XOs, 17 jts 5" HWDP. OAL of BHA = 886.45'. Orient MWD to whipstock face at surface. 10:15 - 12:00 1.75 STWHIP P WEXIT PU bumper sub and nine 6.5" drill collars. 12:00 - 15:00 3.00 STWHIP P WEXIT PU 17jts. 5" HWDP + 1st 5" drill pipe and RIH to 4747'. u•nn _ u•a~ n 7~, . TwHIP P U/EXIT (lricni whinetnek to F7 ricn Inff Tan 7. \/ a} d77T . cc 03.3 "' anchor set w/20K down and shear brass bolt w/35K down. ~„ 15:45 - 17:00 1.25 STWHIP P WEXIT Pump 50 bbl. HI Vis spacer and displace brine to 9.5 ppg LSND milling fluid 525 gpm, 890 psi. 17:00 - 00:00 7.00 STWHIP P WEXIT Mill window f4756' to 4777' 120 rpm, 335 gpm, 520 psi, tq 6K, 110 rpm, WOB 5-6K. Recovered 165# metal at 23:59. Pumped 50 bbl Hi Vis Super sweep at 4772'. 4/14/2007 00:00 - 02:30 2.50 STWHIP P WEXIT Mill window/drill OH w/full gage window mill to 4785' and starter mill to 4792'. 02:30 - 03:00 0.50 STWHIP P WEXIT Work mills through window until slick. CBU w/25 bbl Hi Vis Super Sweep 550 gpm, 1120 psi. Recover 300# metal total for job. Saw cement particles in good quantity across shakers. 03:00 - 04:00 1.00 STWHIP P WEXIT Attempt to perform FIT to 12.0 ppg EMW w/9:5 ppg LSND mud at 4477' MD/4243' TVD w/550 psi. Shoe broke at 325 psi for 11.0 ppg EMW. 04:00 - 05:00 1.00 STWHIP P WEXIT RD test equipment. Service top drive and draw works. Pump dry job. 05:00 - 07:00 2.00 STWHIP P WEXIT POH to HWDP w/milling BHA #2. 07:00 - 08:00 1.00 STWHIP P WEXIT LD nine 6-1/2" drill collars. LD window mills. Upper window mill gage and in good shape. 08:00 - 09:00 1.00 STWHIP P WEXIT Pull wear bushing and jet stack. Reinstall wear bushing. 09:00 - 11:30 2.50 DRILL P INTi MU BHA #3 w/Hughes 8-1/2" HCR503AZ (ser # 7114234), 1.50 deg XP motor, float, ARC LW D, MWD, NM stab, w/2 NM spiral drill collars, NM stab, NM spiral drill collar, saver sub, hyd. jars, ball catcher sub, circ valve,l7 jnts 5" HWDP w/5" drill pipe to surface. (Note: 1st set of jars leaking oil, picked up new set of jars.) 11:30 - 12:00 0.50 DRILL P INT1 Shallow test MWD equipment. 12:00 - 16:00 4.00 DRILL P INT1 PU 5" drill pipe f/pipe-shed and RIH to 4693'. 16:00 - 16:30 0.50 DRILL P INT1 Orient 30 deg. left, establish ECD baseline 10.23 ppg. RIH through window (TOW 4756', BOW 4773') w/4K SO at 4770' and RIH below window to 4792'. 16:30 - 00:00 7.50 DRILL P INTt Drill/slide f/4792' to 5540'. 145K PU, 115K SO, 118 ROT, 80 rpm, 513 gpm, 1650 psi on, 1497 psi off, 6K tq on, 6K tq off. ECDs = 10.32 calc/10.68 actual. ADT f/24 hrs = 4.13 hrs. AST = 1.78 hrs. ART =2.32 hrs. Progress = 748'. 4/15/2007 00:00 - 04:00 4.00 DRILL P INT1 Drill/slide (/5540" to 5917'. 153K PU, 123K SO, 133 ROT, 80 rpm, 508 gpm, 1690 psi on, 1495 psi off, 8K tq on, 7K tq off. BHCT 89.6F. ECDs = 10.32 calc/10.51 actual. 04:00 - 05:00 1.00 DRILL P INT1 CBU x 2. 502 gpm, 1462 psi. 80 rpm, reciprocate pipe 20'. 05:00 - 06:30 1.50 DRILL P INT1 MW 9.5 ppg. Pump OOH f/5917' to window at 4756' w/1.50 deg BHA #3 for BSS. Printed: 5/7/2007 71:16:48 AM ~ ~ BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 3-36 3-36 REENTE NABOBS NABOBS Hours R+COMPLETE ALASKA DRILLING 7ES Task ~ Code ~ NPT Start I Rig Rig Phase Spud Date: 4/3/1993 : 4/5/2007 End: Release: 5/7/2007 Number: Description of Operations 4/15/2007 06:30 - 07:00 0.50 DRILL P INTi Monitor well. Pump dry job. MW =9.5 ppg. 07:00 - 08:30 1.50 DRILL P INTi PJSM. POH to HWDP at 732'. 08:30 - 10:30 2.00 DRILL P INT1 Stand back HWDP, spiral collars, LD CCV, LD BHA. Bit damaged. 10:30 - 13:00 2.50 DRILL P INT1 PJSM. PU Rotary Steerable System BHA #4 w/2nd 8-1/2" Hughes HCR503ZX (ser #7114235), PowerDrvie BSS, float, ARC LW D, MWD NM Stabilizer, 2 NM Spiral drill collars, NM stabilizer, NM spiral drill collar, ball catcher, circulating valve (CCV), saver sub, hydraulic jars, 17 jnts 5" HWDP. Function test PowerDrive at surface. Shallow test MWD. OAL of BHA = 732'. 13:00 - 15:00 2.00 DRILL P INT1 RIH picking 5" drill pipe singles f/732' to 1060' and PU ghost reamer, PU singles to 1778'. 15:00 - 16:30 1.50 DRILL P INT1 RIH w/5" drill pipe stds to 4510'. 16:30 - 17:30 1.00 DRILL P INT1 Service top drive, connect oil cooler. 17:30 - 18:30 1.00 DRILL P INT1 PJSM. Cut and slip 75' drill line. 18:30 - 19:00 0.50 DRILL P INT1 MADPass f/4540' to 4604' inside casing. 511 gpm, 600 fph. 19:00 - 21:00 2.00 DRILL N RREP INT1 Repair electrical problem w/top drive. Joystick would not activate right hand rotation. 21:00 - 22:30 1.50 DRILL P INT1 Continue MADPass f/4604' to 4800'. 510 gpm, 600 fph. 22:30 - 23:30 1.00 DRILL P INT1 RIH f/4800' U5838'. 23:30 - 00:00 0.50 DRILL P INT1 Circulate and establish 10.58 ppg ECD baseline, 120 rpm, 7K tq, 150K PU, 120K SO, 135K ROT, 556 gpm, 1560 psi. Downlink PowerDrive. Wash to bottom at 5917'. No fill. ECDs = 10.32 calc/10.58 actual. ADT f/24 hrs. = 2.66 hrs. AST = 1.48 hrs. ART = 1/18 hrs. Progress = 37T. 4/16/2007 00:00 - 06:00 6.00 DRILL P INT1 Drill w/BSS f/5917' to 6310'. 170K PU, 133K S0,140 ROT, 80 rpm, 551 gpm, 1625 psi on, 1610 psi off, 10K tq on,8K tq off. ECDs =10.41 calc/10.46 actual. 06:00 - 12:45 6.75 DRILL P INT1 Drill w/BSS f/6310' to 6723'. 190K PU, 140K SO, 155 ROT, 80 rpm, 550 gpm, 1650 psi on, 1645 psi off, 11 K tq on, 10K tq off. ROPs dropped to unacceptable levels. Check w/geos and verified that ROPs were consistently lower through shales and higher through sands which is inconsistent w/performance expectations for current bit. 12:45 - 13:15 0.50 DRILL P INT1 Monitor well. MW = 9.6 ppg. Prepare to POH f/bit. 13:15 - 13:45 0.50 DRILL P INT1 POH f/6723' to 6490' 13:45 - 17:30 3.75 DRILL P INT1 Pump dry job then POH f/6490' to 734'. Note 30K overpull at 5850'. SO and RIH to 5860' then POH no problems. 17:30 - 19:00 1.50 DRILL P INT1 Stand back BHA. LD circulation valve. Bit damaged. C/O bit. 19:00 - 20:30 1.50 DRILL P INTi PJSM. Download MWD, RIH w/ Rotary Steerable System BHA #5 w/3rd bit Hycalog RSX69MA4 (ser #212704), PowerDrvie BSS, float, ARC LW D, MWD NM Stabilizer, 2 NM Spiral drill collars, NM stabilizer, NM spiral drill cotlar, ball catcher, circulating valve (CCV), saver sub, hydraulic jars, 17 jnts 5" HWDP. Function test PowerDrive at surface. Shallow test MWD. OAL of BHA = 737'. 20:30 - 22:15 1.75 DRILL P INT1 RIH f/732' to 4697'. 22:15 - 22:45 0.50 DRILL P INT1 Fill drill pipe above window. BD topdrive. Printed: 5/7/2007 11:16:48 AM • w BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 3-36 3-36 REENTE NABOR NABOR Hours ~ R+COM S ALASK S 7ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 4/3/1993 : 4/5/2007 End: Release: 5/7/2007 Number: Description of Operations 4/16/2007 22:45 - 00:00 1.25 DRILL P INT1 Circulate and condition mud before running into OH. 4/17/2007 00:00 - 03:00 3.00 DRILL N DPRB INT1 Wait on Slickline to set plug and test in X nipple in close approach well DS 3-33. Adjust brakes. Clean rig. Clean pipeshed. Service topdrive. 03:00 - 04:30 1.50 DRILL N DPRB INT1 Wait on pump truck to pressure test wireline plug set by slickline in X nipple of close approach well DS 3-33. Paint, clean rig, perform general maintenance. 04:30 - 06:00 1.50 DRILL P INT1 RIH f/4697' to 6723'. No trouble through window. Wash down last stand. No fill. Notified at 06:00 by Wells Group of good test of plug set in X-nipple on DS3-33. 06:00 - 12:00 6.00 DRILL P INT1 Drill directionally w/PowerDrive RSS f/6723' to 7481'. 205K PU, 148K SO, 163 ROT, 120 rpm, 550 gpm, 1880 psi on, 1870 psi off, 14K tq on, 12K tq off. ECD Calc = 10.30 ppg, ECD Act = 10.42 pP9• 12:00 - 00:00 12.00 DRILL P INT1 Drill directionally w/PowerDrive RSS f7481' to 8660'. 220K PU, 150K SO, 165 ROT, 140 rpm, 601 gpm, 2607 psi on, 2536 psi off, 12K tq on, 10K tq off. ECD Calc = 10.44 ppg, ECD Act = 11.09 ppg. ECD differential climbed f/.02 to .61. Increased rate to 600 gpm, backed down on ROP. 4/18/2007 00:00 - 03:00 3.00 DRILL P INT1 Drill directionally w/PowerDrive RSS f/8660' to 9036'. 240K PU, 155K SO, 168 ROT, 140 rpm, 601 gpm, 2660 psi on, 2640 psi off, 14K tq on, 12K tq off. ECD Calc = 10.44 ppg, ECD Act = 11.22 ppg. Pumped 30 bbls Hi-Vis sweep at 8970'. Brought sweep out of hole and saw 30% increase in cuttings. Shut in #1 pump and drop to 340 gpm w/pump #2. 962 psi. 03:00 - 03:45 0.75 DRILL N RREP INT1 Circulate/reciprocate 90' 300 gpm, 960 psi. Check f/washed valve in #1 pump. 03:45 - 06:00 2.25 DRILL P INT1 Drill directionally f/9036' to 9250'. 248K PU, 155K SO, 173 ROT, 140 rpm, 600 gpm, 2460 psi on, 2420 psi off, 14K tq on, 13K tq off. ECD Calc = 10.44 ppg, ECD Act = 11.18 ppg. 06:00 - 12:00 6.00 DRILL P INT1 Drill directionally f/9250' to 9900'. 270K PU, 158K SO, 183 ROT, 140 rpm, 600 gpm, 2670 psi on, 2640 psi off, 17K tq on, 15K tq off. ECD Calc = 10.47 ppg, ECD Act = 11.05 ppg. Had GR failure w/ARC LWD tool. Continued drilling utilizing PowerDrive GR. 12:00 - 16:15 4.25 DRILL P INT1 Drill directionally f/9900' to 10127'. 275K PU, 160K SO, 183 ROT, 140 rpm, 609 gpm, 2732 psi on, 2605 psi off, 15K tq on, 15K tq off. ECD Calc = 11.2 ppg, ECD Act = 11.52 ppg. Start blending in 580 bbls. 11.1 ppg spike fluid at 9900' to increase MW to 10.3 before HRZ entry. 500 psi pack off occurred during displacement to 10.3 ppg mud. 16:15 - 18:00 1.75 DRILL N DFAL INT1 Monitor well. MW = 10.3 ppg. POH to 9775' and MADPass to 9600' per geos. 250'/hr, 610 gpm, 2695 psi, MADPass confirming PowerDrive GR reliability prior to HRZ entry. 18:00 - 18:30 0.50 DRILL P INT1 RIH to 10127'. 18:30 - 00:00 5.50 DRILL P INT1 Drill directionally f/10127' to 10496'. 280K PU, 160K SO, 180 ROT, 140 rpm, 604 gpm, 2721 psi on, 2605 psi off, 17K tq on, 16K tq off. ECD Calc = 11.2 ppg, ECD Act = 11.71 ppg. ADT f/24 hrs = 13.42. Progress = 1836'. 4/19/2007 00:00 - 02:00 2.00 DRILL P INT1 Drill directionally/time drill 50' per hr. f/10496' to 10590'. 285K PU, 165K SO, 183 ROT, 140 rpm, 600 gpm, 2640 psi on, 2580 psi off, 18K tq on, 17K tq off. ECD Calc = 11.22 ppg, ECD Act Printed: 5!7/2007 11:16:48 AM • • BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 0 3-36 Common W ell Name: 0 3-36 Spud Date: 4/3/1993 Event Nam e: REENTE R+COM PLET E Start : 4/5/2007 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 5/7/2007 Rig Name: NABOB S 7ES Rig Number: Date From - To ours Task ~ Code NPT Phase ~ Description of Operations 4/19/2007 00:00 - 02:00 2.00 DRILL P INT1 = 11.35 ppg. 02:00 - 03:00 1.00 DRILL P INT1 CBU f/samples per geos and find LCU silt. TD 8-1/2" intermediate section at 10590' MD/8663' TVD. 03:00 - 05:00 2.00 DRILL P INT1 Monitor well. MW 10.3 ppg. POH f/shortrip backreaming Ugnu w/ghostreamer f/7332' to 8329'. 25K over pull at 9280', 9182',9142', 9083', 8989', 8904', and 8706'. Work pipe and wipe out tight hole. 05:00 - 08:00 3.00 DRILL P INT1 POH backreaming f/8329' to 6771'. 600 gpm, 2340 psi, 140 rpm, 10K tq. POH no pumps to 6589'. 08:00 - 09:00 1.00 DRILL P INTi RIH f/6589' to 8754'. 09:00 - 10:00 1.00 DRILL P INT1 Service top drive. Replace topdrive hydraulic hose. 10:00 - 10:30 0.50 DRILL P INT1 RIH f/8754' to 10545'. 10:30 - 12:00 1.50 DRILL P INT1 Wash down f/10545' to 10590' and pump 30 bbl. 11.3 ppg weighted sweep. 600 gpm, 2640 psi, 140 rpm, 14 tq. 12:00 - 13:00 1.00 DRILL P INT1 Cont. pumping sweep. RoUReciprocate. 600 gpm, 2570 psi, 140 rpm, 18K tq, 285K PU, 163K SO, 192K ROT. Take SPRs. 13:00 - 16:00 3.00 DRILL P INT1 POH (/10590' 5 stds, pump dry job. POH to 9335', 25K overpull, wipe tight spot. 16:00 - 17:30 1.50 DRILL N RREP INT1 Replace second topdrive hydraulic hose. 17:30 - 22:30 5.00 DRILL P INT1 POH to BHA at 1062'. 25K overpull at 9335k', 15K overpull at 6541', 5715', 5684', 5640'. Wipe tight spots then pull ok. 22:30 - 00:00 1.50 DRILL P INT1 PJSM. LD 17 jts HWDP and hydraulic jars. 4/20/2007 00:00 - 02:00 2.00 DRILL P INT1 Cont. LD BHA. The bit was in good shape, 1-1-CT-A-X-I-NO-TD with 3 chipped cutters. Of note: 3 of the flow channels were packed solid with hardened clay which was difficult to chip out, and the other 3 were partially blocked. Clear floor. 02:00 - 03:30 1.50 CASE P LNR1 PJSM w/casing hand, tourpusher, WSL all hands on RIH w/7" 26# BTC-M liner. RU casing running equip. 03:30 - 04:30 1.00 CASE P LNR1 RIH w/shoe track jts. 1-3. Check floats. OK. Fill pipe. RU headpin and pump through floats. OK 04:30 - 16:00 11.50 CASE P LNR1 RIH w/7" 26# L-80 BTC-M liner to 4,500'. Circulate 1.5 x liner volume. RIH to 5956'. Install 135 ea 7 1/8" x 9" Halliburton bow spring centralizers free floating on first 135 joints of liner. PU 160, SO 110. 16:00 - 00:00 8.00 CASE P LNR1 PU HR liner running tools and RIH w/Liner. Every 7 stands break circulation stage up to 3 bpm and see some losses. Back off on rate to 2.5 bpm and pump stand down 7/min/stand with no losses. Stop circulation above HRZ and RIH to TD at 10591'. PU 340K, SO 140K. 4/21/2007 00:00 - 04:30 4.50 CASE P LNR1 Tag up TD at 10591' and attempt to reciprocate/circulate staging up to 7 bpm. Pack off and pressure up to 1350 psi at 3.5 bpm. Work pipe and back off rate to 1.5 bpm. Continue staging rates up and backing off as packoffs occur. Kept working pipe and staging up bringing slight amounts of shale across shakers. Saw tar substance and experienced severe screen blinding early in circulation efforts. Got rates up to 6.2 bpm/1090 psi. PJSM w/Schlumberger, all hands, WSL for cement job. 04:30 - 06:00 1.50 CASE N RREP LNR1 Rig electrical problems. Shut down and circulate 3 bpm at 850 psi. Draw-works shut down 5-10 mins. Epoch down. Used manual gages and rate meters on pumps for backup to keep Printed: 5/7/2007 11:16:48 AM ~ ~ BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours ; Task ~ Code NPT Phase -_ - - -- 4/21/2007 04:30 - 06:00 1.50 ~ CASE ~ N ~ RREP (LNR1 06:00 - 08:00 2.00 CASE I N RREP I LNR1 08:00 - 08:30 08:30 - 09:00 09:00 - 12:00 0.50 CASE P 0.50 CEMT P 3.00 CEMT P LNR1 LNR1 LNR1 Description of Operations circulation going when pump power became available. Waiting for Epoch repairs at 06:00. Repair Epoch and SCR while circulating at 6.5 bpm. Reciprocate pipe. Circulate well at 6.5 bpm. Clean returns. PJSM for cementing. Prime pumps. Pressure test lines to 4,000 psi. Pump 40 bbls of 11 ppg mud push spacer, 167 bbls of 12 ppg lite Crete lead slurry, followed by 35 bbls of 15.8 ppg class G tail slurry with gas block. Shut down pumps and drop drill pipe wiper dart. Wash up cement lines and launch dart: Switch to rig pumps. Displace cement with 10.3 ppg LSND mud. Stage down displacement rate following CemCade: total strokes pumped rate(strokes/min) 3206 87 3553 69 3986 52 4766 35 4974 26 5113 17 Full returns during entire job. Reciprocate pipe 10' strokes until 5,000 strokes into the displacement. Bump plug at 5,113 strokes. Tail slurry exited pipe at 4705 strokes. 12:00 - 13:00 1.00 CEMT P 14:00 - 18:30 4.50 CEMT P 18:30 - 19:00 0.50 CEMT P 19:00 - 19:30 0.50 CEMT P 19:30 - 21:00 1.50 CEMT P 21:00 - 22:00 1.00 BOPSU P 22:00 - 00:00 2.00 BOPSU P LNR1 LNR1 LNRi LNR1 INT1 PROD1 PRODi Pressure up to 2,800 psi to set flex lock hanger. Set down 20K to confirm hanger set. Bleed off pressure and set down to finish setting hanger. Pressure up to 4,200 psi to release HR tool from liner. Bleed off pressure and check floats, OK. PU 6' to expose rotating dog sub PU wt =110K. Slack off on liner top and observe two shear indications for setting packer. Continue to slack off to 40K. Pick up and set back down on packer. Hold weight on packer and rotate 5 turns to the right to ensure packer is set. Pressure up to 500 psi and PU to pull RS pack off from RS nipple. Observe pressure start to fall off and increase rate immediately. PU to place liner running tools above the top of the liner. Circulate excess cement off the top of the liner at 462 gpm, 900 psi. Mud push and 60 bbls of cement returned to surface. Make surface breaks on TopDrive cementing head and LD. Pump dry job. POOH f/4599' and LD 5" DP. Make surface breaks on HR liner running tool and LD. Check brass indicator shear pins on rotating dog sub and find them sheared. RIH w/1225' of 5 drill pipe f/derrick. POH and LD 5" drill pipe f/1225'. Clean and clear floor. Pull wear bushing. Install 13" test plug. PJSM w/all hands. CO lower 4-1/2" x 7" pipe rams to 2-7/8" x 5" variable rams. RU and perform BOP test. Test BOPs 250 psi low pressure test and 4000 psi high pressure test. Test annular preventer to Printed: 5/7/2007 11:16:48 AM BP EXPLORATION Page 8 of 16 I Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date 'From - To Hours -__ __ 4/21 /2007 22:00 - oo:oo I 2.00 Task Code' NPT ~ Phase Description of Operations P I IPRODI 4/22/2007 100:00 - 04:00 I 4.001 BOPSUFI P I I PROD1 04:00 - 04:30 0.50 BOPSU P PROD1 04:30 - 08:30 4.00 DRILL N RREP PROD1 08:30 - 09:30 1.00 DRILL P PROD1 09:30 - 11:30 2.00 DRILL P PROD1 11:30 - 12:30 1.00 DRILL P PROD1 12:30 - 13:00 0.50 DRILL P PROD1 13:00 - 15:00 2.00 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 20:00 4.50 DRILL P PROD1 20:00 - 21:00 1.00 DRILL P PROD1 21:00 - 22:30 1.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 23:30 0.50 EVAL P PROD1 23:30 - 00:00 0.50 EVAL P PROD1 4/23/2007 100:00 - 02:00 I 2.001 DRILL I P I I PROD1 02:00 - 04:00 I 2.001 DRILL I P I I PROD1 04:00 - 05:00 I 1.001 DRILL I P I I PROD1 05:00 - 06:30 1.501 DRILL P PROD1 3500 psi. Test accumulator. NOTE: Lou Grimaldi w/AOGCC waived AOGCC presence for the test. Witnessed by Lowell Anderson BP WSL and Biff Perry Nabors Tourpusher. Continue test BOPs 250 psi low pressure test and 4000 psi high pressure test. Test annular preventer to 3500 psi. Test w/4" and 5" test jts. Test accumulator. NOTE: Lou Grimaldi w/AOGCC waived AOGCC presence for the test. Witnessed by Lowell Anderson BP WSL &Biff Perry Nabors Tourpusher. RD test equipment and BD lines. CO brake bands on draw-works. Change oil in topdrive. PU 6-1/8" production hole drilling BHA # 6 with: 6-1/8" Hughes MX-18HDX ser #5118339, XP AIM Motor w/1.50 deg bend, by pass sub w/float, NM stabilizer, NM Flex lead drill collar, Impulse MWD, PWD, 3 NM Flex drill collars, ball catcher, CCV circ valve, hydraulic jars, (mixed string 4" drill pipe, 5" drill pipe to drill section). PU 4" HT-40 drill pipe to 1183'. Shallow test MWD 250 gpm, 880 psi. PU 4" drill pipe f/1183' to 3094'. Fill pipe every 2500'. Adjust brakes. Cont. PU 4" HT-40 drill pipe f/3094' to 7874'. RIH w/5" drill pipe from derrick f/7874' to 10226'. Cut and slip 134' of drilling line. Adjust brakes. Hook up blower hose. RIH f/10226' and tag cement stringers at 10465'. PU to 10444', RU circ lines. PU 240, SO 125K. Test 9-5/8" casing f/surface to 7" liner top packer at 4599' down to landing collar in 7" liner at 10504'. 4000 psi for 30 mins. Record on chart. Straight line. Drill cement stringers (/10465' through plugs/landing collar at 10503', float collar at 10544', to 10588' just above shoe. Experiencing high torque 9K-10K. Mud swap. Circulate 100 bbls. H2O, 40 bbl Hi-Vis/EP MudLube Pill, 8.4 ppg Flo-Pro mud around surface to surface + 120 bbls. 298 gpm, 1860 psi. D5. Well control drill. Lined up pumps on choke and had all hands, Tourpusher and WSL take turns on choke for simulated well control situation. Drill f/10588' out of shoe at 10590' + 20' 6-1/8" hole to 10610'. 300 gpm, 1440 psi, 60 rpm, 5K tq, PU 200K, SO 150K, ROT 135K. 06:30 - 07:30 1.00 DRILL P PROD1 CBU. 300 gpm, 1615 psi, 60 rpm, 5K tq. 07:30 - 08:00 0.50 DRILL P PROD1 PU to shoe at 10588' and FIT to 10 ppg EMW w/8.4 ppg FloPro mud, 8663' TVD. Perform baseline ECD check. 08:00 - 12:00 4.00 DRILL P PROD1 RIH f/10588' to 10610' and drill to 10699'. PU 200K, SO 153K, ROT 135K, 290 gpm, 1460 psi on, 1410 psi off, 60 rpm, 6K tq on, 5K tq off. 12:00 - 00:00 12.00 DRILL P PROD1 Drill directionally f/10699' to 11096'. PU 205K, SO 150K, ROT 170K, 300 gpm, 1860 psi on, 1720 psi off, 60 rpm, 6.5K tq on, 5K tq off. ECDs talc = 9.30 ECDs act = 9.43. Printed: 5/7/2007 11:16:48 AM BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date I From - To ~ Hours Task Code NPT Phase Description of Operations 4/23/2007 12:00 - 00:00 12.00 DRILL P PROD1 ADT = 11.38 hrs f/24 hrs. AST = 5.35 hrs. ART = 6.03 hrs. Progress = 506'. 4/24/2007 00:00 - 08:00 8.00 DRILL P PROD1 Drill 6-1/8" hole f/ 11,096' to 11,422' md. WOB 20K, PU 206K, SO 155K, ROT 170K, 301 gpm, 1840 psi on, 1730 psi off, 6.5K tq on, 5.5K tq off, 60 rpm. ECDs calc. = 9.31, ECDs act = 9.40 ppg. BIT total 17.61 hrs. AST=4.4 hrs & ART 1.48. Jars 66.83 hrs. 08:00 - 09:30 1.50 DRILL P PROD1 Circulate 1.5 times bottoms up, Recip & Rotate C~? 80 rpm/ 300 gpm. Monitor well -static. 09:30 - 10:30 1.00 DRILL P PROD1 POH 10 Stds to 10,328' md, Pump dry job, & blow down lines. 10:30 - 13:30 3.00 DRILL P PROD1 Continue to POH to 4,717' md. Top of window in 9 5/8" csg ~ 4,756' md. 13:30 - 14:30 1.00 DRILL P PROD1 Drop 1.76" Silver ball, Shear CCV valve sub @ 2000 psi. Circ hole clean. Circ 404 bbls ~ 565 gpm / 780 psi - No increase in cuttings returns noted. Pump dry job. 14:30 - 17:30 3.00 DRILL P PROD1 Continue to POH f/ 4,717' to the BHA. Drop 1.63" Brass ball to close CCV valve. Pumped 33 bbls, Attempt failed -Consult w/ town. Drop another 1.76" Silver ball, Pressure up U 1950 psi. Confirm shut. 17:30 - 18:30 1.00 DRILL P PROD1 Lay down Jars, Ball catcher, CCV, recover 3 balls. Stand back 4 3/4" Flex collars, break Bit. 18:30 - 19:30 1.00 DRILL P PROD1 Make up new 6 1/8" Bit #6 - Hycalog -DTX611 M-A5 Upload MWD. Lay down MWD (software failure). 19:30 - 20:00 0.50 DRILL N DFAL PROD1 Trouble shoot MWD. 20:00 - 21:30 1.50 DRILL P PROD1 P/U new MWD, download PWD and connectivity test f/ bit. M/U Flex collars, jars, CCV sub, and ball catcher. 21:30 - 00:00 2.50 DRILL P PROD1 RIH picking up 4" DP f/ 227' to 1,182' md. Shallow test MWD @ 270 gpm / 770 psi. Continue RIH. 4/25/2007 00:00 - 04:30 4.50 DRILL P PROD1 RIH to 11,422, Fill pipe Q 3,376, 8,667 & 11,408' and 04:30 - 04:45 0.25 DRILL P PROD1 Break circulation & establish SPR's (slow pump rates). Tag Btm ~ 11,422'md / 8981 tvd. 04:45 - 12:00 7.25 DRILL P PROD1 Drill ahead f/ 11,422' and to 11,724'md. AST-3.74, ART-1.08, PU-200K, SO-135K, ROT-158K, 303 gpm, 1930 psi. Tq on-7.5, Tq off-6.5, WOB-10K, RPM-60. 12:00 - 00:00 12.00 DRILL P PROD1 Continue to drill ahead f/ 11,724'md t/ 12,279'md. PU- 205K, SO- 137K, ROT- 155K, WOB- 10K, RPM- 60. 301 gpm, 2150 psi on Btm, 1930 psi. off Btm. AST-6.05, ART-2.17, ADT-8.22, Calc ECD =9.6 ppg. Act ECD= 9.71 ppg. 4/26/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drld ahead f/ 12,279' md. to 12,734' md. PU- 210K, SO- 137K, ROT- 160K, WOB- 15K, RPM- 60. 301 gpm, 2250 psi on Btm, 2070 psi off Btm. Tq on Btm- 9K, Tq off Btm- 7.5K AST- 7.6, ART- 0.63, ADT- 8.23. Calc ECD- 9.67 ppg, Act ECD- 9.89 ppg. Printed: 5!7/2007 11:16:48 AM i ~ BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i Name: 0 ell Name: 0 e: Name: From - To 3-36 3-36 REENTE NABOR NABOR Hours ~ j R+COM S ALASK S 7ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase , Spud Date: 4/3!1993 : 4/5/2007 End: Release: 5/7/2007 Number: Description of Operations 4/26/2007 12:00 - 00:00 12.00 DRILL P PROD1 Drld ahead f/ 12,734' and to 13,481' and / 9,045' tvd. PU- 215K, SO- 137K, ROT- 162K, WOB- 10K, RPM- 80. 301 gpm, 2400 psi on Btm, 2200 psi off Btm. Tq on Btm- 9.5K, Tq off Btm- 7.7K AST- 2.82, ART- 5.02, ADT- 7.84. Calc ECD- 9.93 ppg, Act ECD- 9.99 ppg. Slow Pump Rate taken at 13,294 'md / 9,042' tvd. 4/27/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drld ahead trouble free f/ 13,481' and to 14,047' and / 9,045' tvd. PU- 225K, SO- 140K, ROT- 168K, WOB- 10K, RPM- 80. 301 gpm, 2435 psi on Btm, 2280 psi off Btm. Tq on Btm- 10K, Tq off Btm- 8K AST- 6.55, ART- 1.80, ADT- 8.35. Calc ECD- 9.97 ppg, Act ECD- 10.20 ppg. Mud weight 8.7 ppg. 12:00 - 00:00 12.00 DRILL P PROD1 Drld ahead f/ 14,047' and to 14,636' and / 9,045 tvd. D-D noted stacking on slides. NOTE: Mud weight & ECD's were climbing- perform mud swap out. 20:00 hrs/ 14,488' md. Displaced in 580 bbls of new 8.4 ppg S.F. Flo-Pro. System mud weight cut f/ 8.7 ppg to 8.5 ppg. No stacking noted on next slide and pump psi decreased 100 psi. PU- 223K, SO- 140K, ROT- 165K, WOB- 15K, RPM- 80. 301 gpm, 2220 psi on Btm, 2150 psi off Btm. Tq on Btm- 10.5K, Tq off Btm- 8.5K AST- 3.92, ART- 3.55, ADT- 7.47. Calc ECD- 10.21 ppg, Act ECD- 10.0 ppg. Mud weight 8.5 ppg. Slow pump rate taken ~ 14,613' and / 9,045' tvd. 4/28/2007 00:00 - 09:00 9.00 DRILL P PROD1 Drld ahead f/ 14,636' and to 14,761' and / 9,046' tvd. PU- 227K, SO- 140K, ROT- 165K, WOB- 10K - 35K, RPM- 80. 300 gpm, 2215 psi on Btm, 2053 psi off Btm. Tq on Btm- 11.5K, Tq off Btm- 9.5K. Calc ECD- 9.96 ppg, Act ECD- 9.95 PPG. AST= 2.80, ART= 0.87, ADT=3.67 hrs. Mud weight= 8.6 ppg. 09:00 - 12:00 3.00 DRILL P PROD1 POH due to slow ROP. POH f/ 14,761' and to 11,217 md. P/U= 230K, S0= 140K. 12:00 - 12:30 0.50 DRILL P PROD1 Continued to POH f/ 11,217' and to 10,588' md. 20K overpull ~ 10,870 md, worked tight area. P/U= 198K, S0= 155K ', 12:30 - 15:00 2.50 DRILL P PROD1 ~ 10,588' md. Establish circ rate ~ 2 bpm / 540 psi, drop I 1.76" ball. Continue to pump ~ 2 bpm / 540 psi for 105 bbls. ', Seat ball @ 1,875 psi. Open CCV circ sub. ~, CBU 677 bbls @ 530 gpm / 1,840 psi. Slight increase in 'i cuttings returns. Monitor well -Static. Pump dry job. i 15:00 - 17:00 2.00 DRILL P PROD1 POH f/ 10,588' and to 4,720' md. 17:00 - 18:00 1.00 DRILL P PROD1 Circ through CCV sub across liner top @ 4,599' md. Rate= 512 gpm / 715 psi for 413 bbls. No apparent increase in cuttings Printed: 5/7/2007 11:16:48 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours ~ Task j Code ~ NPT Start: 4/5/2007 Rig Release: 5/7/2007 Rig Number: Phase --_ _ ~ __ 4/28/2007 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 19:30 1.50 DRILL P PROD1 19:30 - 20:00 0.50 DRILL P PROD1 20:00 - 21:00 I 1.001 DRILL I P I I PROD1 21:00 - 21:30 0.50 ~ DRILL ~ P PROD1 21:30 - 23:30 I 2.001 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 4/29/2007 00:00 - 04:30 4.50 DRILL P PROD1 04:30 - 06:30 2.00 DRILL P PROD1 06:30 - 09:30 3.00 DRILL P PROD1 09:30 - 12:00 I 2.501 DRILL I P I I PROD1 12:00 - 00:00 I 12.001 DRILL I P I I PROD1 4/30/2007 100:00 - 02:30 2.501 DRILL P PROD1 02:30 - 03:00 0.501 DRILL P PROD1 03:00 - 06:00 I 3.001 DRILL I P I I PROD1 Page 1 1 of 16 Spud Date: 4/3/1993 End: Description of Operations returns. Monitor well- Static. Pump dry job. POH f/ 4,720' and to 323' md. Drop 1.76" ball, pump @ 2 bpm to close CCV ~ 1860 psi.- Confirm shut, circ 2 bpm / 220 psi. UD Jars, UD CCV & ball catcher, recover (2) x 1.76" balls. Stand back Flex collars, UD motor. Bit 7-7-RO-A-X-I-BT-PR. Clean rig floor. M/U bit. Upload PWD &MWD, connectivity test. Continue to M/U BHA. UD MWD due to loose wear bands, M/U MWD & orient motor. Up load MWD. RIH to 1,183' md, surface test MWD @ 280 gpm / 720 psi. RIH f/ 1,183' and to 10,558' md. PJSM. Cut & slip drilling line (503'). Service Top drive. RIH f/ 10,558' and t/ 14,761' md. Work tight spot C~ 10,870' and (took 15K wt). Continued to RIH, Kelly up ~ 14,614' and & wash down to 14,761' md. Wash down parameters - 250 gpm / 1,770 psi. RPM= 60. P/U= 227K. S0= 130K. ROT wt= 160K. Drld f/ 14,761' and to 14,842' and / 9,045' tvd. 300 gpm / 2266 psi on - 2160 psi off bottom. RPM= 80, W06= 10-15K. Tq on= 10.5K, Tq off= 9.5K, P/U= 230K, S0= 135K, ROT wt= 165K. Calc ECD= 9.97 ppg, Act ECD= 10.07 ppg. ART= 0.05 hrs, AST= 1.45 hrs, ADT= 1.50 hrs. Drill ahead f/ 14,842' and to 15,274'md / 9,043' tvd. 300 gpm / 2350 psi on - 2220 psi off bottom. RPM= 80, WOB= 15K. Tq on= 11 K, Tq off= 10K, P/U= 235K, S0= 138K, ROT wt= 165K. Calc ECD= 10.10 ppg, Act ECD= 10.17 ppg. ART= 2.78 hrs, AST= 5.97 hrs, ADT= 8.75 hrs. Slow pump rates taken @ 15,180' and / 9,044 tvd. Mud weight = 8.6 ppg. Drill f/ 15,274' and to 6 1/8" T.D. depth 15,365' and / 9,043' tvd. Circulated 20 minutes after T.D to clean new hole. NOTE: Prior to T.D. - At 15,274' while drilling down the last stand, -Pumped Wtd Sweep -30 bbls - 10.1 ppg. results were a 15 cuttings returns increase noted at surface. Monitor well -static. Short trip past previous bit trip depth from 15,365' and to 14,740' md. P/U= 240K, S0= 130K. Circulate hole clean. NOTE: Increase RPM to 100 ~ 11.5K off bottom Tq. for first 15 minutes. Pumped 466 bbls ~ 300 gpm / 2320 psi. Bottoms up cuttings returns increased 50% for 5 minutes. Spot Liner running pill - 200 bbls Lube 776 /Drill Beads mud Printed: 5/7/2007 11:16:48 AM • • BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task ~ Code NPT~ Phase ~~ Description of Operations 4/30/2007 03:00 - 06:00 3.00 DRILL P PROD1 pill. Displace pill into open hole. Mud weight = 8.6 ppg. 06:00 - 09:00 3.00 DRILL P PROD1 Monitor well -static. POH f1 15,365' and to 10,550' and (38' inside 7" casing). P/U= 240K, S0= 130K. 09:00 - 11:00 2.00 DRILL P PROD1 Drop ball to open CCV circ sub. Chase ball @ 2 bpm - 40 bbls / 600 psi. CCV opened @ 2100 psi :Pump 513 bbls ~ 500 gpm / 1810 psi. Monitor hole -static. Pump dry job, blow down Top Drive. Mud weight 8.7 ppg. 11:00 - 14:00 3.00 DRILL P PROD1 POH f! 10550' and to 4,815' md. 14:00 - 15:00 1.00 DRILL P PROD1 Circulate 471 bbls through CCV ~ 570 gpm / 915 psi. Slight increase in cuttings noted at surface at bottoms up. Monitor hole -static. Pump dry job. Blow down lines. Mud weight 8.7 ppg. 15:00 - 16:00 1.00 DRILL P PROD1 POH f/ 4,815' and to 325' md. 16:00 - 16:30 0.50 DRILL P PROD1 Drop ball, to close CCV. Circ ~ 2 bpm / 1900 psi f/ 2.5 bbls. Confirm shut -pump 3 bpm / 200 psi for 12 bbls. 16:30 - 18:00 1.50 DRILL P PROD1 Monitor hole -static. Lay down BHA. Clean and clear floor. 18:00 - 20:00 2.00 CASE P RUNPRD R/U torque turn equipment to run 4 1/2" - 12.6# L-80- TCII liner. PJSM with Crew, NAD T.P., B.P. rep, Baker rep and casing running crew. 20:00 - 00:00 4.00 CASE P RUNPRD Run 4 1/2" - 12.6# L-80- TCII liner. Optimum torque 3,850 fVlbs. M/U Shoe track, check floats, run liner and swell packers. 1st Swell packer run in hole ~ 10:45 PM 4/30/07 -calipered ~ 5.75" 2nd Swell packer calipered @ 5.75". Mud wt 8.7 ppg. 5/1/2007 00:00 - 06:00 6.00 CASE P RUNPRD Run 4 1/2" - 12.6# L-80- TCII Liner and Swell packers from 1,300' and to 4,946' md. Avg M!U Tq=3850 ft/Ibs. P/U=75K, S0= 65K. 06:00 - 08:30 2.50 CASE P RUNPRD C/O elevators, P/U Liner hanger and Liner Top packer, RIH. C/O floor equipment to 4". Clean and clear floor of 4 1/2" Liner equipment. P/U 1st stand of 4" DP. RIH. Circulate liner vol of 75 bbls C~J 5,054' md. PlU=77K, S0= 65K, ~ 175 gpm 1200 psi. Mud wt= 8.7 ppg. 08:30 - 12:30 4.00 CASE P RUNPRD Continue to run 4/1/2" Liner on 4" DP to 10,588' md. Run speed 1 minute !Std, filling every 10 stds. 12:30 - 13:30 1.00 CASE P RUNPRD Circulate 1.5 times DP & Liner volume (200 bbls), and stage up pump rate. 3 bpm / 700 psi, 4 bpm / 780 psi & 5 bpm / 935 psi. P/U wt=155K, S0= 125K, ROT wt= 140K, 20 RPM, 5K Tq. Mud wt= 8.7 13:30 - 17:00 3.50 CASE P RUNPRD Continue to RIH to 15,314' md, filling pipe every stand. Install 2 ea 4 1/2" x 5 3/4" OD x 10" long Spirolizer Centralizers per joint with a stop ring in the middle of each joint on the first 115 joints (total 230 centralizers) P/U= 215K, S0= i 20K. 17:00 - 17:30 0.50 CASE P RUNPRD P/U Liner cement head and lines, RIH, tag bottom @ 15,365' Printed: 5/7/2007 11:16:48 AM ~ • BP EXPLORATION Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To Hours Task ~ Code NPT - --- _ _ . _ 5/1/2007 17:00 - 17:30 0.50 CASE P 17:30 - 20:30 3.00 CASE P 20:30 - 21:30 I 1.00 I CASE I P 21:30 - 22:30 I 1.001 CASE I P 22:30 - 00:00 I 1.501 CASE I P 5/2/2007 100:00 - 00:30 I 0.501 CASE I P 00:30 - 02:30 I 2.001 CASE I P 02:30 - 03:30 I 1.001 CASE I P 03:30 - 05:00 1.501 CASE P 05:00 - 07:00 I 2.001 CASE I P 07:00 - 12:00 5.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 17:00 4.50 CASE P 17:00 - 17:30 0.50 EVAL P 17:30 - 00:00 6.50 EVAL P 5/3/2007 100:00 - 09:30 I 9.501 EVAL I P 09:30 - 10:30 I 1.00 I EVAL I P Start: 4/5/2007 Rig Release: 5/7/2007 Rig Number: Page 13 of 16 Spud Date: 4/3/1993 End: Phase Description of Operations RUNPRD and / 9,043' tvd. RUNPRD Stage pumps up: 1 bpm / 840 psi. 2bpm / 970 psi. 3bpm / 1050 psi. PJSM w/ BP rep, NAD TP, Baker rep, M-I, &SLB. RUNPRD PT lines to 4500 psi. Pump cement (40 bbls Mud push ~ 11.0 ppg & 126 bbls of cement (Class "G: with GASBLOK) ~ 15.8 PPg)• RUNPRD Switch to rig pumps and displace. Pump: 15 bbl pert pill, 65 bbls of Seawater, 120 bbls of 8.7 ppg Flo-Pro. Bump plug to 2700 psi. Reciprocate Liner entire job. Full returns received. RUNPRD Slack off to confirm Hanger set, bleed pressure to zero. Slack off 25K + Liner wt. Fully set Liner hanger. Pressure up DP to 4000 psi. Release HR setting tool. Bleed pressure, check floats. P/U & expose LTP setting dogs. Slack off, set 40K on ZXP LTP. P/U, Slack off 40K down on ZXP LTP. Rotate 6 right hand turns. Pressure annulus to 1500 psi f/ 5 minutes. Pressure up to 500 psi, P/U until Rotating Sub Pack Off Seal clear of RS nipple and top of Liner top. RUNPRD Circulate out and dump cement contaminated mud (132 bbls contaminated) ~ 450 gpm / 1850 psi. Dumped 32 bbls of cement. RUNPRD Lay down Liner cementing head & 2 singles. R/U to CBU ~ 379 bbls. 450 gpm / 1700 psi. RUNPRD Test Casing & Liner to 4000 psi. Hold for 30 minutes. -PASS. R/D & blow down lines. RUNPRD Displace well to 8.5 ppg Seawater ~ 450 gpm / 1800 psi. Pumped 650 bbls of Seawater. Blow down Top drive. R/U to POH. RUNPRD POH f/ Liner top @ 10,416" to 5,065' md. P/U 175K, S0= 165K. RUNPRD POH L/D 4" DP. L/D Liner running tool. RUNPRD Clean & clear rig floor. RUNPRD Service rig -Top Drive, Crown, Clean Pits. Clean under Rotary Table & Drawworks w/ Super Sucker. Arrange pipe shed. Prepare 2 7/8" PAC & Perf Guns for Perf Gun run. OTHCMP PJSM w/ SLB USIT log crew. R/U E-Line equipment. OTHCMP RIH w/ USIT CBL tool, Log Cement in 7" f/ 10,395' and to 4,550' md. Require 4 repeats, for High Resolution runs: 10,395' and - 9,450' and over class "G" Cmt. 10,000' and into 9 5/8" casing -Full strip. 7,500 and - 7,050' md. 6,650' and - 6,250' md. OTHCMP Log w/ USIT: High Resolution repeat USIT Logging runs. 7,500' and - 7,050' md. 6,650' and - 6,250' md. Log 9 5/8" casing F/ 4,599' and to surface. Repeat USIT logs over areas of concern. OTHCMP Rig down SLB wireline equipment. Clean and clear floor of all wireline equipment. Printed: 5/7/2007 11:16:48 AM ~ • BP EXPLORATION Page 14 of 16 ~ Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 5/7/2007 Rig Name: NABOBS 7ES Rig Number: Date ;From - To ~ Hours Task i Code NPT Phase i Description of Operations I 5/3/2007 110:30 - 11:30 _ - _ ~ - -- - -- 1.00 PERFOtq P OTHCMP PJSM w/ Rig crew, SLB Gun rep, BP rep, NAD TP. 11:30 - 12:00 I 0.501 PERFOBI N 12:00 - 16:00 ~ 4.00 ~ EVAL ~ N 16:00 - 19:00 I 3.001 EVAL I P 19:00 - 19:30 0.50 EVAL P 19:30 - 23:30 4.00 EVAL N 23:30 - 00:00 I 0.501 EVAL I P 5/4/2007 00:00 - 01:00 1.00 PERFO~ N 01:00 - 01:15 0.25 PERFO P 01:15 - 09:30 I 8.251 PERFOBI P 09:30 - 09:45 I 0.251 PERFOBI P 09:45 - 15:00 5.25 ~ PERFOB~ P 15:00 - 16:00 I 1.001 PERFOBI P 16:00 - 17:00 1.00 17:00 - 18:30 1.50 18:30 - 18:45 I 0.25 P P P Discuss :Perf Guns -and R.P.s. Handling, P/U - UD and running in the hole procedures and safety. R/U floor to run Perf Guns WAIT OTHCMP Consult with ODE. R/D Perf Gun Handling equipment. WAIT OTHCMP Consult w/ Town. Wait on orders. Decision -Run 40 Arm caliper in 9 5/8" casing. Mobilize P.D.S. personnel and caliper tools. General maintenance and house keeping. Fluid in pits is 8.5 ppg Seawater. R/U E-Line equipment. PJSM. OTHCMP RIH w/ 40 Arm caliper in memory mode U 4,599' md. Top of 7" Liner. Log - 9 5/8" casing f/ 4,599' and to surface. OTHCMP R/D E-Line equipment. WAIT OTHCMP Consult w/ Town. Down load caliper results for field evaluation. Wait on Log results. After preliminary onsite results, contact Town. Consult with Town. (ODE & Asset group). OTHCMP Decision to Run Perf Guns. Mobilize Perf Gun crew. WAIT OTHCMP Wait on SLB crew. OTHCMP PJSM w/ Rig crew, SLB crew, BP rep, NAD TP. Discuss -Handling, P/U, running and L/D requirements & procedures for Perf Guns. OTHCMP P/U & run 3 x 40' (120') Perf Guns. P/U and run 52 stands (156 jts) of 2 7/8" Pac DP to 4,955' md. NOTE: At 04:37 hrs, received 40 Arm caliper log results from P.D.S. in Houston Tex. Maximum 9 5/8" casing wear is 49%. Area of concern from 3,983' and to 4,146' md. Seawater wt= 8.5 ppg. OTHCMP R/D 2 7/8" PAC DP floor equipment and running tools. R/U 4" floor equipment and running tools. OTHCMP RIH w/ Perf Guns on 2 7/8" PAC, 4" & 5" DP to a tag depth of 15,274' and (Landing collar). Pull up to 15,110' md. OTHCMP PJSM. Fire guns with pumping sequence. Perforate f/ 15,110' and - 15, 010' md. 6 shots per foot. Initial losses of 6 bbls. - No other losses noted. Seawater wt= 8.5 ppg. OTHCMP Monitor wellbore -static. POH U 14,923' md. OTHCMP CBU ~ 14,923' md. Pump - 184 gpm / 2390 psi. for 555 bbls of Seawater. Dumped 190 bbls of dirty Seawater (~ bottoms up). Slow pump rate taken ~ 18:30 hrs. OTHCMP PJSM. Printed: 6/7/2007 11:16:48 AM ~ • BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To ~ 3-36 3-36 REENTE NABOB NABOB Hours R+COM S ALASK S 7ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 4/3/1993 : 4/5/2007 End: Release: 5/7/2007 Number: Description of Operations 5/4/2007 18:30 - 18:45 0.25 PERFO P OTHCMP Monitor wellbore -static. Pump dry job. Blow down Top drive. 18:45 - 00:00 5.25 PERFO P OTHCMP POH, UD 5" Drill pipe ~ 10,878' md. Change Air slips and Elevators to 4". POH UD 4" DP. Seawater wt= 8.5 ppg. 5/5/2007 00:00 - 05:30 5.50 PERFO P OTHCMP POH UD 4" DP f/ 10,878' to 4,955' md. 05:30 - 11:30 6.00 PERFO P OTHCMP Clean & clear floor. R/U to UD 2 7/8" PAC DP. POH UD 2 7/8" PAC DP f/ 4,955' and to 147' (156 jts). 11:30 - 12:15 0.75 PERFO P OTHCMP PJSM w/ SLB on UD Guns. Change out floor equipment & Elevators to UD Guns. 12:15 - 13:30 1.25 PERFO P OTHCMP UD Guns and tools. Clean & clear rig floor. Seawater wt= 8.5 ppg. - No losses noted. 13:30 - 14:30 1.00 BUNCO RUNCMP Pull wear bushing. Test run tubing hanger. 14:30 - 15:30 1.00 BUNCO RUNCMP R/U to run 4.5" 12.6# - L-80 - TC II Tubing. 15:30 - 00:00 8.50 BUNCO RUNCMP PJSM. Run 4.5" -Tubing completion string. Tubing ~ 6,158' and Seawater wt= 8.5 ppg. - No losses noted. 5/6/2007 00:00 - 05:00 5.00 BUNCO RUNCMP PJSM. Run 4.5" -Tubing completion string. Tubing ~ 10,416' md. Seawater wt= 8.5 ppg. - No losses noted. 05:00 - 06:00 1.00 BUNCO RUNCMP Tag At 10,440' md. Btm of PBR. Space out and place WLEG 5' from the top of the Tie Back extension. Tagged ~ 10,440' and WLEG @ 10,435' md. 06:00 - 09:00 3.00 BUNCO P RUNCMP RILDS. R/U & Reverse in 20 bbls of clean Seawater, followed by 235 bbls of inhibited 8.5 ppg Seawater @ 3 bpm / 200 psi. 09:00 - 10:00 1.00 BUNCO P ' RUNCMP Little Red Services -Reverse in 120 bbls of 6.8 ppg diesel 10:00 - 12:00 2.00 BUNCO RUNCMP Drop Ball & Rod, Pressure up to set Packer w/ 4500 psi. Hold for 30 minutes - OK. Bleed Tbg to 1500 psi. Pressure annulus to 4000 psi. Hold for 30 minutes - OK. 12:00 - 12:30 0.50 BUNCO RUNCMP Set TWC, Test to 1000 psi f/ above - OK. 12:30 - 13:30 1.00 BUNCO RUNCMP Rig down & blow down circulating lines. Blow down Stand Pipe, Choke line, Kill fine, Choke Manifold & Hole Fill line. 13:30 - 18:00 4.50 BOPSU P RUNCMP PJSM. - ND ROPE. N/U Adaptor, Tree & W ing Valve flange. 18:00 - 19:00 1.00 W HSUR P RUNCMP FMC -Test Adaptor void to 5000 psi f/ 10 minutes - OK. Test Tree to 5000 psi f/ 5 minutes - OK. 19:00 - 20:00 1.00 WHSUR P RUNCMP DSM -Pull TWC w/ Lubricator 20:00 - 21:30 1.50 WHSUR P RUNCMP PJSM. P/U Slick line tools, Respot Slick line unit 21:30 - 00:00 2.50 WHSUR P RUNCMP PJSM. R/U Slick line and Lubricator. 5/7/2007 00:00 - 02:45 2.75 WHSUR P RUNCMP PJSM. Printed: 5/7/2007 11:16:48 AM ~ • BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 03-36 Common Well Name: 03-36 Spud Date: 4/3/1993 Event Name: REENTER+COMPLETE Start: 4/5/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/7!2007 Rig Name: NABORS 7ES Rig Number: Date ~ From - To Hours Task Code NPT Phase ~ Description of Operations - ~- - 5/7/2007 00:00 - 02:45 2.75 WHSUR P RUNCMP SLB -Slick line RIH, recover Ball & Rod ~ 10,427' md. R/D Slick line. 02:45 - 04:30 1.75 WHSUR P RUNCMP PJSM. R/U Little Red services. Bullhead 35 bbls of 6.8 ppg Diesel to Freeze Protect the 4 1/2" Tbg to 2,200' and / 2,200' tvd. Pump C~ 1 bpm / 2300 psi LRS -R/D. 04:30 - 05:00 0.50 WHSUR P RUNCMP Set TWC. Install 1 VR plug, Rig must roll ahead to set 2nd VR plug due to proximity of stack. 05:00 - 06:00 1.00 WHSUR P RUNCMP Blow down lines, Clean up cellar, put tools away. Rig Released ~ 06:00 hrs. Printed: 5/7/2007 11:16:48 AM }gyp ~~~,,~ ~~~~~ ~~ 03-36A Su Report Date: 30 April, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure /Slot: DS-03 / 03-36 Well: 03-36 Borehole: 03-36A UWI/API#: 500292234001 Survey Name /Date: 03-36A /April 30, 2007 Tort /AHD / DDI / ERD ratio: 498.736° / 9566.71 ft / 6.909 / 1.057 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.23071908, W 148.27107875 Location Grid NIE Y/X: N 5936971.550 ftUS, E 714172.220 ftUS Grid Convergence Angle: +1.62707914° Grid Scale Factor: 0.99995211 Report Schlumberger Vertical Section Azimuth: 244.00° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 55.67 ft relative to MSL Sea Bed /Ground Level Elevation: 27.00 ft relative to MSL Magnetic Declination: 24.157° Total Field Strength: 57673.396 nT Magnetic Dip: 80.943° Declination Date: April 16, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North •> True North: +24.157° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth SutrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft n n ft de 100 ft ftUS nUS rrofecteo-up u.uu u.uu u. uu -aa.n/ u. uu v.uu u.uu u.vv u.vv v.vv v.uv aasoa/ r.oo / 141 /L.ZZ r~ /v.csv/ ravo vv 14r5.Z/ IV/8/J GCT MS 57.37 0.00 0. 00 1.70 57. 37 0.00 0.00 0.00 0.00 0.00 0.00 5936971.55 714172.22 N 70.23071908 W 148.27107875 63.47 0.06 89. 34 7.80 63. 47 0.00 0.00 0.00 0.00 0.00 0.98 5936971.55 714172.22 N 70.23071908 W 148.27107873 77.47 0.06 87. 73 21.80 77. 47 -0.02 0.02 0.02 0.00 0.02 0.01 5936971.55 714172.24 N 70.23071908 W 148.27107861 91.97 0.04 99. 69 36.30 91. 97 -0.03 0.03 0.03 0.00 0.03 0.15 5936971.55 714172.25 N 70.23071908 W 148.27107851 106.37 0.01 126. 11 50.70 106. 37 -0.03 0.04 0.04 0.00 0.04 0.22 5936971.55 714172.26 N 70.23071908 W 148.27107846 120.77 0.00 138. 09 65.10 120. 77 -0.03 0.04 0.04 0.00 0.04 0.07 5936971.55 714172.26 N 70.23071908 W 148.27107845 135.07 0.00 131. 16 79.40 135. 07 -0.03 0.04 0.04 0.00 0.04 0.00 5936971.55 714172.26 N 70.23071908 W 148.27107845 149.37 0.00 133. 85 93.70 149. 37 -0.03 0.04 0.04 0.00 0.04 0.00 5936971.55 714172.26 N 70.23071908 W 148.27107845 163.67 0.00 137. 77 108.00 163. 67 -0.03 0.04 0.04 0.00 0.04 0.00 5936971.55 714172.26 N 70.23071908 W 148.27107845 177.92 0.00 142. 37 122.25 177. 92 -0.03 0.04 0.04 0.00 0.04 0.00 5936971.55 714172.26 N 70.23071908 W 148.271 192.07 0.00 149. 76 136.40 192 .07 -0.03 0.04 0.04 0.00 0.04 0.00 5936971.55 714172.26 0 N 70.23071908 W 148.2710 206.07 0.01 136. 41 150.40 206 .07 -0.03 0.04 0.04 0.00 0.04 0.07 5936971.55 714172.26 N 70.23071907 W 148.27107 4 220.07 0.01 134. 98 164.40 220 .07 -0.03 0.04 0.04 -0.01 0.04 0.00 5936971.55 714172.26 N 70.23071907 W 148.27107843 234.07 0.02 159. 84 178.40 234. 07 -0.03 0.05 0.04 -0.01 0.04 0.08 5936971.54 714172.26 N 70.23071906 W 148.27107842 248.02 0.03 172. 07 192.35 248. 02 -0.03 0.05 0.05 -0.01 0.04 0.08 5936971.54 714172.26 N 70.23071904 W 148.27107840 261.87 0.03 167. 96 206.20 261. 87 -0.03 0.06 0.05 -0.02 0.04 0.02 5936971.53 714172.26 N 70.23071902 W 148.27107839 275.67 0.04 149. 88 220.00 275. 67 -0.03 0.07 0.06 -0.03 0.05 0.11 5936971.52 714172.27 N 70.23071900 W 148.27107837 289.47 0.04 124. 42 233.80 289 .47 -0.03 0.08 0.06 -0.04 0.05 0.13 5936971.52 714172.27 N 70.23071898 W 148.27107832 303.37 0.06 108. 60 247.70 303 .37 -0.04 0.09 0.08 -0.04 0.06 0.17 5936971.51 714172.29 N 70.23071897 W 148.27107823 317.27 0.09 105. 63 261,60 317 .27 -0.05 0.11 0.09 -0.05 0.08 0.22 5936971.51 714172.30 N 70.23071896 W 148.27107809 331.12 0.08 107. 22 275,45 331 .12 -0.07 0.13 0.11 -0.05 0.10 0.07 5936971.50 714172.32 N 70.23071894 W 148.27107793 345.27 0.07 110. 47 289.60 345. 27 -0.08 0.15 0.13 -0.06 0.12 0.08 5936971.50 714172.34 N 70.23071892 W 148.27107779 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 1 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt ft ft tt ft tt ft de 100 ft ttUS ftUS ~5y.4/ U.U/ 111.(13 :iU3.tSU 3Sy.4/ -U.Uy U.1(i U.lb -U.U(i U.14 U.UI by:itiy/1.4y /141/"1.:iti N /U.1:iU/ltiyl W 14t5.L/1U//EiEi 373.77 0.06 109.56 318.10 373.77 -0.10 0.18 0.17 -0.07 0.15 0.07 5936971.48 714172.37 N 70.23071889 W 148.27107753 388.07 0.05 109.09 332.40 388.07 -0.11 0.19 0.18 -0.07 0.16 0.07 5936971.48 714172.39 N 70.23071888 W 148.27107743 402.32 0.03 106.51 346.65 402.32 -0.12 0.20 0.19 -0.08 0.17 0.14 5936971.48 714172.40 N 7023071887 W 148.27107735 416.62 0.03 105.84 360.95 416.62 -0.13 0.21 0.20 -0.08 0.18 0.00 5936971.48 714172.40 N 70.23071886 W 148.27107730 430.97 0.03 111.26 375.30 430.97 -0.13 0.22 0.20 -0.08 0.19 0.02 5936971.47 714172.41 N 70.23071886 W 148.27107724 445.12 0.02 112.26 389.45 445.12 -0.14 0.22 0.21 -0.08 0.19 0.07 5936971.47 714172.42 N 70.23071885 W 148.27107719 459.37 0.01 111.83 403.70 459.37 -0.14 0.23 0.21 -0.09 0.20 0.07 5936971,47 714172.42 N 70.23071885 W 148.27107716 473.82 0.01 113.82 418.15 473.82 -0.14 0.23 0.22 -0.09 0.20 0.00 5936971.47 714172.42 N 70.23071885 W 148.27107715 488.17 0.02 116.66 432.50 488.17 -0.14 0.23 0.22 -0.09 0.20 0.07 5936971.47 714172.42 N 70.23071884 W 148.27107712 502.67 0.03 123.82 447.00 502.67 -0.15 0.24 0.23 -0.09 0.21 0.07 5936971.46 714172.43 N 70.23071883 W 148.27107707 517.07 0.01 130.86 461.40 517.07 -0.15 0.25 0.23 -0.09 0.21 0.14 5936971.46 714172.43 N 70.23071882 W 148.2710 531.47 0.00 134.72 475.80 531.47 -0.15 0.25 0.23 -0.10 0.21 0.07 5936971.46 714172.44 N 70.23071882 W 148.27107703 545.87 0.01 139.83 490.20 545.87 -0.15 0.25 0.23 -0.10 0.21 0.07 5936971.46 714172.44 N 70.23071882 W 148.27107703 560.37 0.01 146.09 504.70 560.37 -0.15 0.25 0.24 -0.10 0.22 0.01 5936971.46 714172.44 N 70.23071881 W 148.27107701 574.67 0.00 148.12 519.00 574.67 -0.15 0.25 0.24 -0.10 0.22 0.07 5936971.46 714172.44 N 70.23071881 W 148.27107701 589.17 0.00 153.93 533.50 589.17 -0.15 0.25 0.24 -0.10 0.22 0.00 5936971.46 714172.44 N 70.23071881 W 148.27107701 603.52 0.00 162.63 547.85 603.52 -0.15 0.25 0.24 -0.10 0.22 0.00 5936971.46 714172.44 N 70.23071881 W 148.27107701 617.87 0.02 169.02 562.20 617.87 -0.15 0.25 0.24 -0.10 0.22 0.14 5936971.45 714172.44 N 70.23071880 W 148.27107701 632.07 0.03 176.35 576.40 632.07 -0.15 0.26 0.24 -0.11 0.22 0.07 5936971.45 714172.44 N 70.23071879 W 148.27107700 646.37 0.02 185.09 590.70 646.37 -0.15 0.27 025 -0.11 0.22 0.07 5936971.44 714172.44 N 70.23071877 W 148.27107700 660.77 0.01 194.38 605.10 660.77 -0.14 027 0.25 -0.12 0.22 0.07 5936971.44 714172.44 N 70.23071876 W 148.27107700 675.17 0.02 200.58 619.50 675.17 -0.14 0.27 0.25 -0.12 022 0.07 5936971.43 714172.44 N 70.23071875 W 148.27107701 689.52 0.03 202.36 633.85 689.52 -0.14 0.28 0.25 -0.13 0.21 0.07 5936971.43 714172.44 N 70.23071873 W 148.27107703 703.87 0.03 205.87 648.20 703.87 -0.13 0.29 0.25 -0.13 0.21 0.01 5936971.42 714172.43 N 70.23071872 W 148.27107706 718.27 0.03 209.61 662.60 718.27 -0.12 0.30 0.25 -0.14 0.21 0.01 5936971.42 714172.43 N 70.23071870 W 148.27107709 732.67 0.04 213.47 677.00 732.67 -0.12 0.30 0.25 -0.15 0.20 0.07 5936971.41 714172.43 N 70.23071868 W 148.27107712 747.07 0.05 216.09 691.40 747.07 -0.11 0.32 0.25 -0.16 0.20 0.07 5936971.40 714172.42 N 70.23071865 W 148.27107717 761.27 0.07 210.83 705.60 761.27 -0.09 0.33 0.25 -0.17 0.19 0.15 5936971.39 714172.41 N 70.23071862 W 148.2710 774.87 0.09 209.87 719.20 774.87 -0.08 0.35 0.26 -0.19 0.18 0.15 5936971.37 714172.40 N 70.23071857 W 148.2710 788.47 0.09 212.84 732.80 788.47 -0.06 0.37 0.26 -0.20 0.17 0.03 5936971.35 714172.39 N 70.23071852 W 148.27107741 802.27 0.10 213.98 746.60 802.27 -0.04 0.39 0.27 -0.22 0.15 0.07 5936971.33 714172.38 N 70.23071847 W 148.27107751 816.07 0.11 217.85 760.40 816.07 -0.02 0.42 028 -0.24 0.14 0.09 5936971.31 714172.37 N 70.23071842 W 148.27107763 829.87 0.10 222.87 774.20 829.87 0.01 0.44 0.29 -026 0.12 0.10 5936971.29 714172.35 N 70.23071836 W 148.27107776 843.87 0.08 220.95 788.20 843.87 0.03 0.47 0.30 -0.28 0.11 0.14 5936971.27 714172.34 N 70.23071832 W 148.27107788 859.97 0.08 213.02 804.30 859.97 0.05 0.49 0.31 -0.30 0.09 0.07 5936971.26 714172.32 N 70.23071827 W 148.27107799 877.22 0.07 208.29 821.55 87722 0.06 0.51 0.33 -0.32 0.08 0.07 593697124 714172.31 N 70.23071822 W 148.27107808 894.47 0.06 199.52 838.80 894.47 0.08 0.53 0.34 -0.33 0.07 0.08 5936971.22 714172.30 N 70.23071817 W 148.27107815 911.57 0.05 186.16 855.90 911.57 0.09 0.55 0.36 -0.35 0.07 0.09 5936971.20 714172.30 N 70.23071812 W 148.27107818 928.77 0.08 174.85 873.10 928.77 0.10 0.57 0.38 -0.37 0.07 0.19 5936971.18 714172.30 N 70.23071807 W 1 48271 0781 7 945.87 0.11 168.36 890.20 945.87 0.11 0.59 0.41 -0.40 0.08 0.19 5936971.15 714172.31 N 70.23071799 W 148.27107814 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 2 of 12 Comments Measured inclination Azimuth SutrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft n n ft ft de 00 ft ftUS ftUS 562.y/ U.12 1 /U.43 5U/.3U y62.9/ U.1L U.63 U.44 -U.43 U.Ut3 U.U6 by36971.1Z 7141 /2.31 N 7U.23U/1 /yU W 148.271U7t3U9 980.02 0.11 177.82 924.35 980.02 0.13 0.66 0.47 -0.47 0.09 0.10 5936971.09 714172.32 N 70.23071781 W 148.27107806 997.07 0.10 184.65 941.40 997.07 0.14 0.69 0.50 -0.50 0.09 0.09 5936971.06 714172.32 N 70.23071772 W 148.27107806 1013.87 0.10 192.66 958.20 1013.87 0.16 0.72 0.53 -0.53 0.08 0.08 5936971.03 714172.32 N 70.23071765 W 148.27107810 1030.47 0.09 204.61 974.80 1030.47 0.18 0.75 0.56 -0.55 0.07 0.13 5936971.00 714172.31 N 70.23071757 W 148.27107817 1047.07 0.09 213.35 991.40 1047.07 0.20 0.78 0.58 -0.57 0.06 0.08 5936970.98 714172.30 N 70.23071751 W 148.27107827 1063.72 0.09 217.56 1008.05 1063.72 0.22 0.80 0.60 -0.60 0.04 0.04 5936970.96 714172.28 N 70.23071745 W 148.27107839 1080.37 0.09 219.62 1024.70 1080.37 0.24 0.83 0.62 -0.62 0.03 0.02 5936970.93 714172.27 N 70.23071740 W 148.27107852 1097.02 0.09 221.08 1041.35 1097.02 0.27 0.86 0.64 -0.64 0.01 0.01 5936970.91 71417225 N 70.23071734 W 148.27107866 1113.57 0.06 229.40 1057.90 1113.57 029 0.88 0.65 -0.65 0.00 0.19 5936970.90 714172.23 N 70.23071730 W 148.27107878 1130.17 0.04 233.50 1074.50 1130.17 0.30 0.89 0.66 -0.66 -0.02 0.12 5936970.89 714172.22 N 70.23071728 W 148.2710 1146.67 0.06 230.76 1091.00 1146.67 0.32 0.91 0.67 -0.67 -0.03 0.12 5936970.88 714172.21 7 N 70.23071725 W 148.2710 1163.17 0.08 229.58 1107.50 1163.17 0.34 0.93 0.68 -0.68 -0.04 0.12 5936970.87 714172.20 N 70.23071722 W 148.27107909 1179.67 0.10 235.85 1124.00 1179.67 0.36 0.95 0.70 -0.70 -0.06 0.13 5936970.85 714172.18 N 70.23071717 W 148.27107926 1196.17 0.13 247.07 1140.50 1196.17 0.40 0.98 0.72 -0.71 -0.09 0.23 5936970.83 714172.15 N 70.23071713 W 148.27107949 1212.57 0.18 254.20 1156.90 1212.57 0.44 1.03 0.74 -0.73 -0.13 0.33 5936970.82 714172.11 N 70.23071709 W 148.27107983 1229.07 0.27 259.39 1173.40 1229.07 0.50 1.09 0.77 -0.74 -0.20 0.56 5936970.80 714172.04 N 70.23071706 W 148.27108034 1246.37 0.35 265.73 1190.70 1246.37 0.59 1.19 0.81 -0.75 -0.29 0.50 5936970.79 714171.95 N 70.23071702 W 148.27108109 1263.87 0.39 272.47 1208.20 1263.87 0.69 1.30 0.86 -0.75 -0.40 0.34 5936970.78 714171.84 N 70.23071702 W 148.27108200 1281.27 0.42 276.61 1225.60 1281.27 0.80 1.42 0.91 -0.75 -0.53 0.24 5936970.79 714171.72 N 70.23071705 W 148.27108299 1298.77 0.43 279.55 1243.10 1298.77 0.91 1.55 0.98 -0.73 -0.65 0.14 5936970.81 714171.59 N 7023071710 W 148.27108403 1316.17 0.44 282.21 1260.50 1316.17 1.01 1.68 1.05 -0.70 -0.78 0.13 5936970.83 714171.46 N 70.23071717 W 148.27108507 1333.62 0.47 284.63 1277.95 1333.62 1.12 1.82 1.14 -0.67 -0.92 0.20 5936970.85 714171.32 N 70.23071725 W 148.27108616 1351.07 0.48 285.93 1295.40 1351.07 1.23 1.97 1.23 -0.63 -1.06 0.08 5936970.89 714171.18 N 70.23071736 W 148.27108729 1368.42 0.48 286.13 1312.75 1368.42 1.34 2.11 1.34 -0.59 -1.20 0.01 5936970.93 714171.04 N 70.23071747 W 148.27108841 1385.77 0.45 286.54 1330.09 1385.76 1.44 2.25 1.44 -0.55 -1.33 0.17 5936970.96 714170.90 N 70.23071758 W 148.27108950 1403.07 0.44 287.13 1347.39 1403.06 1.54 2.39 1.55 -0.51 -1.46 0.06 5936971.00 714170.77 N 70.23071768 W 148.27109054 1420.27 0.40 287.87 1364.59 1420.26 1.63 2.51 1.65 -0.47 -1.58 0.23 5936971.03 714170.65 N 70.23071779 W 148.27109151 1436.87 0.31 289.45 1381.19 1436.86 1.70 2.62 1.74 -0.44 -1.68 0.55 5936971.06 714170.55 N 70.23071787 W 148.2710 1453.42 0.20 292.99 1397.74 1453.41 1.75 2.69 1.80 -0.42 -1.75 0.67 5936971.08 714170.49 N 70.23071795 W 148.2710 1470.17 0.15 29625 1414.49 1470.16 1.79 2.74 1.84 -0.39 -1.79 0.30 5936971.10 714170.44 N 70.23071800 W 148.27109323 1486.87 0.13 304.23 1431.19 1486.86 1.81 2.78 1.87 -0.37 -1.83 0.17 5936971.12 714170.40 N 70.23071806 W 148.27109352 1503.57 0.13 316.73 1447.89 1503.56 1.82 2.82 1.89 -0.35 -1.86 0.17 5936971.15 714170.37 N 70.23071813 W 148.27109375 1520.32 0.16 330.12 1464.64 1520.31 1.83 2.86 1.91 -0.32 -1.88 0.27 5936971.18 714170.35 N 70.23071822 W 148.27109395 1537.07 0.20 344.56 1481.39 1537.06 1.83 2.92 1.92 -0.27 -1.90 0.36 5936971.23 714170.33 N 70.23071835 W 148.27109410 1553.87 0.27 356.72 1498.19 1553.86 1.81 2.98 1.92 -0.20 -1.91 0.51 5936971.30 714170.31 N 70.23071854 W 148.27109418 1570.67 0.36 7.98 1514.99 1570.66 1.76 3.08 1.91 -0.11 -1.91 0.65 5936971.39 714170.32 N 70.23071879 W 148.27109414 1587.47 0.45 17.52 1531.79 1587.46 1.69 3.19 1.88 0.01 -1.88 0.67 5936971.50 714170.34 N 70.23071910 W 148.27109392 1604.27 0.56 24.08 1548.59 1604.26 1.58 3.34 1.83 0.15 -1.83 0.74 5936971.64 714170.39 N 7023071948 W 148.27109349 1620.97 0.65 29.37 1565.29 1620.96 1.44 3.52 1.77 0.30 -1.75 0.63 5936971.80 714170.47 N 70.23071991 W 148.27109285 1637.67 0.73 33.76 1581.99 1637.66 1.27 3.72 1.71 0.47 -1.64 0.57 5936971.98 714170.57 N 70.23072038 W 148.27109200 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 3 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de n n n n n n n de 00 n nUS ttUS 1654.52 0.84 36.95 1598.84 1654.51 1.06 3.95 1.65 0.66 -1.51 0.70 5936972.17 714170.69 N 70.23072089 W 148.27109092 1671.37 0.93 40.19 1615.69 1671.36 0.83 4.21 1.60 0.86 -1.34 0.61 5936972.38 714170.85 N 70.23072144 W 148.27108960 1688.17 1.00 42.93 1632.48 1688.15 0.57 4.49 1.58 1.08 -1,16 0.50 5936972.59 714171.03 N 70.23072202 W 148.27108809 1704.97 1.08 44.47 1649.28 1704.95 0.28 4.80 1.60 1.30 -0.95 0.50 5936972.82 714171.24 N 70.23072262 W 148.27108639 1721.77 1.13 45.70 1666.08 1721.75 -0.02 5.12 1.68 1.52 -0.72 0.33 5936973.05 714171.46 N 70.23072325 W 148.27108454 1738.57 1.15 46.45 1682.87 1738.54 -0.34 5.46 1.82 1.76 -0.48 0.15 5936973.29 714171.69 N 70.23072388 W 148.27108259 1755.37 1.18 46.35 1699.67 1755.34 -0.67 5.80 2.01 1.99 -0,23 0.18 5936973.53 714171.93 N 70.23072452 W 148.27108060 1772.07 1.22 45.76 1716.37 1772.04 -1.00 6.15 2.24 2.23 0.02 0.25 5936973.78 714172.18 N 70.23072519 W 148.27107856 1788.87 1.27 44.56 1733.16 1788.83 -1.35 6.51 2.51 2.49 0.28 0.34 5936974.05 714172.43 N 70.23072589 W 148.27107648 1805.42 1.30 42.70 1749.71 1805.38 -1.69 6.88 2.81 2.76 0.54 0.31 5936974.33 714172.68 N 70.23072663 W 148.27107441 1821.77 1.33 40.03 1766.05 1821.72 -2.04 7.26 3.14 3.04 0.79 0.42 5936974.61 714172.92 N 70.23072739 W 148.2710 1838.17 1.37 37.21 1782.45 1838.12 -2.39 7.65 3.50 3.34 1.03 0.47 5936974.92 714173.15 N 70.23072822 W 148.2710 1854.77 1.38 35.22 1799.05 1854.72 -2.74 8.04 3.88 3.67 126 0.29 5936975.25 714173.38 N 70.23072910 W 148.27106857 1871.62 1.39 34.04 1815.89 1871.56 -3.10 8.45 4.27 4.00 1.49 0.18 5936975.59 714173.60 N 70.23073001 W 148.27106670 1888.47 1.39 33.32 1832.74 1888.41 -3.45 8.86 4.67 4.34 1.72 0.10 5936975.94 714173.82 N 70.23073094 W 148.27106487 1905.27 1.37 33.27 1849.53 1905.20 -3.80 9.26 5.07 4.68 1.94 0.12 5936976.28 714174.03 N 70.23073187 W 148.27106308 1922.07 1.35 33.78 1866.33 1922.00 -4.14 9.66 5.46 5.01 2.16 0.14 5936976.62 714174.24 N 70.23073277 W 148.27106130 1938.87 1.35 34.30 1883.12 1938.79 -4.48 10.06 5.85 5.34 2.38 0.07 5936976.95 714174.45 N 70.23073367 W 148.27105951 1955.77 1.34 36.48 1900.02 1955.69 -4.83 10.46 6.24 5.66 2.61 0.31 5936977.28 714174.67 N 70.23073455 W 148.27105766 1972.67 1.33 39.29 1916.91 1972.58 -5.19 10.85 6.62 5.97 2.86 0.39 5936977.60 714174.90 N 70.23073540 W 148.27105571 1989.52 1.33 40.41 1933.76 1989.43 -5.54 11.24 7.00 6.27 3.11 0.15 5936977.91 714175.15 N 70.23073622 W 148.27105368 2006.37 1.33 40.59 1950.60 2006.27 -5.90 11.63 7.38 6.57 3.36 0.02 5936978.21 714175.39 N 70.23073703 W 14827105163 2023.27 1.34 40.76 1967.50 2023.17 -6.26 12.02 7.76 6.87 3.62 0.06 5936978.52 714175.64 N 70.23073785 W 148.27104956 2040.22 1.35 41.51 1984.44 2040.11 -6.63 12.42 8.15 7.17 3.88 0.12 5936978.83 714175.89 N 70.23073867 W 148.27104745 2057.27 1.36 42.16 2001.49 2057.16 -7.00 12.83 8.54 7.47 4.15 0.11 5936979.13 714176.15 N 70.23073949 W 148.27104528 2074.42 1.38 42.80 2018.63 2074.30 -7.38 13.24 8.94 7.77 4.42 0.15 5936979.44 714176.42 N 70.23074032 W 148.27104305 2091.57 1.46 44.12 2035.78 2091.45 -7.78 13.66 9.36 8.08 4.72 0.50 5936979.76 714176.70 N 70.23074116 W 148.27104069 2108.77 1.59 46.49 2052.97 2108.64 -8.22 14.12 9.80 8.40 5.04 0.84 5936980.09 714177.02 N 70.23074204 W 148.27103806 2125.87 1.75 50.24 2070.07 2125.74 -8.70 14.62 10.28 8.73 5.41 1.13 5936980.43 714177.38 N 70.23074294 W 148.2710 2143.07 1.98 54.29 2087.26 2142.93 -9.24 15.18 10.80 9.07 5.86 1.54 5936980.79 714177.82 N 70.23074387 W 148.2710 2160.17 2.24 57.61 2104.34 2160.01 -9.87 15.81 11.38 9.43 6.38 1.68 5936981.15 714178.33 N 70.23074483 W 148.27102726 2177.27 2.61 61.34 2121.43 2177.10 -10.59 16.53 12.04 9.79 7.00 2.35 5936981.54 714178.94 N 70.23074583 W 148.27102222 2194.27 2.98 65.48 2138.41 2194.08 -11.42 17.36 12.78 10.16 7.75 2.48 5936981.93 714179.67 N 70.23074684 W 148.27101624 2211.27 3.31 69.00 2155.38 2211.05 -12.35 18.29 13.59 10.52 8.61 225 5936982.31 714180.52 N 70.23074782 W 148.27100929 2228.17 3.64 71.60 2172.25 2227.92 -13.36 19.31 14.48 10.86 9.57 2.16 5936982.68 714181.48 N 70.23074876 W 148.27100151 2245.22 4.02 73.94 2189.26 2244.93 -14.49 20.45 15.46 11.20 10.66 2.41 5936983.05 714182.56 N 70.23074968 W 148.27099273 2261.77 4.45 75.67 2205.77 2261.44 -15.69 21.68 16.52 11.52 11.84 2.71 5936983.40 714183.73 N 70.23075055 W 148.27098321 2277.77 4.92 76.38 2221.72 2277.39 -16.97 22.98 17.66 11.83 13.11 2.96 5936983.75 714184.98 N 70.23075141 W 148.27097297 2293.97 5.47 76.91 2237.85 2293.52 -18.40 24.45 18.96 12.17 14.53 3.41 5936984.13 714186.40 N 70.23075234 W 148.27096146 2310.47 5.98 77.16 2254.27 2309.94 -20.00 26.09 20.44 12.54 16.14 3.09 5936984.54 714187.99 N 70.23075335 W 148.27094851 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 4 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de n n ft ft ft ft n de oo ft ftUS nUS L3L/.1 / Ei.425 //.1(i "L"L/U .tS/ 1:iLti .b4 -Ll.// L/.yl LL.Uy 1L .y4 1 / .yU "L.yy SyiliytSb.UU /141LSy./5 N /U.L3U/5445 W 1425."L/Uyi4Lb 2343.77 7. 02 77 .22 2287 .35 2343 .02 -23.67 29.86 23.90 13 .38 19 .81 3.25 5936985.48 714191.64 N 70.23075563 W 148.27091889 2360.42 7. 70 77. 66 2303 .87 2359 .54 -25.74 31.99 25.90 13. 84 21. 89 4.10 5936986.01 714193.71 N 70.23075689 W 148.27090209 2377.07 8. 44 78. 45 2320 .35 2376 .02 -28.01 34.33 28.10 14. 32 24. 18 4.49 5936986.55 714195.98 N 70.23075821 W 148.27088363 2393.67 9. 10 79. 26 2336 .76 2392 .43 -30.45 36.86 30.50 14. 81 26. 66 4.04 5936987.11 714198.45 N 70.23075955 W 148.27086359 2410.22 9. 71 80. 10 2353 .08 2408 .75 -33.06 39.56 33.07 15. 30 29. 32 3.78 5936987.67 714201.09 N 70.23076087 W 148.27084212 2426.77 10. 23 80 .81 2369 .38 2425 .05 -35.81 42.43 35.81 15. 77 32. 15 3.23 5936988.23 714203.90 N 70.23076217 W 148.27081931 2443.47 10. 74 81. 50 2385. 80 2441. 47 -38.71 45.47 38.72 16. 24 35. 15 3.15 5936988.78 714206.89 N 70.23076344 W 148.27079508 2460.22 11. 19 82. 36 2402. 25 2457. 92 -41.74 48.65 41.78 16. 68 38. 30 2.86 5936989.31 714210.03 N 70.23076466 W 148.27076962 2476.97 11. 56 83. 07 2418. 67 2474. 34 -44.87 51.96 44.96 17. 10 41. 58 2.36 5936989.83 714213.30 N 70.23076581 W 148.27074317 2493.77 11. 90 83. 45 2435. 12 2490. 79 -48.09 55.37 48.26 17. 50 44. 97 2.08 5936990.32 714216.67 N 70.23076690 W 148.270715 9 2510.47 12. 22 83. 65 2451. 45 2507 .12 -51.38 58.86 51.64 17. 90 48. 44 1.93 5936990.81 714220.13 N 70.23076797 W 148.2706 2527.27 12. 53 83. 86 2467. 86 2523. 53 -54.77 62.46 55.14 18. 29 52. 02 1.86 5936991.31 714223.69 N 70.23076904 W 148.2706 2541.37 12. 70 84. 02 2481. 62 2537. 29 -57.66 65.54 58.14 18. 61 55. 08 1.23 5936991.72 714226.75 N 70.23076993 W 148.27063421 2542.87 12. 72 84. 03 2483. 08 2538. 75 -57.97 65.87 58.46 18. 65 55. 41 1.34 5936991.76 714227.07 N 70.23077002 W 148.27063156 2561.52 13. 04 84. 01 2501. 26 2556. 93 -61.88 70.03 62.52 19. 08 59. 54 1.72 5936992.31 714231.19 N 70.23077121 W 148.27059819 2585.87 13. 35 83. 97 2524. 97 2580. 64 -67.10 75.59 67.98 19. 66 65. 07 1.27 5936993.05 714236.70 N 70.23077280 W 148.27055358 2613.67 13. 88 83. 80 2551. 99 2607. 66 -73.26 82.13 74.42 20. 36 71. 58 1.91 5936993.93 714243.19 N 70.23077470 W 148.27050106 2642.12 14. 74 83. 40 2579. 56 2635. 23 -79.88 89.16 81.36 21. 14 78. 57 3.04 5936994.91 714250.15 N 70.23077684 W 148.27044467 2670.67 15. 73 82. 76 2607. 10 2662. 77 -86.97 96.67 88.79 22. 05 86. 01 3.52 5936996.03 714257.57 N 70.23077932 W 148.27038456 2699.17 16. 57 82. 13 2634. 48 2690. 15 -94.49 104.59 96.67 23. 09 93. 87 3.01 5936997.30 714265.39 N 70.23078217 W 148.27032114 2727.67 17. 22 81. 72 2661. 75 2717. 42 -102.37 112.88 104.91 24. 26 102. 07 2.32 5936998.69 714273.56 N 70.23078535 W 148.27025495 2756.17 17. 94 81. 42 2688. 92 2744. 59 -110.58 121.48 113.49 25. 52 110. 59 2.55 5937000.20 714282.03 N 70.23078880 W 148.27018623 2784.67 18. 89 81. 12 2715. 96 2771. 63 -119.18 130.49 122.47 26. 89 119. 48 3.35 5937001.82 714290.89 N 70.23079253 W 148.27011441 2813.07 19. 83 80. 91 2742. 75 2798. 42 -128.18 139.90 131.87 28. 36 128. 78 3.32 5937003.55 714300.14 N 70.23079655 W 148.27003936 2841.57 20. 55 80. 79 2769. 50 2825. 17 -137.59 149.74 141.69 29. 92 138. 49 2.53 5937005.39 714309.80 N 70.23080082 W 148.26996099 2870.17 21. 25 80. 56 2796. 22 2851. 89 -147.37 159.94 151.88 31. 57 148. 56 2.46 5937007.33 714319.82 N 70.23080534 W 148.26987973 2898.57 22. 19 80. 13 2822. 60 2878. 27 -157.45 170.45 162.38 33. 34 158. 92 3.36 5937009.38 714330.12 N 70.23081015 W 148.26979611 2926.82 23. 18 79. 70 2848. 67 2904. 34 -167.93 181.34 173.27 35. 25 169. 65 3.55 5937011.60 714340.79 N 70.23081537 W 148.26970954 2954.97 23. 98 79. 54 2874. 46 2930. 13 -178.78 192.60 184.53 37. 28 180. 73 2.85 5937013.94 714351.81 N 70.23082091 W 148.2696 2983.37 24. 68 79. 52 2900. 34 2956. 01 -190.05 204.31 196.23 39. 40 192. 23 2.46 5937016.39 714363.25 N 70.23082672 W 148,26952728 3011.77 25. 52 79. 49 2926. 06 2981. 73 -201.66 216.35 208.27 41. 60 204. 08 2.96 5937018.92 714375.02 N 70.23083271 W 148,26943168 3040.17 26. 53 79. 57 2951. 58 3007. 25 -213.66 228.81 220.73 43. 86 216. 33 3.56 5937021.53 714387.21 N 70.23083890 W 14826933278 3068.57 27. 46 79. 69 2976. 89 3032. 56 -226.08 241.70 233.62 46. 18 229. 01 3.28 5937024.21 714399.82 N 70.23084524 W 148,26923044 3096.97 28. 04 79. 79 3002. 02 3057. 69 -238.81 254.93 246.84 48. 54 242. 02 2.05 5937026.94 714412.75 N 70.23085167 W 148.26912542 3125.17 28. 43 79. 81 3026. 86 3082 .53 -251.64 26827 260.18 50. 90 255. 15 1.38 5937029.67 714425.81 N 70.23085812 W 148.26901945 3153.47 28. 81 79. 79 3051. 71 3107. 38 -264.69 281.82 273.73 53. 30 268. 49 1.34 5937032.45 714439.08 N 70.23086468 W 148.26891177 3184.57 29. 35 79. 63 3078. 89 3134. 56 -279.24 296.94 288.85 56. 00 283. 37 1.75 5937035.57 714453.87 N 70.23087205 W 148.26879174 3217.67 30. 19 79. 39 3107. 62 3163. 29 -295.07 313.37 305.28 58. 99 299. 53 2.56 5937039.02 714469.94 N 70.23088023 W 148.26866131 3250.27 31. 12 79. 25 3135. 66 3191. 33 -311.10 330.00 321.90 62. 07 315. 86 2.86 5937042.56 714486.17 N 70.23088864 W 148.26852949 3282.47 32.10 79.12 3163.08 3218.75 -327.39 346.87 338.78 65.24 332.44 3.05 5937046.20 714502.65 N 70.23089729 W 148.26839569 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 5 of 12 Comments Measured Inclination Azimuth Sub-Sea ND NO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft n n tt ft ft ft de 100 ft nUS ftUS :1314.5/ :13.15 /t5.y/ :ilyU.lU :iL4b.// -:144.1;1 :i1i4.1U :1511.11 fikS.S~ ;i4y.4b :i.by byi/U4y.y/ /1451y.b/ N /U. L:3UyU(iL`J W 1415."Lt5i5"L525Jt1 3346.72 34.33 78.87 3216.82 3272 .49 -361 .40 382.08 373.99 71.97 367.00 3.36 5937053.91 714537.01 N 70. 23091567 W 148.26811676 3378.67 35.29 78.76 3243.05 3298 .72 -379 .04 400.32 392.23 75.51 384.89 3.01 5937057.95 714554.79 N 70. 23092534 W 148.26797235 3410.22 36.09 78.71 3268.68 3324 .35 -396. 84 418.73 410.63 79.10 402.94 2.54 5937062.06 714572.73 N 70. 23093516 W 148.26782666 3441.87 36.90 78.83 3294.12 3349. 79 -415. 04 437.55 429.46 82.77 421.40 2.57 5937066.25 714591.08 N 70. 23094517 W 148.26767764 3473.57 38.01 78.96 3319.29 3374. 96 -433. 67 456.83 448.73 86.48 440.32 3.51 5937070.49 714609.89 N 70. 23095531 W 148.26752496 3505.17 39.16 79.02 3343.99 3399. 66 -452. 71 476.54 468.44 90.24 459.67 3.64 5937074.81 714629.12 N 70. 23096559 W 148.26736883 3536.82 40.12 79.06 3368.36 3424. 03 -472. 21 496.73 488.63 94.08 479.49 3.03 5937079.21 714648.82 N 70. 23097607 W 148.26720884 3568.37 40.88 79.10 3392.35 3448. 02 -491. 99 517.22 509.12 97.97 499.61 2.41 5937083.66 714668.82 N 70. 23098667 W 148.26704646 3599.67 41.67 79.13 3415.87 3471. 54 -511. 92 537.87 529.77 101.86 519.88 2.52 5937088.13 714688.98 N 70. 23099732 W 148.26688281 3630.97 42.85 79.19 3439.04 3494. 71 -532. 24 558.91 550.82 105.82 540.56 3.77 5937092.67 714709.53 N 70. 23100813 W 148.2667 3662.37 44.08 79.27 3461.83 3517. 50 -553. 08 580.51 572.42 109.86 561.78 3.92 5937097.31 714730.62 N 70. 1 23101915 W 148.2665 3693.87 44.89 79.38 3484.30 3539. 97 -574. 37 602.59 594.49 113.95 583.47 2.58 5937102.01 714752.19 N 70. 23103032 W 148.2663 3725.37 45.49 79.52 3506.50 3562. 17 -595. 91 624.93 616.84 118.04 605.44 1.93 5937106.73 714774.03 N 70. 23104149 W 148.26619231 3756.77 46.12 79.66 3528.39 3584. 06 -617. 59 647.45 639.35 122.11 627.58 2.03 5937111.42 714796.05 N 70. 23105260 W 148.26601359 3788.57 46.96 79.87 3550.26 3605. 93 -639. 81 670.53 662.43 126.21 650.29 2.68 5937116.16 714818.64 N 70. 23106380 W 148.26583026 3821.27 47.73 80.10 3572.42 3628. 09 -662. 93 694.58 686.47 130.39 673.98 2.41 5937121.02 714842.19 N 70. 23107522 W 148.26563912 3853.87 48.21 80.34 3594.24 3649. 91 -686. 18 718.79 710.68 134.50 697.84 1.57 5937125.81 714865.92 N 70. 23108645 W 148.26544652 3886.57 48.64 80.57 3615.94 3671. 61 -709. 64 743.26 735.14 138.56 721.96 1.42 5937130.54 714889.92 N 70. 23109752 W 148.26525181 3919.27 49.02 80.72 3637.47 3693. 14 -733. 22 767.87 759.75 142.56 746.25 1.21 5937135.23 714914.09 N 70. 23110845 W 148.26505579 3951.67 49.38 80.85 3658.64 3714. 31 -756. 70 792.40 784.26 146.49 770.46 1.15 5937139.85 714938.17 N 70. 23111917 W 148.26486038 3983.97 49.73 80.94 3679.60 3735. 27 -780. 22 816.98 808.84 150.38 794.73 1.10 5937144.42 714962.32 N 70. 23112979 W 148.26466449 4016.27 49.97 80.99 3700.42 3756. 09 -803. 84 841.67 833.51 154.25 819.12 0.75 5937148.99 714986.58 N 70. 23114038 W 148.26446769 4048.67 49.95 81.19 3721.27 3776. 94 -827. 55 866.47 858.31 158.10 843.62 0.48 5937153.53 715010.97 N 70. 23115086 W 148.26426990 4081.07 49.73 81.55 3742.16 3797. 83 -851. 18 891.23 883.05 161.81 868.10 1.09 5937157.94 715035.34 N 70. 23116101 W 148.26407231 4113.57 49.57 81.91 3763.20 3818. 87 -874. 77 916.00 907.80 165.37 892.61 0.98 5937162.19 715059.73 N 70. 23117073 W 148.26387448 4145.67 49.32 82.40 3784.07 3839. 74 -897. 95 940.39 932.17 168.70 916.77 1.40 5937166.21 715083.79 N 70. 23117982 W 148.26367948 4177.57 49.15 82.88 3804.90 3860. 57 -920. 84 964.55 956.29 171.80 940.74 1.26 5937169.98 715107.65 N 70. 23118827 W 148.26348608 4209.37 49.09 83.16 3825.72 3881. 39 -943. 57 988.60 980.30 174.72 964.60 0.69 5937173.58 715131.42 N 70. 23119624 W 148.26329347 4241.17 49.05 83.37 3846.55 3902. 22 -966. 25 1012.62 1004.28 177.54 988.46 0.51 5937177.07 715155.19 N 70. 23120393 W 148.2631 4272.87 49.12 83.49 3867.31 3922. 98 -988. 84 1036.58 1028.19 180.28 1012.26 0.36 5937180.49 715178.90 N 70. 23121141 W 148.26290882 4304.37 49.19 83.49 3887.91 3943. 58 -1011. 30 1060.40 1051.97 182.98 1035.93 0.22 5937183.86 715202.49 N 70. 23121878 W 148.26271773 4335.97 49.24 83.19 3908.55 3964. 22 -1033. 88 1084.33 1075.86 185.76 1059.70 0.74 5937187.31 715226.16 N 70. 23122635 W 148.26252592 4367.57 49.38 82.63 3929.16 3984. 83 -1056. 55 1108.29 1099.79 188.71 1083.48 1.41 5937190.94 715249.85 N 70. 23123442 W 148.26233401 4399.27 49.55 82.21 3949.76 4005. 43 -1079. 41 1132.38 1123.86 191.89 1107.36 1.14 5937194.80 715273.63 N 70. 23124310 W 148.26214126 4430.87 49.68 82.05 3970.23 4025. 90 -1102. 28 1156.45 1147.92 195.19 1131.20 0.56 5937198.77 715297.37 N 70. 23125209 W 148.26194882 4462.47 49.94 81.97 3990.63 4046 .30 -1125 .24 1180.59 1172.04 198.54 1155.11 0.85 5937202.80 715321.17 N 70. 23126125 W 148.26175587 4493.97 50.44 81.61 4010.79 4066 .46 -1148 .28 1204.79 1196.23 202.00 1179.05 1.81 5937206.93 715345.01 N 70. 23127068 W 148.26156257 4525.47 51.05 81.08 4030.73 4086. 40 -1171. 56 1229.18 1220.62 205.67 1203.17 2.33 5937211.29 715369.00 N 70. 23128070 W 148.26136795 4556.97 51.52 80.88 4050.43 4106. 10 -1195. 07 1253.76 1245.20 209.52 1227.44 1.57 5937215.83 715393.16 N 70. 23129122 W 148.26117203 4588.47 51.75 80.92 4069.98 4125. 65 -1218. 70 1278.46 1269.89 213.43 1251.83 0.74 5937220.43 715417.42 N 70. 23130188 W 148.26097519 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 6 of 12 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft n n ft ft de 100 ft ftUS ttUS 4fily.// 51.// tS1. U25 4UtSy. :~b 4145.01 -1141.L7 1;iU:i.U4 1Ly4.4ti 11/.Lt3 11/(i.ll 0.41 by:~/'L14.yli /1b441.5t5 N /U.L;fl:ilL~/ W 14t3.1tiU//yLl 4650.97 51.67 81. 37 4108. 68 4164.35 -1265 .60 1327.53 1318.97 221.01 1300. 32 0.80 5937229.38 715465.67 N 70. 23132257 W 148.26058384 4682.07 51.53 81. 81 4128. 00 4183.67 -1288 .84 1351.91 1343.33 224.58 1324. 43 1.20 5937233.63 715489.67 N 70. 23133229 W 148.26038924 4713.37 51.47 82. 30 4147. 48 4203.15 -1312 .12 1376.40 1367.82 227.96 1348. 69 1.24 5937237.70 715513.82 N 70. 23134153 W 148.26019343 Tie in Survey 4744.67 51.61 82. 64 4166. 95 4222.62 -1335 .37 1400.91 1392.31 231.17 1372. 99 0.00 5937241.60 715538.02 N 70. 23135030 W 148.25999731 Inc+Trend 4756.00 51.66 82. 70 4173. 98 4229.65 -1343 .79 1409.80 1401.19 232.31 1381. 80 0.61 5937242.98 715546.79 N 70. 23135339 W 148.25992620 4773.00 52.70 80. 45 4184. 41 4240.08 -1356 .59 1423.22 1414.61 234.28 1395. 08 12.11 5937245.33 715560.01 N 70. 23135876 W 148.25981900 4787.24 52.65 80. 45 4193. 04 4248.71 -1367 .45 1434.55 1425.94 236.16 1406. 25 0.35 5937247.53 715571.12 N 70. 23136389 W 148.25972887 4817.21 53.00 78. 80 4211. 15 4266.82 -1390. 44 1458.43 1449.81 240.46 1429. 73 4.54 5937252.49 715594.48 N 70. 23137562 W 14825953929 4909.28 49.01 75. 80 4269. 08 4324.75 -1460. 04 1529.96 1521.24 256.13 1499. 52 5.02 5937270.14 715663.79 N 70. 23141841 W 148.25897599 Last Inc+Trend 5003.97 47.11 69. 70 4332. 40 4388.07 -1529. 58 1600.36 1591.03 276.94 1566. 74 5.19 5937292.85 715730.39 N 70. 23147523 W 148.258433 First MWD+IFR+MS 5098.12 47.14 63. 04 4396. 50 4452.17 -1598 .45 1669.33 1658.10 304.57 1629. 89 5.18 5937322.26 715792.72 N 70. 23155067 W 148.2579 5190.92 44.59 61. 81 4461. 12 4516.79 -1665 .02 1735.92 1721.90 335.38 1688. 92 2.91 5937354.74 715850.85 N 70. 23163482 W 148.2574 5288.97 41.87 62. 85 4532. 55 4588.22 -1732 .14 1803.07 1786.40 366.58 1748. 38 2.87 5937387.61 715909.40 N 70 23172000 W 148.25696720 5382.63 39.74 65. 93 4603. 45 4659.12 -1793 .32 1864.26 1845.88 393.06 1803. 54 3.13 5937415.64 715963.79 N 70. 23179231 W 148.25652194 5475.37 37.00 68. 81 4676. 16 4731.83 -1850. 77 1921.82 1902.51 415.24 1856. 65 3.53 5937439.32 716016.23 N 70. 23185288 W 148.25609331 5569.59 34.66 68. 67 4752. 54 4808.21 -1905. 73 1976.97 1957.05 435.24 1908. 04 2.49 5937460.77 716067.04 N 70. 23190747 W 148.25567842 5663.39 32.95 71. 49 4830. 48 4886.15 -1957. 62 2029.15 2008.84 453.04 1957. 08 2.47 5937479.95 716115.56 N 70. 23195607 W 148.25528256 5758.30 29.38 71. 19 4911. 68 4967.35 -2006. 32 2078.26 2057.72 468.75 2003. 61 3.77 5937496.97 716161.62 N 70. 23199895 W 148.25490697 5852.22 25.72 67. 15 4994. 95 5050.62 -2049. 55 2121.67 2100.76 484.10 2044. 22 4.37 5937513.47 716201.77 N 70. 23204085 W 148.25457920 5863.52 25.27 66. 78 5005. 15 5060.82 -2054. 40 2126.54 2105.55 486.00 2048. 70 4.22 5937515.50 716206.19 N 70. 23204604 W 148.25454307 5957.18 23.33 63. 95 5090. 51 5146.18 -2092. 92 2165.07 2143.36 502.03 2083. 73 2.42 5937532.51 716240.76 N 70. 23208981 W 148.25426023 6051.21 18.06 64. 53 5178. 44 5234.11 -2126 .14 2198.29 2175.83 516.48 2113. 64 5.61 5937547.81 716270.24 N 70. 23212927 W 148.25401880 6146.23 14.40 66. 34 5269. 66 5325.33 -2152. 68 2224.84 2201.90 527.56 2137. 77 3.89 5937559.57 716294.04 N 70. 23215952 W 148.25382403 6240.28 10.58 67. 79 5361. 47 5417.14 -2172. 99 2245.18 2221.98 535.52 2156. 48 4.08 5937568.06 716312.52 N 70. 23218125 W 148.25367298 6334.90 6.16 70. 50 5455. 05 5510.72 -2186. 71 2258.94 2235.64 540.50 2169. 31 4.69 5937573.40 716325.21 N 70. 23219485 W 148.25356939 6428.81 1.74 71. 24 5548. 72 5604.39 -2193. 13 2265.41 2242.08 542.64 2175. 42 4.71 5937575.71 716331.24 N 70. 23220070 W 148.25352012 6523.19 2.16 244. 84 5643. 08 5698.75 -2192 .77 2267.05 2241.76 542.35 2175. 16 4.13 5937575.41 716331.00 N 70. 23219989 W 148.25352217 6617.79 5.25 248. 44 5737. 47 5793.14 -2186 .68 2273.16 2235.72 540.00 2169. 52 3.27 5937572.90 716325.43 N 70. 23219348 W 148.2535 6655.38 6.06 250. 93 5774. 88 5830.55 -2182 .99 2276.87 2232.04 538.72 2166. 05 2.25 5937571.53 716321.99 N 70. 23218998 W 148.2535 6709.75 8.19 248. 73 5828. 82 5884.49 -2176. 28 2283.61 2225.34 536.38 2159. 73 3.95 5937569.00 716315.74 N 70. 23218359 W 148.25364678 6804.37 11.88 240. 42 5921. 99 5977.66 -2159. 84 2300.07 2209.27 529.12 2144. 97 4.18 5937561.33 716301.20 N 70. 23216378 W 148.25376590 6899.24 14.97 234. 04 6014. 26 6069.93 -2138. 02 2322.07 2188.52 517.10 2126. 55 3.61 5937548.80 716283.13 N 70. 23213095 W 148.25391457 6994.40 18.16 235. 99 6105. 46 6161.13 -2111 .22 2349.19 2163.26 501.59 2104. 31 3.40 5937532.66 716261.33 N 70. 23208858 W 148.25409417 7087.44 21.24 241. 63 6193. 05 6248.72 -2080 .01 2380.53 2133.42 485.46 2077. 45 3.89 5937515.78 716234.95 N 70. 23204456 W 148.25431097 7181.75 26.50 242. 70 6279 .26 6334.93 -2041 .88 2418.68 2096.53 467.68 2043. 70 5.60 5937497.05 716201.71 N 70. 23199601 W 148.25458343 7276.71 29.66 245 .52 6363 .04 6418.71 -1997 .20 2463.37 2053.00 448.22 2003. 48 3.61 5937476.45 716162.06 N 70. 23194288 W 148.25490811 7371.27 34.97 245. 08 6442 .92 6498.59 -1946 .68 2513.90 2003.63 427.10 1957. 58 5.62 5937454.03 716116.78 N 70. 23188519 W 148.25527864 7464.89 40.38 244. 26 6517. 00 6572.67 -1889 .49 2571.09 1947.95 402.60 1905. 89 5.80 5937428.08 716065.82 N 70. 23181831 W 148.25569587 7559.25 44.17 244. 08 6586. 80 6642.47 -1826 .03 2634.56 1886.41 374.95 1848. 77 4.02 5937398.82 716009.50 N 70. 23174280 W 148.25615697 7652.39 49.73 244. 59 6650. 36 6706.03 -1757 .99 2702.59 1820.52 345.49 1787. 44 5.98 5937367.64 715949.04 N 70. 23166237 W 14825665202 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 7 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft it ft ft ft ft ft de 100 ft ftUS ftUS //4fi.5Ei 4y.:i5 L4'L.LU Ei/11.4/ ti/(i/.14 -1titSEi.36 L//4.24 1/51.(15 ;11;1.41 1/Z:3.:itt l.y/ by:i/~;i:3./5 /1bt3tSb.yL N /U.L:i15/4// W 14tf.L5/1tiyUy 7839.71 50.94 237.23 6771.19 6826. 86 -1615.09 2845.73 1684.67 277.34 1661.69 4.44 5937295.95 715825.28 N 70.23147627 W 148.25766710 7934.27 49.69 237,38 6831.57 6887. 24 -1542.82 2918.50 1618.05 238.04 1600.45 1.33 5937254.92 715765.19 N 70.23136892 W 148.25816143 8028.10 47.97 236.24 6893.34 6949. 01 -1472.75 2989.12 1554.18 199.38 1541.34 2.05 5937214.60 715707.20 N 70.23126335 W 148.25863857 8121.44 49.63 235,84 6954.82 7010. 49 -1403.20 3059.35 1491.71 160.15 1483.09 1.81 5937173.73 715650.09 N 70.23115620 W 148.25910875 8215.66 47.63 235.86 7017.08 7072. 75 -1333.21 3130.06 1429.66 120.46 1424.58 2.12 5937132.40 715592.73 N 70.23104780 W 148.25958106 8310.03 48.28 236.21 7080.28 7135. 95 -1263.80 3200.14 1368.87 81.31 1366.46 0.74 5937091.62 715535.75 N 70.23094087 W 148.26005023 8404.37 48.06 236.24 7143.20 7198. 87 -1194.16 3270.43 1308.71 42,23 1308.02 0.23 5937050.89 715478.45 N 70.23083413 W 148.26052188 8498.23 48.12 236.93 7205.90 7261. 57 -1124.89 3340.28 1249.73 3.76 1249.72 0.55 5937010.79 715421.27 N 70.23072907 W 148.26099249 8591.59 48.52 237.30 7267.98 7323. 65 -1055.67 3410.01 1191.65 -34.10 1191.17 0.52 5936971.29 715363.81 N 70.23062567 W 148.26146512 8686.91 47.66 237.06 7331.65 7387. 32 -985.23 3480.94 1133.88 -72.54 1131.55 0.92 5936931.17 715305.32 N 70.23052066 W 148.2619 8780.44 46.81 237.09 7395.15 7450. 82 -917.07 3549.61 1079.52 -109.87 1073.92 0.91 5936892.22 715248.77 4 N 70.23041872 W 148.2624 8875.00 47.18 237.38 7459.65 7515. 32 -848.40 3618.76 1026.39 -147.29 1015.77 0.45 5936853.17 715191.71 N 70.23031651 W 148.26288084 8969.28 47.25 237.43 7523.69 7579. 36 -779.66 3687.95 975.10 -184.56 957.47 0.08 5936814.25 715134.50 N 70.23021470 W 148.26335136 9064.77 47.13 238.25 7588.58 7644. 25 -710.02 3758.00 925.16 -221.85 898.17 0.64 5936775.30 715076.28 N 70.23011285 W 148.26383000 9159.11 47.68 238.96 7652.43 7708. 10 -640.88 3827.45 877.68 -258.03 838.89 0.80 5936737.46 715018.06 N 70.23001404 W 148.26430847 9252.69 48.24 240.80 7715.10 7770. 77 -571.56 3896.95 832.03 -292.90 778.78 1.58 5936700.90 714958.96 N 70.22991880 W 148.26479364 9347.13 47.69 241.54 7778.34 7834. 01 -501.51 3967.09 788.23 -326.72 717.33 0.82 5936665.34 714898.50 N 70.22982640 W 148.26528958 9442.06 47.71 241.63 7842.23 7897. 90 -431.35 4037.31 747.98 -360.13 655.57 0.07 .5936630.19 714837.72 N 70.22973514 W 148.26578799 9536.21 48.53 243.97 7905.08 7960. 75 -361.28 4107.40 711.14 -392.16 593.23 2.05 5936596.41 714776.32 N 70.22964765 W 148.26629114 9630.80 48.72 245.27 7967.61 8023. 28 -290.31 4178.38 677.15 -422.58 529.10 1.05 5936564.18 714713.08 N 70.22956456 W 148.26680869 9725.34 49.69 245.08 8029.37 8085. 04 -218.75 4249.95 648.31 -452.63 464.15 1.04 5936532.30 714649.01 N 70.22948247 W 148.26733293 9820.31 46.86 245.00 8092.58 8148. 25 -147.89 4320.82 626.71 -482.54 399.89 2.98 5936500.58 714585.63 N 70.22940078 W 148.26785150 9912.89 47.22 244.69 8155.67 8211. 34 -80.14 4388.58 613.27 -511.34 338.57 0.46 5936470.05 714525.15 N 70.22932211 W 148.26834643 10007.54 48.38 244.55 8219.24 8274. 91 -10.03 4458.69 607.33 -541.39 275.22 1.23 5936438.22 714462.68 N 70.22924001 W 14826885768 10100.39 48.52 245.23 8280.83 8336. 50 59.45 4528.18 609.08 -570.88 212.30 0.57 5936406.96 714400.63 N 70.22915946 W 14826936546 10194.00 47.80 244.74 8343.27 8398. 94 129.17 4597.92 618.61 -600.37 149.10 0.86 5936375.69 714338.30 N 70.22907890 W 148.26987549 10288.35 48.18 245.77 8406.42 8462. 09 199.26 4668.02 635.48 -629.71 85.43 0.91 5936344.55 714275.49 N 70.22899875 W 148.27038929 10383.32 47.82 245.25 8469.97 8525. 64 269.81 4738.60 659.31 -658.97 21.21 0.56 5936313.48 714212.13 N 70.22891882 W 148.2709 10478.03 48.35 245.32 8533.23 8588. 90 340.27 4809.07 689.76 -688.43 -42.81 0.56 5936282.21 714148.97 N 70.22883832 W 148.2714 10525.21 48.65 243.99 8564.50 8620. 17 375.60 4844.41 707.52 -703.56 -74.75 2.20 5936266.19 714117.48 N 70.22879700 W 148.27168197 10643.93 47.91 241.88 8643.51 8699. 18 464.19 4933.02 759.57 -743.87 -153.65 1.47 5936223.66 714039.76 N 70.22868688 W 148.27231873 10674.39 47.23 240.53 8664.06 8719. 73 486.65 4955.50 774.35 -754.69 -173.35 3.96 5936212.28 714020.37 N 70.22865730 W 148.27247772 10702.81 46.13 239.95 8683.56 8739. 23 507.28 4976.18 788.51 -764.95 -191.30 4.15 5936201.51 714002.72 N 70.22862926 W 148.27262257 10736.33 46.78 238.71 8706.65 8762. 32 531.49 5000.47 805.79 -777.35 -212.20 3.31 5936188.53 713982.19 N 70.22859540 W 148.27279120 10771.24 50.42 239.11 8729.73 8785. 40 557.57 5026.65 824.94 -790.87 -234.62 10.46 5936174.38 713960.16 N 70.22855847 W 148.27297215 10800.57 50.91 237.99 8748.33 8804. 00 580.15 5049.34 841.92 -802.70 -253.97 3.39 5936162.00 713941.15 N 70.22852613 W 148.27312831 10830.70 52.73 237.55 8766.95 8822. 62 603.70 5073.02 860.15 -815.33 -274.01 6.15 5936148.80 713921.49 N 70.22849162 W 148.27328998 10864.82 54.80 238.81 8787.12 8842. 79 631.07 5100.54 881.52 -829.84 -297.39 6.76 5936133.64 713898.52 N 70.22845199 W 148.27347869 10893.00 56.72 239.40 8802.97 8858. 64 654.28 5123.84 899.64 -841.80 -317.38 7.03 5936121.12 713878.88 N 70.22841931 W 148.27364000 10926.76 59.43 240.16 8820.82 8876. 49 682.86 5152.49 922.05 -856.22 -342.14 8.25 5936106.00 713854.54 N 70.22837992 W 148.27383979 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 8 of 12 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft tt tt tt tt tt tt de 00 ft ttUS ftUS 1U9b/.Ei1 61.36 14U.UU Sf336.U/ tttf91 .14 /U9.Ei1 5179.:31 943 .15 -t369 .6U -3tib.39 Ei.L4 b936U91.9/ /13tf31.66 N /U.1"Ltf3433G W 14tS.L/4U1/44 10985.93 62.60 240.41 8849.37 8905 .04 734.56 5204.31 963 .22 -882 .02 -387.08 4.60 5936078.94 713810.36 N 70.22830943 W 148.27420244 11018.86 64.09 240.40 8864.14 8919 .81 763.93 5233.74 986 .97 -896 .55 -412.67 4.52 5936063.69 713785.19 N 70.22826972 W 148.27440894 i i 050.92 67.40 240.84 8877.31 8932 .98 793.10 5262.96 1010 .78 -910 .89 -438.14 10.40 5936048.63 713760.14 N 70.22823055 W 148.27461446 11084.13 69.61 241.90 8889.48 8945 .15 823.97 5293.86 1036. 04 -925. 69 -465.26 7.29 5936033.07 713733.45 N 70.22819010 W 148.27483331 11116.35 70.06 239.91 8900.59 8956 .26 854.17 5324.10 1061. 18 -940. 40 -491.69 5.96 5936017.62 713707.46 N 70.22814992 W 148.27504656 11138.92 73.85 238.70 8907.58 8963 .25 875.55 5345.56 1079 .49 -951. 35 -510.13 17.55 5936006.14 713689.33 N 70.22811999 W 148.27519543 11178.80 75.75 240.00 8918.04 8973 .71 913.91 5384.04 1112 .61 -970. 97 -543.24 5.71 5935985.60 713656.79 N 70.22806639 W 148.27546258 11210.59 77.20 240.13 8925.47 8981 .14 944.74 5414.95 1139 .25 -986. 39 -570.03 4.58 5935969.42 713630.46 N 70.22802425 W 148.27567872 11242.86 78.70 239.15 8932.21 8987 .88 976.21 5446.51 1166 .79 -1002 .34 -597.26 5.52 5935952.70 713603.69 N 70.22798067 W 148.27589844 11274.86 80.65 239.53 8937.94 8993 .61 1007.58 5477.99 1194. 54 -1018. 40 -624.34 6.20 5935935.89 713577.08 N 70.22793681 W 148.27611 11303.07 83.01 239.51 8941.95 8997 .62 1035.42 5505.91 1219. 26 -1032. 56 -648.40 8.37 5935921.05 713553.43 N 70.22789811 W 148.2763 11334.35 84.84 239.96 8945.26 9000 .93 1066.44 5537.01 1246. 91 -1048. 23 -675.26 6.02 5935904.62 713527.03 N 70.22785528 W 148.27652790 11364.52 88.74 239.79 8946.95 9002 .62 1096.48 5567.13 1273. 79 -1063. 35 -701.31 12.94 5935888.77 713501.42 N 70.22781398 W 148.27673810 11416.52 88.96 233.73 8947.99 9003 .66 1148.03 5619.12 1321. 66 -1091. 83 -744.77 11.66 5935859.06 713458.78 N 70.22773615 W 148.27708881 11447.59 88.51 230.13 8948.68 9004 .35 1178.40 5650.18 1351 .29 -1110. 99 -769.22 11.67 5935839.23 713434.89 N 70.22768382 W 148.27728609 11478.82 88.24 229.71 8949.57 9005. 24 1208.68 5681.40 1381. 44 -1131. 08 -793.11 1.60 5935818.46 713411.58 N 70.22762891 W 148.27747883 11509.47 88.58 227.36 8950.42 9006. 09 1238.20 5712.04 1411. 25 -1151. 37 -816.07 7.74 5935797.53 713389.21 N 70.22757348 W 148.27766406 11541.60 88.20 227.36 8951.32 9006. 99 1268.98 5744.15 1442. 68 -1173. 13 -839.69 1.18 5935775.11 713366.22 N 70.22751404 W 148.27785470 11572.76 87.52 224.59 8952.48 9008. 15 1298.58 5775.29 1473. 31 -1194. 76 -862.08 9.15 5935752.85 713344.45 N 70.22745491 W 148.27803533 11604.90 87.34 220.21 8953.92 9009 .59 1328.43 5807.40 1505. 20 -1218. 47 -883.73 13.63 5935728.54 713323.49 N 70.22739015 W 148.27820998 11635.58 88.55 217. 76 8955.03 9010.70 1356. 21 5838.06 1535.82 -1242.30 -903.01 8.90 5935704.17 713304.89 N 70.22732504 W 148.27836559 11667.49 89.34 216. 68 8955.61 9011.28 1384. 69 5869.96 1567.72 -1267.70 -922.31 4.19 5935678.23 713286.32 N 70.22725563 W 148.27852129 11698.69 88.86 213. 79 8956.10 9011.77 1412. 04 5901.16 1598.91 -1293.18 -940.31 9.39 5935652.26 713269.06 N 70.22718602 W 148.27866648 11730.27 89.10 212. 85 8956.67 9012.34 1439. 19 5932.74 1630.45 -1319.57 -957.65 3.07 5935625.39 713252.47 N 70.22711393 W 148.27880641 11762.07 88.10 211. 49 8957.44 9013.11 1466. 20 5964.53 1662.17 -1346.48 -974.58 5.31 5935598.01 713236.31 N 70.22704041 W 148.27894297 11793.38 87.45 210. 12 8958.66 9014.33 1492 .38 5995.81 1693.33 -1373.35 -990.60 4.84 5935570.70 713221.06 N 70.22696699 W 148.27907222 11825.51 88.00 205. 64 8959.93 9015.60 1518. 31 6027.92 1725.13 -1401.72 -1005.61 14.04 5935541.91 713206.87 N 70.22688948 W 148.27919330 11856.12 88.31 202. 70 8960.92 9016.59 1541. 80 6058.51 1755.12 -1429.63 -1018.13 9.65 5935513.66 713195.14 N 70.22681323 W 148.2792 11887.70 88.48 200. 83 8961.80 9017.47 1565. 17 6090.08 1785.80 -1458.94 -1029.84 5.94 5935484.03 713184.27 N 70.22673313 W 148.2793 11918.97 87.93 197. 34 8962.78 9018.45 1587. 30 6121.33 1815.84 -1488.48 -1040.06 11.29 5935454.22 713174.90 N 70.22665245 W 148.27947118 11949.31 87.86 195. 29 8963.90 9019.57 1607. 71 6151.65 1844.59 -1517.57 -1048.57 6.76 5935424.89 713167.21 N 70.22657296 W 148.27953987 11981.72 88.10 193. 86 8965.04 9020.71 1628. 78 6184.04 1875.05 -1548.92 -1056.72 4.47 5935393.33 713159.95 N 70.22648732 W 148.27960560 12012.66 88.27 192. 13 8966.02 9021.69 1648 .24 6214.97 1903.89 -1579.05 -1063.68 5.62 5935363.01 713153.86 N 70.22640500 W 148.27966168 12043.73 87.07 193. 32 8967.28 9022.95 1667. 66 6246.01 1932.86 -1609.33 -1070.51 5.44 5935332.55 713147.88 N 70.22632227 W 148.27971682 12075.86 86.80 192. 42 8969.00 9024,67 1687. 79 6278.09 1962.89 -1640.61 -1077.66 2.92 5935301.09 713141.63 N 70.22623682 W 148.27977445 12107.92 86.52 190. 95 8970.87 9026.54 1707 .36 6310.10 1992.68 -1671.95 -1084.14 4.66 5935269.58 713136.04 N 70.22615119 W 148.27982671 12138.06 86.83 187. 75 8972.62 9028.29 1724 .76 6340.19 2020.28 -1701.64 -1089.03 10.65 5935239.76 713132.00 N 70.22607009 W 148.27986612 12170.62 86.63 184. 78 8974.48 9030.15 1742 .11 6372.70 2049.46 -1733.95 -1092.58 9.13 5935207.37 713129.37 N 70.22598182 W 148.27989470 12202.49 86.97 182. 37 8976.26 9031.93 1757 .82 6404.52 2077.44 -1765.70 -1094.56 7.63 5935175.57 713128.29 N 70.22589506 W 148.27991067 12233.74 86.73 181. 55 8977.97 9033.64 1772. 45 6435.72 2104.57 -1796.89 -1095.63 2.73 5935144.37 713128.11 N 70.22580987 W 148.27991924 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\0336A Generated 6/5/2007 11:53 AM Page 9 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n ft tt ft ft ft de 00 ft ftUS TtUS 12265.12 87. 66 178.39 8979.51 9035.18 1786.17 6467 .06 2131.38 -1828.22 -1095.61 10.49 5935113.05 713129.01 N 70.22572426 W 148.27991907 12297.22 88. 20 178.99 8980.67 9036 .34 1799.57 6499 .14 2158 .58 -1860.29 -1094.88 2.51 5935081.01 713130.66 N 70.22563664 W 148.27991312 12328.38 87. 72 175.20 8981.78 9037 .45 1811.78 6530 .28 2184 .64 -1891.39 -1093.30 12.25 5935049.98 713133.12 N 70.22555169 W 148.27990035 12360.25 88. 48 173.64 8982.83 9038 .50 1822.89 6562 .13 2210. 61 -1923.09 -1090.20 5.44 5935018.38 713137.11 N 70.22546509 W 148.27987532 12391.34 88. 48 172.73 8983.66 9039 .33 1833.11 6593 .21 2235. 72 -1953.95 -1086.52 2.93 5934987.64 713141.67 N 70.22538079 W 148.27984553 12422.88 88. 34 170.56 8984.53 9040 .20 1842.66 6624 .74 2260. 83 -1985.14 -1081.93 6.89 5934956.59 713147.14 N 70.22529558 W 148.27980853 12453.64 87. 96 167.74 8985.53 9041 .20 1850.70 6655 .48 2284. 66 -2015.33 -1076.15 9.25 5934926.58 713153.78 N 70.22521310 W 148.27976181 12484.91 89. 03 165.06 8986.35 9042 .02 1857.41 6686 .74 2308 .09 -2045.71 -1068.80 9.23 5934896.42 713161.99 N 70.22513010 W 148.27970247 12516.36 89. 16 162.03 8986.85 9042 .52 1862.62 6718 .19 2330 .79 -2075.86 -1059.89 9.64 5934866.53 713171.75 N 70.22504773 W 148.27963057 12548.43 89. 37 158.21 8987.26 9042. 93 1866.04 6750. 26 2352. 80 -2106.02 -1048.99 11.93 5934836.71 713183.50 N 70.22496536 W 148.27954257 12579.16 90. 06 155.78 8987.41 9043. 08 1867.65 6780. 98 2372. 88 -2134.30 -1036.98 8.22 5934808.78 713196.31 N 70.22488810 W 148.2794 12608.83 89. 64 152.74 8987.49 9043. 16 1867.78 6810. 65 2391. 40 -2161.02 -1024.10 10.34 5934782.43 713209.94 N 70.22481510 W 148.2793 12641.53 89. 82 150.40 8987.64 9043 .31 1866.40 6843. 35 2410. 86 -2189.78 -1008.53 7.18 5934754.13 713226.32 N 70.22473655 W 148.27921603 12672.69 89. 95 146.89 8987.70 9043 .37 1863.49 6874. 51 2428. 38 -2216.38 -992.32 11.27 5934728.00 713243.28 N 70.22466387 W 148.27908520 12702.65 89. 92 143.87 8987.74 9043 .41 1859.00 6904 .47 2444. 06 -2241.03 -975.30 10.08 5934703.84 713260.99 N 70.22459653 W 148.27894786 12734.46 89. 88 141.82 8987.79 9043. 46 1852.84 6936. 28 2459. 80 -2266.38 -956.09 6.45 5934679.05 713280.91 N 70.22452728 W 148.27879283 12765.54 90. 23 139.05 8987.76 9043. 43 1845.55 6967. 36 2474. 33 -2290.34 -936.29 8.98 5934655.66 713301.38 N 70.22446183 W 148.27863309 12796.70 90. 06 137.47 8987.69 9043. 36 1837.10 6998. 52 2488. 16 -2313.59 -915.55 5.10 5934633.01 713322.77 N 70.22439832 W 148.27846570 12829.16 89. 20 135.16 8987.90 9043. 57 1827.24 7030. 98 2501. 91 -2337.06 -893.13 7.59 5934610.19 713345.85 N 70.22433421 W 148.27828481 12860.46 89. 37 136.21 8988.29 9043. 96 1817.41 7062. 28 2515. 18 -2359.46 -871.27 3.40 5934588.43 713368.34 N 70.22427304 W 148.27810838 12890.35 89. 78 136.72 8988.51 9044. 18 1808.40 7092. 17 2528. 52 -2381.12 -850,68 2.19 5934567.35 713389.53 N 70.22421385 W 148.27794225 12922.47 90. 23 136.85 8988.50 9044. 17 1798.90 7124. 29 2543. 32 -2404.53 -828.69 1.46 5934544.58 713412.18 N 70.22414990 W 148.27776478 12954.53 90. 33 136.78 8988.35 9044. 02 1789.42 7156. 35 2558. 43 -2427.91 -806.75 0.38 5934521.84 713434.77 N 70.22408605 W 148.27758774 12985.90 90. 06 136.62 8988.24 9043. 91 1780.10 7187. 72 2573. 46 -2450.74 -785.23 1.00 5934499.63 713456.93 N 70.22402368 W 148.27741414 13018.15 89. 92 136.53 8988.25 9043. 92 1770.44 7219. 97 2589. 16 -2474.16 -763.06 0.52 5934476.84 713479.75 N 70.22395970 W 148.27723526 13049.39 89. 64 136.83 8988.37 9044. 04 1761.14 7251. 21 2604. 70 -2496.89 -741.63 1.31 5934454.74 713501.82 N 70.22389761 W 148.27706232 13079.94 90. 06 137.66 8988.45 9044 .12 1752.33 7281. 76 2620. 43 -2519.32 -720.89 3.04 5934432.90 713523.18 N 70.22383634 W 148.27689498 13111.15 90. 43 136.21 8988.31 9043 .98 1743.17 7312 .97 2636. 63 -2542.12 -699.58 4.79 5934410.72 713545.13 N 70.22377405 W 148.276723 3 13141.89 90. 50 135.93 8988.06 9043. 73 1733.71 7343. 71 2652. 44 -2564.26 -678.26 0.94 5934389.20 713567.08 N 70.22371358 W 148.2765 13173.69 90. 33 135.69 8987.83 9043. 50 1723.78 7375. 51 2668. 96 -2587.06 -656.09 0.92 5934367.03 713589.88 N 70.22365129 W 148.2763 13205.05 90. 33 135.66 8987.65 9043 .32 1713.92 7406. 87 2685. 45 -2609.49 -634.18 0.10 5934345.23 713612.42 N 70.22359001 W 148.27619530 13236.08 90. 06 135.54 8987.55 9043 .22 1704.13 7437. 90 2701. 99 -2631.66 -612.47 0.95 5934323.69 713634.75 N 70.22352945 W 148.27602013 13268.12 89. 75 135.25 8987.60 9043 .27 1693.91 7469 .94 2719. 25 -2654.48 -589.97 1.32 5934301.53 713657.89 N 70.22346713 W 148.27583859 13299.05 89. 27 133.99 8987.87 9043 .54 1683.64 7500 .86 2735 .80 -2676.20 -567.96 4.36 5934280.44 713680.51 N 70.22340779 W 148.27566097 13330.32 89. 27 134.35 8988.26 9043. 93 f 673.04 7532. 13 2752. 59 -2697.99 -545.53 1.15 5934259.30 713703.54 N 70.22334827 W 148.27548001 13361.54 89. 47 135.27 8988.61 9044 .28 1662.78 7563 .35 2769. 88 -2719.99 -523.38 3.02 5934237.94 713726.30 N 70.22328817 W 148.27530132 13393.26 89. 20 134.24 8988.97 9044 .64 1652.32 7595 .07 2787. 68 -2742.32 -500.86 3.36 5934216.25 713749.45 N 70.22322717 W 148.27511959 13424.01 89. 37 132.20 8989.36 9045 .03 1641.41 7625 .82 2804. 49 -2763.37 -478.45 6.66 5934195.84 713772.44 N 70.22316965 W 148.27493881 13455.65 89. 34 130.00 8989.71 9045 .38 1629.10 7657 .45 2821. 04 -2784.17 -454.61 6.95 5934175.73 713796.86 N 70.22311284 W 148.27474647 13486.50 89. 75 126.15 8989.96 9045 .63 1615.62 7688 .30 2836 .03 -2803.19 -430.33 12.55 5934157.41 713821.67 N 70.22306088 W 148.27455057 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 10 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft n n ft ft ft ft de 100 ft ftUS ftUS 1 Jbl /.bb 13548.87 13579.93 13611.30 13642.69 13673.87 13706.40 13737.32 13768.96 13800.86 13832.15 13864.16 13896.38 13927.35 13959.24 13990.60 14021.06 14052.84 14084.08 14114.73 14145.75 14178.57 14209.82 14241.27 14272.92 14305.25 14336.69 14367.57 14398.40 14430.32 14461.86 14492.87 14525.44 14556.49 14588.17 ua. /b 90.50 90.19 89.75 89.68 89.68 89.82 89.71 89.68 89.16 89.64 89.13 88.99 89.71 90.12 90.23 90.30 90.40 91.05 91.26 91.08 91.08 90.19 89.75 89.54 89.88 89.82 89.71 90.06 89.88 89.88 89.92 89.75 89.88 89.75 7 ZJ.4 / 121.06 117.65 114.58 111.85 110.06 107.70 104.39 102.80 100.16 97.74 95.52 92.96 91.42 91.60 91.67 92.12 91.77 90.56 91.04 91.43 92.26 91.02 88.90 87.45 86.40 86.32 86.54 86.78 87.35 88.00 87.41 87.03 82.66 77.77 tSyyV.l U 8990.03 8989.84 8989.86 8990.01 8990.19 8990.33 8990.46 8990.62 8990.95 8991.28 8991.62 8992.15 8992.50 8992.55 8992.45 8992.31 8992.12 8991.72 8991.10 8990.47 8989.85 8989.50 8989.52 8989.72 8989.88 8989.96 8990.09 8990.15 8990.17 8990.23 8990.29 8990.38 8990.48 8990.58 14620.02 90.02 77.39 8990.65 14651.87 90.36 74.46 8990.54 14704.41 90.84 71.01 8989.99 14716.17 90.45 69.86 8989.86 14746.66 89.90 69.64 8989.77 14776.85 90.24 67.86 8989.73 yV45. / / 9045.70 9045.51 9045.53 9045.68 9045.86 9046.00 9046.13 9046.29 9046.62 9046.95 9047.29 9047.82 9048.17 9048.22 9048.12 9047.98 9047.79 9047.39 9046.77 9046.14 9045.52 9045.17 9045.19 9045.39 9045.55 9045.63 9045.76 9045.82 9045.84 9045.90 9045.96 9046.05 9046.15 9046.25 9046.32 9046.21 9045.66 9045.53 9045.44 9045.40 1 bVU.4Z 1584.01 1566.35 1547.09 1526.59 1505.31 1482.26 1459.30 1434.92 1409.61 1383.97 1357.01 1329.18 1301.89 1273.61 1245.82 1218.90 1190.83 1163.04 1135.69 1108.11 1079.10 1051.41 1023.14 994.27 964.49 935.41 906.87 878.42 849.05 //ly.4b 7750.67 7781.73 7813.10 7844.49 7875.67 7908.20 7939.12 7970.76 8002.66 8033.95 8065.95 8098.17 8129.14 8161.03 8192.39 8222.85 8254.63 8285.86 8316.51 8347.52 8380.33 8411.58 8443.03 8474.68 8507.01 8538.45 8569.33 8600.16 8632.08 820.17 8663.62 791.77 8694.63 761.84 8727.20 732.83 8758.25 702.42 8789.93 671.46 8821.78 640.30 8853.63 588.38 8906.17 576.70 8917.93 546.36 8948.42 516.28 8978.61 Li54y.i5/ -LiSLV.y15 2862.75 -2837.64 2874.41 -2852.86 2884.82 -2866.67 2894.04 -2879.04 2902.33 -2890.19 2910.17 -2900.71 2916.45 -2909.26 2921.88 -2916.70 2926.52 -2923.04 2930.04 -2927.91 2932.70 -2931.61 2934.38 -2933.99 2935.22 -2935.17 2936.05 -2936.01 2937.27 -2936.91 2938.92 -2937.91 2941.00 -2938.99 2942.95 -2939.63 2944.99 -2940.06 2947.61 -2940.72 2951.09 -2941.78 2954.62 -2942.68 2957.59 -2942.65 2959.93 -2941.65 2961.97 -2939.91 2963.97 -2937.92 2966.31 -2935.99 2969.08 -2934.20 2972.50 -2932.56 2976.55 -2931.28 2980.87 -2930.04 2985.48 -2928.46 2988.91 -2925.67 2990.20 -2920.29 2990.36 -2913.44 2989.95 -2905.69 2987.08 -2890.10 2986.10 -2886.17 2983.39 -2875.61 2980.49 -2864.67 -4V4./b tS.bU b`JS414U.Jb /13154/./) IV /V.ZZ3V IZZ`J VV 14i5.Z/4.144115 -378.36 8.09 5934124.46 713874. 60 N 70.22296678 W 148.27413128 -351.29 11.02 5934110.01 713902. 08 N 70.22292520 W 148.27391290 -323.13 9.89 5934097.01 713930. 63 N 70.22288748 W 148.27368567 -294.29 8.70 5934085.46 713959. 81 N 70.22285369 W 148.27345295 -265.17 5.74 5934075.14 713989.23 N 70.22282323 W 148.27321805 -234. 39 7.27 5934065.49 714020.29 N 70.22279448 W 148.27296974 -204. 68 10.71 5934057.80 714050.23 N 70.22277113 W 148.27273004 -173. 93 5.03 5934051.24 714081.18 N 70.22275082 W 148.27248194 -142. 67 8.43 5934045.78 714112.61 N 70.22273348 W 148.27222976 -111. 77 7.88 5934041.79 714143.64 N 70.22272018 W 148.27198043 -79. 97 7.12 5934039.00 714175.52 N 70.22271009 W 148.2717 -47. 85 7.96 5934037.53 714207.70 N 70.22270358 W 148.2714 -16. 91 5.49 5934037.23 714238.66 N 70.22270035 W 148.27121512 14. 97 1.40 5934037.29 714270.55 N 70.22269805 W 148.27095793 46. 32 0.42 5934037.29 714301.91 N 70.22269561 W 148.27070504 76. 76 1.50 5934037.15 714332.36 N 70.22269286 W 148.27045943 108. 52 1.15 5934036.97 714364.14 N 70.22268991 W 148.27020320 139. 75 4.40 5934037.22 714395.38 N 70.22268817 W 148.26995124 170. 40 1.71 5934037.66 714426.01 N 70.22268700 W 148.26970404 201. 40 1.38 5934037.88 714457.03 N 70.22268518 W 148.26945389 234. 20 2.53 5934037.75 714489.84 N 70.22268229 W 14826918930 265. 43 4.88 5934037.74 714521.08 N 70.22267984 W 148.26893731 296. 88 6.88 5934038.66 714552.52 N 70.22267990 W 148.26868360 328. 51 4.63 5934040.56 714584.11 N 70.22268265 W 148.26842840 360. 80 3.41 5934043.21 714616.32 N 70.22268738 W 148.26816795 392. 17 0.32 5934046.10 714647.63 N 70.22269283 W 148.26791482 422. 99 0.80 5934048.90 714678.38 N 70.22269808 W 148.26766617 453. 77 1.38 5934051.57 714709.09 N 70.22270298 W 148.26741787 485. 65 1.87 5934054.11 714740.91 N 70.22270744 W 148.2671 517. 16 2.06 5934056.28 714772.37 N 70.22271093 W 148.26690644 548. 15 1.91 5934058.40 714803.31 N 70.22271432 W 148.26665647 580. 68 1.28 5934060.90 714835.78 N 70.22271863 W 148.26639401 611. 59 14.08 5934064.57 714866.61 N 70.22272624 W 148.26614459 642. 80 15.44 5934070.83 714897.65 N 70.22274094 W 148.26589279 673. 91 1.46 5934078.56 714928.54 N 70.22275964 W 148.26564185 704. 80 9.26 5934087.18 714959.20 N 70.22278080 W 148.26539263 754. 96 6.63 5934104.19 715008.90 N 70.22282337 W 148.26498792 766. 04 10.33 5934108.44 715019.86 N 70.22283413 W 148.26489853 794. 65 1.94 5934119.80 715048.15 N 70.22286295 W 148.26466774 822. 78 6.00 5934131.54 715075.97 N 70.22289283 W 148.26444074 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 11 of 12 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft tt ft ft tt ft de 00 ft ftUS ftUS 14t5V/.3/ t5y.4y bb.VV rSy25y.tSV yV45.4/ 4t3b./y yVUy.13 Ly/b.b4 -LtSbL.4/ tSbU./5 14839.92 89.01 62.38 8990.23 9045.90 453.24 9041.67 2971.32 -2838.04 879.93 14871.39 89.11 58.73 8990.74 9046.41 421.84 9073.14 2964.83 -2822.58 907.32 14900.69 89.62 55.10 8991.07 9046.74 392.77 9102.44 2957.25 -2806.59 931.87 14934.26 89.56 53.94 8991.31 9046.98 359.66 9136.01 2947.54 -2787.10 959.20 14963.93 89.97 51.05 8991.43 9047.10 330.59 9165.68 2938.26 -2769.04 982.74 14994.87 90.17 47.76 8991.39 9047.06 300.65 9196.61 2927.29 -2748.91 1006.23 15026.99 90.48 45.53 8991.21 9046.88 270.00 9228.73 2914.76 -2726.86 1029.58 15057.47 91.03 42.72 8990.81 9046.48 241.34 9259.21 2901.92 -2704.99 1050.80 15088.79 91.41 41.46 8990.14 9045.81 212.29 9290.52 2888.00 -2681.75 1071.79 15121.71 90.82 41.58 8989.50 9045.17 181.88 9323.44 2873.36 -2657.11 1093.60 15152.53 91.03 42.02 8989.00 9044.67 153.34 9354.25 2860.07 -2634.14 1114.14 15184.51 91.34 41.67 8988.34 9044.01 123.73 9386.23 2846.59 -2610.32 1135.47 15216.00 90.58 38.50 8987.82 9043.49 94.95 9417.71 2832.73 -2586.23 1155.74 15247.74 89.86 35.87 8987.69 9043.36 66.63 9449.45 2817.61 -2560.95 1174.93 15279.54 90.07 36.32 8987.71 9043.38 38.53 9481.25 2802.20 -2535.25 1193.66 Last MWD+IFR+MS 15308.48 90.21 37.06 8987.64 9043.31 12.81 9510.19 2788.69 -2512.05 1210.95 TD (Projected) 15365.00 90.21 37.06 8987.44 9043.11 -37.57 9566.71 2763.31 -2466.94 1245.01 Survey Type: Definitive Survey NOTES: GCT MS - ( Schlumberger GCT multishot --GCT surveys in casing or open hole. G CT = "Gyro Continuous Tool".) MWD +IFR + MS - (In-fie ld referenced MWD with mull-stati on analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 906 FSL 4381 FEL S11 T 10N R15E UM 5936971.55 714172.22 BHL : 3719 FSL 3139 FEL S14 T10N R15E UM 5934541.07 715486.71 y. b`J by34744.b3 /IDIU3. bi5 IV /U.ZZL`JLb lb VV 14t3.Lb4L1 bV/ 8.18 5934159.77 715132,33 N 70.22296556 W 148.26397969 11.60 5934176.01 715159.27 N 70.22300780 W 148.26375865 12.51 5934192.69 715183.35 N 70.22305148 W 148.26356062 3.46 5934212.94 715210.12 N 70.22310470 W 148.26334006 9.84 5934231.66 715233.13 N 70.22315404 W 148.26315017 10.65 5934252.45 715256.04 N 70.22320902 W 148.26296064 7.01 5934275.15 715278.76 N 70.22326925 W 148.26277220 9.39 5934297.62 715299.34 N 70.22332900 W 148.26260100 4.20 5934321.44 715319.66 N 70.22339248 W 148.26243164 1.83 5934346.70 715340.77 N 70.22345979 W 148.26225 1.58 5934370.24 715360.65 N 70.22352254 W 1482620 1.46 5934394.65 715381.29 N 70.22358761 W 148.2619 10.35 5934419.30 715400.87 N 70.22365340 W 148.26175415 8.59 5934445.12 715419.33 N 70.22372247 W 148.26159936 1.56 5934471.34 715437.32 N 70.22379266 W 148.26144818 2.60 5934495.02 715453.95 N 70.22385605 W 148.26130865 0.00 5934541.07 715486.71 N 70.22397925 W 148.26103377 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\03-36A\03-36A Generated 6/5/2007 11:53 AM Page 12 of 12 WELLHEAb = 13-5/8" FMC ACTUATOR = KB. ElEV = BAKER 60' BF. ELEV = 30' KOP = Max Angle = Datum MD = 2700' 91 ° @ 15057 10888' Datum TV D = 8800' SS PJC DRAFT 13-3/8" CSC, 68#, NT-80 CYHE, ID = 12.415" I--I 3977' ~- Minimum ID (03-36A) = 3.725" @ 10423' 4-1 /2" HES XN NIPPLE 9-5/8" WHIPSTOCK (04(12/07) ~-~ 4756' 9-5/8" EZSV (04/12/07} 4777' 9-5/8" CSC, 47#, NT-80S, I-{ 11901 NSCC, K) = 8.681 " ~--~ O ~ -3 6A I S~ N07ES: WELLBORE 70° @ 11115' 22~-~4-1/2" HES X NIP, ID = 3.813" 2900' ~ EST CEMENT (06/20/06) 4600' -L9-5/8" X 7" HR ZXP LTP, ID = 6.29" 4622' 9-5/8" X 7" FLEX LOCK HGR, ID = 6.30" MILLOUT WINDOW (03-36A) 4756' - 4777' ~4-1/2" HES X NIP, ID = 3.813" ~ 10379' ~ 7" X 4-112" BKR S-3 PKR, ID = 3.870" 10402' 4-1/2" HES X NIP, ID = 3.813" 10416' 12' TIEBACK, ID = 5.250" 10423' 4-1/2" HES XN NIP, ID = 3.725" 1-1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, ID = 3.958" ~ 10435' 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 8.276"` I~ 10588' PERFORATION SUMMARY REF LOG: SLB USIT ON 05l02T07 ANGLE AT TOP PERF: 90° @ 15010' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-718" 6 15010 - 15110 O 5/4/2007 10428' ~-i 7" X 5" HR ZXP LTP, ID = 4.350" 10435' ~4-1/2" WLEG, ID = 3.958" 10439' 7" X 5" FLEX-LOCK LNR HGR, ID = 4.350" 10449' 5" X 4-1/2" XO, ID = 3.920" 11~--~ 5-3/4" SWELL PKR, ID = 3.958" 12415' 5-3/4" SWELL PKR, ID = 3.958" 13020' S-3/4" SWELL PKR, ID = 3.958" 13624' 5-3/4" SWELL PKR, ID = 3.958" 14228' S-3/4" SWELL PKR, ID = 3.958" 14830' 5-314" SWELL PKR, ID = 3.958" PBTD -( 15274' 4-1/2" LNR, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 15363' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 04/29!93 ORIGINAL COMPLETION WELL: r03-36 04!29!93 N28E RWO PERMIT No: FL070200 05/07/07 N7ES SIDETRACK (03-36A) API No: 50-029-22340-01 05/30/07 ?/ PJC DRLG DRAFT CORRECTIONS SEC 11, T10N, R15E, 899' FWL & 906' FSL BP Exploration (Alaska) .~ SCHLUMBERGER Survey report Client ...................: Field ....................: Well ...................... API number ...............: Engineer .................. RIG :...................... STATE :...................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration (Alaska) Inc. Prudhoe Bay 03-36A 50-029-22340-01 J. Hudon Nabors-7ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Depth GL above permanent.......: 27.00 ft KB above permanent.......: 55.67 ft DF above permanent.......: 55.67 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 244.00 degrees 4-May-2007 18:23:53 Page 1 of 16 Spud date ................: 12-Apr-07 Last survey date.........: 30-Apr-07 Total accepted surveys...: 449 MD of first survey.......: 0.00 ft MD of last survey........: 15365.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 12-Apr-2007 Magnetic field strength..: 1153.47 HCNT Magnetic dec (+E/W-).....: 24.16 degrees Magnetic dip .............: 80.94 degrees ----- MWD survey Reference Reference G ............... Reference H ..............: Reference Dip ............. Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.67 meal 1153.47 HCNT 80.94 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)...... 24.16 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.16 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~~ SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 2 of 16 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) (f t) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 57.37 0.00 0.00 57.37 57.37 0.00 0.00 0.00 0.00 0.00 0.00 BP_ GCT MS 3 63.47 0.06 89.34 6.10 63.47 -0.00 0.00 0.00 0.00 89.34 0.98 BP_ GCT MS 4 77.47 0.06 87.73 14.00 77.47 -0.02 0.00 0.02 0.02 88.68 0.01 BP_ GCT MS 5 91.97 0.04 99.69 14.50 91.97 -0.03 -0.00 0.03 0.03 90.26 0.15 BP_ GCT MS 6 106.37 0.01 126.11 14.40 106.37 -0.03 -0.00 0.04 0.04 92.72 0.22 BP_ GCT MS 7 120.77 0.00 138.09 14.40 120.77 -0.03 -0.00 0.04 0.04 93.77 0.07 BP_ GCT MS 8 135.07 0.00 131.16 14.30 135.07 -0.03 -0.00 0.04 0.04 93.77 0.00 BP_ GCT MS 9 149.37 0.00 133.85 14.30 149.37 -0.03 -0.00 0.04 0.04 93.77 0.00 BP_ GCT MS 10 163.67 0.00 137.77 14.30 163.67 -0.03 -0.00 0.04 0.04 93.77 0.00 BP_ GCT MS 11 177.92 0.00 142.37 14.25 177.92 -0.03 -0.00 0.04 0.04 93.77 0.00 BP_ GCT MS 12 192.07 0.00 149.76 14.15 192.07 -0.03 -0.00 0.04 0.04 93.77 0.00 BP_ GCT MS 13 206.07 0.01 136.41 14.00 206.07 -0.03 -0.00 0.04 0.04 95.01 0.07 BP_ GCT MS 14 220.07 0.01 134.98 14.00 220.07 -0.03 -0.01. 0.04 0.04 97.27 0.00 BP_ GCT MS 15 234.07 0.02 159.84 14.00 234.07 -0.03 -0.01 0.04 0.04 101.21 0.08 BP_ GCT MS 16 248.02 0.03 172.07 13.95 248.02 -0.03 -0.01 0.04 0.05 108.22 0.08 BP_ GCT MS 17 261.87 0.03 167.96 13.85 261.87 -0.03 -0.02 0.04 0.05 115.69 0.02 BP_ GCT MS 18 275.67 0.04 149.88 13.80 275.67 -0.03 -0.03 0.05 0.06 121.44 0.11 BP_ GCT MS 19 289.47 0.04 124.42 13.80 289.47 -0.03 -0.04 0.05 0.06 123.69 0.13 BP_ GCT MS 20 303.37 0.06 108.60 13.90 303.37 -0.04 -0.04 0.06 0.08 122.32 0.17 BP_ GCT MS 21 317.27 0.09 105.63 13.90 317.27 -0.05 -0.05 0.08 0.09 119.36 0.22 BP_ GCT MS 22 331.12 0.08 107.22 13.85 331.12 -0.07 -0.05 0.10 0.11 117.05 0.07 BP_ GCT MS 23 345.27 0.07 110.47 14.15 345.27 -0.08 -0.06 0.12 0.13 115.89 0.08 BP_ GCT MS 24 359.47 0.07 111.63 14.20 359.47 -0.09 -0.06 0.14 0.15 115.33 0.01 BP_ GCT MS 25 373.77 0.06 109.56 14.30 373.77 -0.10 -0.07 0.15 0.17 114.88 0.07 BP_ GCT MS 26 388.07 0.05 109.09 14.30 388.07 -0.11 -0.07 0.16 0.18 114.46 0.07 BP _GCT MS 27 402.32 0.03 106.51 14.25 402.32 -0.12 -0.08 0.17 0.19 114.13 0.14 BP_ GCT MS 28 416.62 0.03 105.84 14.30 416.62 -0.13 -0.08 0.18 0.20 113.83 0.00 BP_ GCT MS 29 430.97 0.03 111.26 14.35 430.97 -0.13 -0.08 0.19 0.20 113.63 0.02 BP_ GCT MS 30 445.12 0.02 112.26 14.15 445.12 -0.14 -0.08 0.19 0.21 113.58 0.07 BP_ GCT MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 3 of 16 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) (f t) (ft) (deg) 100f) type (deg) 31 459.37 0.01 111.83 14.25 459.37 -0.14 -0.09 0.20 0.21 113.55 0.07 BP _GCT MS 32 473.82 0.01 113.82 14.45 473.82 -0.14 -0.09 0.20 0.22 113.54 0.00 BP _GCT MS 33 488.17 0.02 116.66 14.35 488.17 -0.14 -0.09 0.20 0.22 113.58 0.07 BP _GCT MS 34 502.67 0.03 123.82 14.50 502.67 -0.15 -0.09 0.21 0.23 113.78 0.07 BP _GCT MS 35 517.07 0.01 130.86 14.40 517.07 -0.15 -0.09 0.21 0.23 114.04 0.14 BP _GCT MS 36 531.47 0.00 134.72 14.40 531.47 -0.15 -0.10 0.21 0.23 114.13 0.07 BP _GCT MS 37 545.87 0.01 139.83 14.40 545.87 -0.15 -0.10 0.21 0.23 114.26 0.07 BP _GCT MS 38 560.37 0.01 146.09 14.50 560.37 -0.15 -0.10 0.22 0.24 114.55 0.01 BP _GCT MS 39 574.67 0.00 148.12 14.30 574.67 -0.15 -0.10 0.22 0.24 114.71 0.07 BP _GCT MS 40 589.17 0.00 153.93 14.50 589.17 -0.15 -0.10 0.22 0.24 114.71 0.00 BP _GCT MS 41 603.52 0.00 162.63 14.35 603.52 -0.15 -0.10 0.22 0.24 114.71 0.00 BP _GCT MS 42 617.87 0.02 169.02 14.35 617.87 -0.15 -0.10 0.22 0.24 115.20 0.14 BP _GCT MS 43 632.07 0.03 176.35 14.20 632.07 -0.15 -0.11 0.22 0.24 116.44 0.07 BP _GCT MS 44 646.37 0.02 185.09 14.30 646.37 -0.15 -0.11 0.22 0.25 117.74 0.07 BP _GCT MS 45 660.77 0.01 194.38 14.40 660.77 -0.14 -0.12 0.22 0.25 118.56 0.07. BP _GCT MS 46 675.17 0.02 200.58 14.40 675.17 -0.14 -0.12 0.22 0.25 119.42 0.07 BP _GCT MS 47 689.52 0.03 202.36 14.35 689.52 -0.14 -0.13 0.21 0.25 120.86 0.07 BP _GCT MS 48 703.87 0.03 205.87 14.35 703.87 -0.13 -0.13 0.21 0.25 122.57 0.01 BP _GCT MS 49 718.27 0.03 209.61 14.40 718.27 -0.12 -0.14 0.21 0.25 124.29 0.01 BP _GCT MS 50 732.67 0.04 213.47 14.40 732.67 -0.12 -0.15 0.20 0.25 126.30 0.07 BP _GCT MS • 51 747.07 0.05 216.09 14.40 747..07 -0.11 -0.16 0.20 0.25 128.89 0.07 BP _GCT MS 52 761.27 0.07 210.83 14.20 761.27 -0.09 -0.17 0.19 0.25 132.24 0.15 BP _GCT MS 53 774.87 0.09 209.87 13.60 774.87 -0.08 -0.19 0.18 0.26 136.37 0.15 BP _GCT MS 54 788.47 0.09 212.84 13.60 788.47 -0.06 -0.20 0.17 0.26 140.86 0.03 BP _GCT MS 55 802.27 0.10 213.98 13,80 802.27 -0.04 -0.22 0.15 0.27 145.47 0.07 BP _GCT MS 56 816.07 0.11 217.85 13,80 816.07 -0.02 -0.24 0.14 0.28 150.33 0.09 BP _GCT MS 57 829.87 0.10 222.87 13.80 829.87 0.01 -0.26 0.12 0.29 155.02 0.10 BP _GCT MS 58 843.87 0.08 220.95 14.00 843.87 0.03 -0.28 0.11 0.30 158.89 0.14 BP _GCT MS 59 859.97 0.08 213.02 16.10 859.97 0.05 -0.30 0.09 0.31 162.38 0.07 BP _GCT MS 60 877.22 0.07 208.29 17.25 877.22 0.06 -0.32 0.08 0.33 165.33 0.07 BP _GCT MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 4 of 16 --- 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 -------- 894.47 ------ 0.06 ------- 199.52 ------ 17.25 -- 894.47 0.08 -0.33 0.07 0.34 167.38 0.08 BP_ GCT MS 62 911.57 0.05 186.16 17.10 911.57 0.09 -0.35 0.07 0.36 168.53 0.09 BP_ GCT MS 63 928.77 0.08 174.85 17.20 928.77 0.10 -0.37 0.07 0.38 169.07 0.19 BP_ GCT MS 64 945.87 0.11 168.36 17.10 945.87 0.11 -0.40 0.08 0.41 169.22 0.19 BP_ GCT MS 65 962.97 0.12 170.43 17.10 962.97 0.12 -0.43 0.08 0.44 169.23 0.06 BP_ GCT MS 66 980.02 0.11 177.82 17.05 980.02 0.13 -0.47 0.09 0.47 169.57 0.10 BP_ GCT MS 67 997.07 0.10 184.65 17.05 997.07 0.14 -0.50 0.09 0.50 170.28 0.09 BP_ GCT MS 68 1013.87 0.10 192.66 16.80 1013.87 0.16 -0.53 0.08 0.53 171.27 0.08 BP_ GCT MS 69 1030.47 0.09 204.61 16.60 1030.47 0.18 -0.55 0.07 0.56 172.55 0.13 BP_ GCT MS 70 1047.07 0.09 213.35 16.60 1047.07 0.20 -0.57 0.06 0.58 174.09 0.08 BP_ GCT MS 71 1063.72 0.09 217.56 16.65 1063.72 0.22 -0.60 0.04 0.60 175.74 0.04 BP_ GCT MS 72 1080.37 0.09 219.62 16.65 1080.37 0.24 -0.62 0.03 0.62 177.39 0.02 BP_ GCT MS 73 1097.02 0.09 221.08 16.65 1097.02 0.27 -0.64 0.01 0.64 179.00 0.01 BP_ GCT MS 74 1113.57 0.06 229.40 16.55 1113.57 0.29 -0.65 -0.00 0.65 180.35 0.19 BP_ GCT MS 75 1130.17 0.04 233.50 16.60 1130.17 0.30 -0.66 -0.02 0.66 181.32 0.12. BP_ GCT MS 76 1146.67 0.06 230.76 16.50 1146.67 0.32 -0.67 -0.03 0.67 182.27 0.12 BP_ GCT MS 77 1163.17 0.08 229.58 16.50 1163.17 0.34 -0.68 -0.04 0.68 183.52 0.12 BP_ GCT MS 78 1179.67 0.10 235.85 16.50 1179.67 0.36 -0.70 -0.06 0.70 185.13 0.13 BP_ GCT MS 79 1196.17 0.13 247.07 16.50 1196.17 0.40 -0.71 -0.09 0.72 187.34 0.23 BP_ GCT MS 80 1212.57 0.18 254.20 16.40 1212.57 0.44 -0.73 -0.13 0.74 190.42 0.33 BP_ GCT MS 81 1229.07 0.27 259.39 16.50 1229.07 0.50 -0.74 -0.20 0.77 194.86 0.56 BP _GCT MS 82 1246.37 0.35 265.73 17.30 1246.37 0.59 -0.75 -0.29 0.81 201.03 0.50 BP _GCT MS 83 1263.87 0.39 272.47 17.50 1263.87 0.69 -0.75 -0.40 0.86 208.07 0.34 BP_ GCT MS 84 1281.27 0.42 276.61 17.40 1281.27 0.80 -0.75 -0.53 0.91 215.17 0.24 BP _GCT MS 85 1298.77 0.43 279.55 17.50 1298.77 0.91 -0.73 -0.65 0.98 221.96 0.14 BP _GCT MS 86 1316.17 0.44 282.21 17.40 1316.17 1.01 -0.70 -0.78 1.05 228.14 0.13 BP _GCT MS 87 1333.62 0.47 284.63 17.45 1333.62 1.12 -0.67 -0.92 1.14 233.89 0.20 BP _GCT MS 88 1351.07 0.48 285.93 17.45 1351.07 1.23 -0.63 -1.06 1.23 239.16 0.08 BP _GCT MS 89 1368.42 0.48 286.13 17.35 1368.42 1.34 -0.59 -1.20 1.34 243.72 0.01 BP _GCT MS 90 1385.77 0.45 286.54 17.35 1385.77 1.44 -0.55 -1.33 1.44 247.51 0.17 BP _GCT MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 5 of 16 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) --- 91 -------- 1403.07 ------ 0.44 ------- 287.13 ---- 17.30 1403.06 1.54 - 0.51 - 1.46 1.55 250.66 0.06 BP_ GCT MS 92 1420.27 0.40 287.87 17.20 1420.26 1.63 -0.47 -1.58 1.65 253.28 0.23 BP_ GCT MS 93 1436.87 0.31 289.45 16.60 1436.86 1.70 -0.44 -1.68 1.74 255.24 0.55 BP_ GCT MS 94 1453.42 0.20 292.99 16.55 1453.41 1.75 -0.42 -1.75 1.80 256.61 0.67 BP_ GCT MS 95 1470.17 0.15 296.25 16.75 1470.16 1.79 -0.39 -1.79 1.84 257.59 0.30 BP_ GCT MS 96 1486.87 0.13 304.23 16.70 1486.86 1.81 -0.37 -1.83 1.87 258.43 0.17 BP_ GCT MS 97 1503.57 0.13 316.73 16.70 1503.56 1.82 -0.35 -1.86 1.89 259.33 0.17 BP_ GCT MS 98 1520.32 0.16 330.12 16.75 1520.31 1.83 -0.32 -1.88 1.91 260.47 0.27 BP_ GCT MS 99 1537.07 0.20 344.56 16.75 1537.06 1.83 -0.27 -1.90 1.92 261.99 0.36 BP_ GCT MS 100 1553.87 0.27 356.72 16.80 1553.8.6 1.81 -0.20 -1.91 1.92 264.04 0.51 BP_ GCT MS 101 1570.67 0..36 7.98 16.80 1570.66 1.76 -0.11 -1.91 1.91 266.76 0.65 BP_ GCT MS 102 1587.47 0.45 17.52 16.80 1587.46 1.69 0.01 -1.88 1.88 270.22 0.67 BP_ GCT MS 103 1604.27 0.56 24.08 16.80 1604.26 1.58 0.15 -1.83 1.83 274.54 0.74 BP_ GCT MS 104 1620.97 0.65 29.37 16.70 1620.96 1.44 0.30 -1.75 1.77 279.81 0.63 BP_ GCT MS 105 1637.67 0.73 33.76 16.70 1637.66 1.27 0.47. -1.64 1.71 286.08 0.57 BP_ GCT MS 106 1654.52 0.84 36.95 16.85 1654.51 1.06 0.66 -1.51 1.65 293.68 0.70 BP_ GCT MS 107 1671.37 0.93 40.19 16.85 1671.36 0.83 0.86 -1.34 1.60 302.73 0.61 BP_ GCT MS 108 1688.17 1.00 42.93 16.80 1688.15 0.57 1.08 -1.16 1.58 312.92 0.50 BP_ GCT MS 109 1704.97 1.08 44.47 16.80 1704.95 0.28 1.30 -0.95 1.60 323.87 0.50 BP_ GCT MS 110 1721.77 1.13 45.70 16.80 1721.75 -0.02 1.52 -0.72 1.68 334.82 0.33 BP_ GCT MS 111 1738.57 1.15 46.45 16.80 1738.54 -0.34 1.76 -0.48 1.82 344.84 0.15 BP_ GCT MS 112 1755.37 1.18 46.35 16.80 1755.34 -0.67 1.99 -0.23 2.01 353.45 0.18 BP_ GCT MS 113 1772.07 1.22 45.76 16.70 1772.04 -1.00 2.23 0.02 2.24 0.59 0.25 BP_ GCT MS 114 1788.87 1.27 44.56 16.80 1788.83 -1.35 2.49 0.28 2.51 6.45 0.34 BP_ GCT MS 115 1805.42 1.30 42.70 16.55 1805.38 -1.69 2.76 0.54 2.81 11.02 0.31 BP_ GCT MS 116 1821.77 1.33 40.03 16.35 1821.72 -2.04 .3..04 0.79 3.14 14.48 0.42 BP_ GCT MS 117 1838.17 1.37 37.21 16.40 1838.12 -2.39 3.34 1.03 3.50 17.07 0.47 BP_ GCT MS 118 1854.77 1.38 35.22 16.60 1854.72 -2.74 3.67 1..26 3.88 19.00 0.29 BP_ GCT MS 119 1871.62 1.39 34.04 16.85 1871.56 -3.10 4.00 1.49 4.27 20.47 0.18 BP_ GCT MS 120 1888.47 1.39 33.32 16.85 1888.41 -3.45 4.34 1.72 4.67 21.62 0.10 BP_ GCT MS SCHLUMBERGER Survey Report 4 -May-2007 18:23:53 Page 6 of 1b Seq Measured Incl Azimuth Course TUD 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) (f t) (ft) (ft) (deg) 100f) type (deg) --- 121 -------- 1905.27 ------ 1.37 ----- 33.27 16.80 1905.20 -3.80 4.68 1.94 5.07 22.54 0.12 BP _GCT MS 122 1922.07 1.35 33.78 16.80 1922.00 -4.14 5.01 2.16 5.46 23.34 0.14 BP _GCT MS 123 1938.87 1.35 34.30 16.80 1938.79 -4.48 5.34 2.38 5.85 24.06 0.07 BP _GCT MS 124 1955.77 1.34 36.48 16.90 1955.69 -4.83 5.66 2.61 6.24 24.77 0.31 BP _GCT MS 125 1972.67 1.33 39.29 16.90 1972.58 -5.19 5.97 2.86 6.62 25.55 0.39 BP _GCT MS 126 1989.52 1.33 40.41 16.85 1989.43 -5.54 6.27 3.11 7.00 26.34 0.15 BP _GCT MS 127 2006.37 1.33 40.59 16.85 2006.27 -5.90 6.57 3.36 7.38 27.08 0.02 BP _GCT MS 128 2023.27 1.34 40.76 16.90 2023.17 -6.26 6.87 3.62 7.76 27.76 0.06 BP _GCT MS 129 2040.22 1.35 41.51 16.95 2040.11 -6.63 7.17 3.88 8.15 28.41 0.12 BP _GCT MS 130 2057.27 1.36 42.16 17.05 2057.16 -7.00 7.47 4.15 8.54 29.04 0.11 BP _GCT MS 131 2074.42 1.38 42.80 17.15 2074.30 -7.38 7.77 4.42 8.94 29.65 0.15 BP _GCT MS 132 2091.57 1.46 44.12 17.15 2091.45 -7.78 8.08 4.72 9.36 30.27 0.50 BP _GCT MS 133 2108.77 1.59 46.49 17.20 2108.64 -8.22 8.40 5.04 9.80 30.97 0.84 BP _GCT MS 134 2125.87 1.75 50.24 17.10 2125.74 -8.70 8.73 5.41 10.28 31.80 1.13 BP _GCT MS 135 2143.07 1.98 54.29 17.20 2142.93 -9.24 9.07 5.86 10.80 32.85 1.54 BP _GCT MS 136 2160.17 2.24 57.61 17.10 2160.01 -9.87 9.43 6.38 11.38 34.09 1.68 BP _GCT MS 137 2177.27 2.61 61.34 17.10 2177.10 -10.59 9.79 7.00 12.04 35.58 2.35 BP _GCT MS 138 2194.27 2.98 65.48 17.00 2194.08 -11.42 10.16 7.75 12.78 37.32 2.48 BP _GCT MS 139 2211.27 3.31 69.00 17.00 2211.05 -12.35 10.52 8.61 13.59 39.29 2.25 BP _GCT MS 140 2228.17 3.64 71.60 16.90 2227.92 -13.36 10.86 9.57 14.48 41.38 2.16 BP _GCT MS 141 2245.22 4.02 73.94 17.05 2244.93 -14.49 11.20 10.66 15.46 43.58 2.41 BP _GCT MS 142 2261.77 4.45 75.67 16.55 2261.44 -15.69 11.52 11.84 16.52 45.78 2.71 BP _GCT MS 143 2277.77 4.92 76.38 16.00 2277.39 -16.97 11.83 13.11 17.66 47.92 2.96 BP _GCT MS 144 2293.97 5.47 76.91 16.20 2293.52 -18.40 12.17 14.53 18.96 50.05 3.41 BP _GCT MS 145 2310.47 5.98 77.16 16.50 2309.94 -20.00 12.54 16.14 20.44 52.15 3.09 BP _GCT MS 146 2327.17 6.48 77.16 16.70 2326.54 -21.77 12.94 17.90 22.09 54.13 2.99 BP _GCT MS 147 2343.77 7.02 77.22 16.60 2343.02 -23.67 13.38 19.81 23.90 55.97 3.25 BP _GCT MS 148 2360.42 7.70 77.66 16.65 2359.54 -25.74 13.84 21.89 25.90 57.69 4.10 BP _GCT MS 149 2377.07 8.44 78.45 16.65 2376.02 -28.01 14.32 24.18 28.10 59.35 4.49 BP _GCT MS 150 2393.67 9.10 79.26 16.60 2392.43 -30.45 14.81 26.66 30.50 60.94 4.04 BP _GCT MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 7 of 16 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) 151 2410 22 9.71 80.10 16.55 2408.75 -33.06 15.30 29.32 33.07 62.45 3.78 BP_ GCT MS 152 2426.77 10.23 80.81 16.55 2425.05 -35.81 15.77 32.15 35.81 63.87 3.23 BP_ GCT MS 153 2443.47 10.74 81.50 16.70 2441.47 -38.71 16.24 35.15 38.72 65.20 3.15 BP_ GCT MS 154 2460.22 11.19 82.36 16.75 2457.92 -41.74 16.68 38.30 41.78 66.46 2.86 BP_ GCT MS 155 97 2476 11.56 83.07 16.75 2474.34 -44.87 17.10 41.58 44.96 67.64 2.36 BP GCT MS . _ 156 2493.77 11.90 83.45 16.80 2490.79 -48.09 17.50 44.97 48.26 68.73 2.08 BP_ GCT MS 157 2510.47 12.22 83.65 16.70 2507.12 -51.38 17.90 48.44 51.64 69.72 1.93 BP_ GCT MS 158 2527.27 12.53 83.86 16.80 2523.53 -54.77 18.29 52.02 55.14 70.63 1.86 BP_ GCT MS 159 2541.37 12.70 84.02 14.10 2537.29 -57.66 18.61 55.08 58.14 71.33 1.23 BP_ GCT MS 160 2542.87 12.72 84.03 1.50 2538.75 -57.97 18.65 55.41 58.46 71.40 1.34 BP_ GCT MS 161 2561.52 13.04 84.01 18.65 2556.93 -61.88 19.08 59.54 62.52 72.23 1.72 BP_ GCT MS 162 2585.87 13.35 83.97 24,35 2580.64 -67.10 19.66 65.07 67.98 73.19 1.27 BP_ GCT MS 163 2613.67 13.88 83.80 27,80 260.7.66 -73.26 20.36 71.58 74.42 74.12 1.91 BP_ GCT MS 164 2642.12 14.74 83.40 28.45 2635.23 -79.88 21.14 78.57 81.36 74.94 3.04 BP_ GCT MS 165 2670.67 15.73 82.76 28.55 2662.77 -86.97 22.05 86.01 88.79 75.62 3.52 BP_ GCT MS 166 2699.17 16.57 82.13 28,50 2690.15 -94.49 23.09 93.87 96.67 76.18 3.01 BP_ GCT MS 167 2727.67 17.22 81.72 28.50 2717.42 -102.37 24.26 102.07 104.91 76.63 2.32 BP_ GCT MS 168 2756.17 17.94 81.42 28.50 2744.59 -110.58 25.52 110.59 113.49 77.01 2.55 BP_ GCT MS 169 2784.67 18.89 81.12 28.50 2771.63 -119.18 26.89 119.48 122.47 77.32 3.35 BP_ GCT MS 170 2813.07 19.83 80.91 28.40 2798.42 -128.18 28.36 128.78 131.87 77.58 3.32 BP_ GCT MS 171 2841.57 20.55 80.79 28.50 2825.17 -137.59 29.92 138.49 141.69 77.81 2.53 BP _GCT MS 172 2870.17 21.25 80.56 28.60 2851.89 -147.37 31.57 148.56 151.88 78.00 2.46 BP _GCT MS 173 2898.57 22.19 80.13 28.40 2878.27 -157.45 33.34 158.92 162.38 78.15 3.36 BP_ GCT MS 174 2926.82 23.18 79.70 28.25 2904.33 -167.93 35.25 169.65 173.27 78.26 3.55 BP_ GCT MS 175 2954.97 23.98 79.54 28.15 2930.13 -178.78 37.28 180.73 184.53 78.35 2.85 BP_ GCT MS 176 2983.37 24.68 79.52 28.40 2956.01 -190.05 39.40 192.23 196.23 78.42 2.46 BP _GCT MS 177 3011.77 25.52 79.49 28.40 2981.73 -201.66 41.60 204.08 208.27 78.48 2.96 BP _GCT MS 178 3040.17 26.53 79.57 28.40 3007.25 -213.66 43,86 216.33 220.73 78.54 3.56 BP _GCT MS 179 3068.57 27.46 79.69 28.40 3032.56 -226.08 46,18 229.01 233.62 78.60 3.28 BP _GCT MS 180 3096.97 28.04 79.79 28.40 3057.69 -238.81 48.54 242.02 246.84 78.66 2.05 BP _GCT MS SCHLUMBERGER Survey Report 4 -May-2007 18:23:53 Page 8 of 16 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) 181 3125.17 28.43 79.81 28.20 3082.53 -251.64 50.90 255.15 260,18 78.72 1.38 BP_ GCT M5 182 3153.47 28.81 79.79 28.30 3107.38 -264.69 53.30 268.49 273,73 78.77 1.34 BP_ GCT MS 183 3184.57 29.35 79.63 31.10 3134.56 -279.24 56.00 283.37 288,85 78.82 1.75 BP_ GCT M5 184 3217.67 30.19 79.39 33.10 3163.29 -295.07 58.99 299.53 305.28 78.86 2.56 BP_ GCT MS 185 3250.27 31.12 79.25 32.60 3191.33 -311.10 62.07 315.86 321.90 78.88 2.86 BP_ GCT MS 186 3282.47 32.10 79.12 32.20 3218.75 -327.39 65.24 332.44 338.78 78.90 3.05 BP_ GCT MS 187 3314.57 33.25 78.97 32.10 3245.77 -344.13 68.53 349.45 356.11 78.90 3.59 BP_ GCT MS 188 3346.72 34.33 78.87 32.15 3272.49 -361.40 71.97 367.00 373.99 78.90 3.36 BP_ GCT MS 189 3378.67 35.29 78.76 31.95 3298.72 -379.04 75.51 384.89 392.23 78.90 3.01 BP_ GCT MS 190 3410.22 36.09 78.71 31.55 3324.35 -396.84 79.10 402.94 410.63 78.89 2.54 BP_ GCT MS 191 3441.87 36.90 78.83 31.65 3349.79 -415.04 82.77 421.40 429.46 78.89 2.57 BP_ GCT MS 192 3473.57 38.01 78.96 31.70 3374.96 -433.67 86.48 440.32 448.73 78.89 3.51 BP_ GCT MS 193 3505.17 39.16 79.02 31.60 3399.66 -452.71 90.24 459.67 468.44 78.89 3.64 BP_ GCT MS 194 3536.82 40.12 79.06 31.65 3424.03 -472.21 94.08 479.49 488.63 78.90 3.03 BP_ GCT MS 195 3568.37 40.88 79.10 31.55 3448.02 -491.99 97.97 499.61 509.12 78.91 2.41 BP_ GCT MS 196 3599.67 41.67 79.13 31.30 3471.54 -511.92 101.86 519.88 529.77 78.91 2.52 BP_ GCT MS 197 3630.97 42.85 79.19 31.30 3494.71 -532.24 105.82 540.56 550.82 78.92 3.77 BP_ GCT MS 198 3662.37 44.08 79.27 31.40 3517.50 -553.08 109.86 561.78 572.42 78.94 3.92 BP_ GCT MS 199 3693.87 44.89 79.38 31.50 3539.97 -574.37 113.95 583.47 594.49 78.95 2.58 BP_ GCT MS 200 3725.37 45.49 79.52 31.50 3562.17 -595.91 118.04 605.44 616.84 78.97 1.93 BP_ GCT M5 . 201 3756.77 46.12 79.66 31.40 3584.06 -617.59 122.11 627.58 639.35 78.99 2.03 BP_ GCT MS 202 3788.57 46.96 79.87 31.80 3605.93 -639.81 126.21 650.29 662.43 79.02 2.68 BP_ GCT MS 203 3821.27 47.73 80.10 32.70 3628.09 -662.93 130.39 673.98 686.47 79.05 2.41 BP_ GCT MS 204 3853.87 48.21 80.34 32.60 3649.92 -686.18 134.50 697.84 710.68 79.09 1.57 BP_ GCT MS 205 3886.57 48.64 80.57 32.70 3671.61 -709.64 138.56 721.96 735.14 79.14 1.42 BP_ GCT MS 206 3919.27 49.02 80.72 32.70 3.693.14 -733.22 142.56 746.25 759.75 79.18 1.21 BP_ GCT MS 207 3951.67 49.38 80.85 32.40 3714.31 -756.70 146.49 770.46 784.26 79.23 1.15 BP_ GCT MS 208 3983.97 49.73 80.94 32.30 3735.27 -780.22 150.38 794.73 808.84 79.29 1.10 BP_ GCT MS 209 4016.27 49.97 80.99 32.30 3756.09 -803.84 154.25 819.12 833.51 79.34 0.75 BP_ GCT MS 210 4048.67 49.95 81.19 32.40 3776.94 -827.55 158.10 843.62 858.31 79.39 0.48 BP_ GCT MS SCHLUMBERGER Survey Report Seq Measured Incl # depth angle - (ft) (deg) 211 4081.07 49.73 212 4113.57 49.57 213 4145.67 49.32 214 4177.57 49.15 215 4209.37 49.09 216 4241.17 49.05 217 4272.87 49.12 218 4304.37 49.19 219 4335.97 49.24 220 4367.57 49.38 221 4399.27 49.55 222 4430.87 49.68 223 4462.47 49.94 224 4493.97 50.44 225 4525.47 51.05 226 4556.97 51.52 227 4588.47 51.75 228 4619.77 51.77 229 4650.97 51.67 230 4682.07 51.53 231 4713.37 51.47 232 4744.67 51.61 233 4756.00 51.66 234 4773.00 52.70 235 4787.24 52.65 236 4817.21 53.00 237 4909.28 49.01 238 5003.97 47.11 239 5098.12 47.14 240 5190.92 44.59 4-May-2007 18:23:53 Page 9 of 16 Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 81.55 32.40 3797 83 -851.18 161.81 868.10 883.05 79.44 1.09 BP_ GCT MS 81.91 32.50 3818.87 -874.77 165.37 892.61 907.80 79.50 0.98 BP_ GCT MS 82.40 32.10 3839.74 -897.95 168.70 916.77 932.17 79.57 1.40 BP_ GCT MS 82.88 31.90 3860.57 -920.84 171.80 940.74 956.29 79.65 1.26 BP_ GCT MS 83.16 31.80 3881.39 -943.57 174.72 964.60 980.30 79.73 0.69 BP_ GCT MS 83.37 31.80 3902.22 -966.25 177.54 988.46 1004.28 79.82 0.51 BP_ GCT MS 83.49 31.70 3922.98 -988.84 180.28 1012.26 1028.19 79.90 0.36 BP_ GCT MS 83.49 31.50 3943.58 -1011.30 182.98 1035.93 1051.97 79.98 0.22 BP_ GCT MS 83.19 31.60 3964.22 -1033.88 185.76 1059.70 1075.86 80.06 0.74 BP_ GCT MS 82.63 31.60 3984.83 -1056.55 188.71 1083.48 1099.79 80.12 1.41 BP_ GCT MS 82.21 31.70 4005.43 -1079.41 191.89 1107.36 1123.86 80.17 1.14 BP_ GCT MS 82.05 31.60 4025.90 -1102.28 195.19 1131.20 1147.92 80.21 0.56 BP_ GCT MS 81.97 31.60 4046.30 -1125.24 198.54 1155.11 1172.04 80.25 0.85 BP_ GCT MS 81.61 31.50 4066.46 -1148.28 202.00 1179.06 1196.23 80.28 1.81 BP_ GCT M5 81.08 31.50 4086.40 -1171.56 205.67 1203.17 1220.62 80.30 2.33 BP_ GCT MS 80.88 31.50 4106.10 -1195.07 209.52 1227.44 1245.20 80.31 1.57 BP_ GCT MS 80.92 31.50 4125.65 -1218.70 213.43 1251.83 1269.89 80.32 0.74 BP_ GCT MS 81.08 31.30 4145.02 -1242.21 217.28 1276.11 1294.48 80.34 0.41 BP_ GCT MS 81.37 31.20 4164.35 -1265.60 221.01 1300.32 1318.97 80.35 0.80 BP_ GCT MS 81.81 31.10 4183.67 -1288.83 224.58 1324.43 1343..33 80..38 1.20 BP_ GCT MS 82.30 31.30 4203.15 -1312.12 227.96 1348.69 1367.82 80.41 1.24 BP_ GCT MS 82.64 31.30 4222.62 -1335.37 231.17 1372.98 1392.31 80.44 0.96 BP_ GCT MS 82.70 11.33 4229.65 -1343.79 232.31 1381.80 1401.19 80.46 0.61 BP_ INC +TREND 80.45 17.00 4240.08 -1356.59 234.28 1395.08 1414.61 80.47 12.11 BP_ INC +TREND 80.45 14.24 4248.71 -1367.45 236.16 1406.25 1425.94 80.47 0.35 BP _INC +TREND 78.80 29.97 4266.82 -1390.44 240.46 1429.73 1449.81 80.45 4.54 BP _INC+TREND 75.80 92.07 4324.75 -1460.04 256.13 1499.52 1521.24 80.31 5.02 BP _INC +TREND 69.70 94.69 4388.07 -1529.58 276.94 1566.74 1591.03 79.98 5.19 BP _INC +TREND 63.04 94.15 4452.17 -1598.45 304.57 1629.88 1658.10 79.42 5.18 BP _MWD +IFR+MS 61.81 92.80 4516.79 -1665.02 335.38 1688.92 1721.90 78.77 2.91 BP _MWD +IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 10 of 16 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) 241 5288.97 41.87 62.85 98.05 4588.22 -1732.14 366.58 1748.38 1786.40 78.16 2.87 BP _MWD+IFR+MS 242 5382.63 39.74 65.93 93.66 4659.12 -1793.32 393.06 1803.54 1845.88 77.71 3.13 BP _MWD+IFR+MS 243 5475.37 37.00 68.81 92.74 4731.83 -1850.77 415.24 1856.64 1902.51 77.39 3.53 BP _MWD+IFR+MS 244 5569.59 34.66 68.67 94.22 4808.21 -1905.73 435.24 1908.04 1957.05 77.15 2.49 BP _MWD+IFR+MS 245 5663.39 32.95 71.49 93.80 4886.15 -1957.62 453.04 1957.08 2008.84 76.97 2.47 BP MWD+IFR+MS . _ 246 5758.30 29.38 71.19 94.91 4967.35 -2006.32 468.75 2003.61 2057.72 76.83 3.77 BP _MWD+IFR+MS 247 5852.22 25.72 67.15 93.92 5050.62 -2049.55 484.10 2044.22 2100.76 76.68 4.37 BP _MWD+IFR+MS 248 5863.52 25.27 66.78 11.30 5060.82 -2054.40 486.00 2048.70 2105.55 76.65 4.22 BP _MWD+IFR+MS 249 5957.18 23.33 63.95 93.66 5146.18 -2092.92 502.03 2083.73 2143.36 76.45 2.42 BP _MWD+IFR+MS 250 6051.21 18.06 64.53 94.03 5234.11 -2126.14 516.48 2113.64 2175.83 76.27 5.61 BP _MWD+IFR+MS 251 6146.23 14.40 66.34 95.02 5325.33 -2152.68 527.56 2137.77 2201.90 76.14 3.89 BP _MWD+IFR+MS 252 6240.28 10.58 67.79 94.05 5417.13 -2172.99 535.52 2156.48 2221.98 76.05 4.08 BP _MWD+IFR+MS 253 6334.90 6.16 70.50 94.62 5510.72 -2186.71 540.50 2169.31 2235.64 76.01 4.69 BP _MWD+IFR+MS 254 6428.81 1.74 71.24 93.91 5604.39 -2193.13 542.64 2175.42 2242.08 .75.99 4.71 BP _MWD+IFR+MS 255 6523.19 2.16 244.84 94.38 5698.75 -2192.77 542.35 2175.16 2241.76 76.00 4.13 BP _MWD+IFR+MS 256 6617.79 5.25 248.44 94.60 5793.14 -2186.67 540.00 2169.52 2235.72 76.02 3.27 BP _MWD+IFR+MS 257 6655.38 6.06 250.93 37.59 5830.55. -2182.99 538.72 2166.05 2232.04 76.03 2.25 BP _MWD+IFR+MS 258 6709.75 8.19 248.73 54.37 5884.49 -2176.28 536.38 2159.73 2225.34 76.05 3.95 BP _MWD+IFR+MS 259 6804.37 11.88 240.42 94.62 5977.66 -2159.84 529.12 2144.97 2209.27 76.14 4.18 BP _MWD+IFR+MS 260 6899.24 14.97 234.04 94.87 6069.93 -2138.02 517.10 2126.55 2188.52 76.33 3.61 BP _MWD+IFR.+MS 261 6994.40 18.16 235.99 95.16 6161.13 -2111.22 501.59 2104.31 2163.26 76.59 3.40 BP _MWD+IFR+MS . 262 7087.44 21.24 241.63 93.04 6248.72 -2080.01 485.46 2077.45 2133.42 76.85 3.89 BP _MWD+IFR+MS 263 7181.75 26.50 242.70 94.31 6334.93 -2041.88 467.68 2043.70 2096.53 77.11 5.60 BP _MWD+IFR+MS 264 7276.71 29.66 245.52 94.96 6418.71 -1997.20 448.22 2003.48 2053.00 77.39 3.61 BP _MWD+IFR+MS 265 7371.27 34.97 245.08 94.56 6498.59 -1946.68 427.10 1957.58 2003.63 77.69 5.62 BP _MWD+IFR+MS 266 7464.89 40.38 244.26 93.62 6572.67 -1889.49 402.60 1905.89 1947.95 78.07 5.80 BP _MWD+IFR+MS 267 7559.25 44.17 244.08 94.36 6642.47 -1826.03 374.95 1848.77 1886.41 78.54 4.02 BP_MWD+IFR+MS 268 7652.39 49.73 244.59 93.14 6706.03 -1757.99 345.49 1787.44 1820.52 79.06 5.98 BP _MWD+IFR+MS 269 7746.56 49.35 242.20 94.17 6767.14 -1686.36 313.41 1723.38 1751.65 79.69 1.97 BP _MWD+IFR+MS 270 7839.71 50.94 237.23 93.15 6826.86 -1615.09 277.34 1661.69 1684.67 80..52 4.44 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 11 of 16 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) 271 7934.27 49.69 237.38 94.56 6887.24 -1542.82 238.04 1600.45 1618.05 81.54 1.33 BP _MWD+IFR+MS 272 8028.10 47.97 236.24 93.83 6949.00 -1472.75 199.38 1541.34 1554.18 82.63 2.05 BP _MWD+IFR+MS 273 8121.44 49.63 235.84 93.34 7010.48 -1403.20 160.15 1483.09 1491.71 83.84 1.81 BP _MWD+IFR+MS 274 8215.66 47.63 235.86 94.22 7072.75 -1333.21 120.46 1424.58 1429.66 85.17 2.12 BP _MWD+IFR+MS 275 8310.03 48.28 236.21 94.37 7135.95 -1263.80 81.31 1366.46 1368.87 86.59 0.74 BP _MWD+IFR+MS • 276 8404.37 48.06 236.24 94.34 7198.87 -1194.15 42.23 1308.02 1308.71 88.15 0.23 BP _MWD+IFR+MS 277 8498.23 48.12 236.93 93.86 7261.57 -1124.89 3.76 1249.72 1249.73 89.83 0.55 BP _MWD+IFR+MS 278 8591.59 48.52 237.30 93.36 7323.65 -1055.67 -34.10 1191.17 1191.65 91.64 0.52 BP _MWD+IFR+MS 279 8686.91 47.66 237.06 95.32 7387.32 -985.23 -72.54 1131.55 1133.88 93..67 0.92 BP _MWD+IFR+MS 280 8780.44 46.81 237.09 93.53 7450.82 -917.07 -109.87 1073.92 1079.52 95.84 0.91 BP _MWD+IFR+MS 281 8875.00 47.18 237.38 94.56 7515.32 -848.40 -147.29 1015.77 1026.39 98.25 0.45 BP _MWD+IFR+MS 282 8969.28 47.25 237.43 94.28 7579.36 -779.66 -184.56 957.47 975.10 100.91 0.08 BP _MWD+IFR+MS 283 9064.77 47..13 238.25 95.49 7644.25 -710.02 -221.85 898.17 925.16 103.87 0.64 BP _MWD+IFR+MS 284 9159.11 47.68 238.96 94.34 7708.10 -640.88 -258.03 838.89 877.68 107.10 0.80 BP _MWD+IFR+MS 285 9252.69 48.24 240.80 93.58 7770.77 -571.56 -292.90 778.78 832.03 110.61 1.58 BP _MWD+IFR+MS 286 9347.13 47.69 241.54 94.44 7834.01 -501.50 -326.72 717.33 788.23 114.49 0.82 BP _MWD+IFR+MS 287 9442.06 47.71 241.63 94.93 7897.89 -431.35 -360.13 655.57 747.98 118.78 0.07 BP _MWD+IFR+MS 288 9536.21 48.53 243.97 94.15 7960.75 -361.28 -392.16 593.23 711.14 123.47 2.05 BP _MWD+IFR+MS 289 9630.80 48.72 245.27 94.59 8023.27 -290.31 -422.58 529.10 677.15 128.61 1.05 BP _MWD+IFR+MS 290 9725.34 49.69 245.08 94.54 8085.04 -218.75 -452.63 464.15 648.31 134.28 1..04 BP _MWD+IFR+MS 291 9820.31 46.86 245.00 94.97 8148.24 -147.89 -482.54 399.89 626.71 140.35 2.98 BP _MWD+IFR+MS • 292 9912.89 47.22 244.69 92.58 8211.34 -80.14 -511.34 338.57 613.27 146.49 0.46 BP _MWD+IFR+MS 293 10007.54 48.38 244.55 94.65 8274.91 -10.03 -541.39 275.22 607.33 153.05 1.23 BP _MWD+IFR+MS 294 10100.39 48.52 245.23 92.85 8336.50 59.45 -570.88 212.30 609.08 159.60 0.57 BP _MWD+IFR+MS 295 10194.00 47.80 244.74 93.61 8398.94 129.17 -600.37 149.10 618.61 166.05 0.86 BP _MWD+IFR+MS 296 10288.35 48.18 245.77 94.35 8462.09 199.26 -629.71 85.43 635.48 172.27 0.91 BP _MWD+IFR+MS 297 10383.32 47.82 245.25 94.97 8525.63 269.81 -658.97 21.21 659.31 178.16 0.56 BP _MWD+IFR+MS 298 10478.03 48.35 245.32 94.71 8588.90 340.27 -688.43 -42.82 689.76 183.56 0.56 BP _MWD+IFR+MS 299 10525.21 48.65 243.99 47..18 8620.17 375.60 -703.56 -74.75 707.52 186.06 2.20 BP _MWD+IFR+MS 300 10643.93 47.91 241.88 118.72 8699.18 464.19 -743.86 -153.65 759.57 191.67 1.47 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 12 of 16 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) --- 301 -------- 10674.39 ------ 47.23 ------ 240.53 30.46 8719.73 486.65 -754.69 -173.35 774.35 192.94 3.96 BP_ MWD+IFR+MS 302 10702.81 46.13 239.95 28.42 8739.23 507.28 -764.95 -191.30 788.51. 194.04 4.15 BP_ MWD+IFR+MS 303 10736.33 46.78 238.71 33.52 8762.32 531.49 -777.35 -212.20 805.79 195.27 3.31 BP_ MWD+IFR+MS 304 10771.24 50.42 239.11 34.91 8785.40 557.57 -790.87 -234.62 824.94 196.52 10.46 BP_ MWD+IFR+MS 305 10800 57 50.91 237.99 29.33 8803.99 580.15 -802.70 -253.97 841.92 197.56 3.39 BP MWD+IFR+MS . _ 306 10830.70 52.73 237.55 30.13 8822.62 603.70 -815.33 -274.01 860.15 198.58 6.15 BP_ MWD+IFR+MS 307 10864.82 54.80 238.81 34.12 8842.79 631.07 -829.84 -297.39 881.52 199.72 6.76 BP_ MWD+IFR+MS 308 10893.00 56.72 239.40 28.18 8858.64 654.28 -841.80 -317.38 899.64 200.66 7.03 BP_ MWD+IFR+MS 309 10926.76 59.43 240.16 33.76 8876.49 682.86 -856.22 -342.14 922.05 201.78 8.25 BP_ MWD+IFR+MS 310 10957.62 61.35 240.00 30.86 8891.74 709.62 -869.60 -365.39 943.25 202.79 6.24 BP_ MWD+IFR+MS 311 10985.93 62.60 240.41 28.31 8905.04 734.56 -882.02 -387.08 963.22 203.69 4.60 BP_ MWD+IFR+MS 312 11018.86 64.09 240.40 32.93 8919.81 763.93 -896.55 -412.67 986.97 204.72 4.52 BP_ MWD+IFR+MS 313 11050.92 67.40 240.84 32.06 8932.98 793.10 -910.89 -438.14 1010.78 205.69 10.40 BP_ MWD+IFR+MS 314 11084.13 69.61 241.90 33.21 8945.15 823.97 -925.69 -465.26 1036.04 206.68 7.29 BP_ MWD+IFR+MS 315 11116.35 70.06 239.91 32.22 8956.25 854.17 -940.40 -491.69 1061.18 207.60 5.96 BP_ MWD+IFR+MS 316 11138.92 73.85 238.70 22.57 8963.25 875.55 -951.35 -510.13 1079.49 208.20 17.55 BP_ MWD+IFR+MS 317 11178.80 75.75 240.00 39.88 8973.70 913.91 -970.97 -543.24 1112.61 209.23 5.71 BP_ MWD+IFR+MS 318 11210.59 77.20 240.13 31.79 8981.14 944.74 -986.39 -570.03 1139.25 210.02 4.58 BP_ MWD+IFR+MS 319 11242.86 78.70 239.15 32.27 8987.87 976.21 -1002.34 -597..26 1166.79 210.79 5.52 BP_ MWD+IFR+MS 320 11274.86 80.65 239.53 32.00 8993.61 1007.59 -1018.40 -624.34 1194.54 211.51 6.20 BP_ MWD+IFR+MS S 321 11303.07 83.01 239.51 28.21 8997.62 1035.42 -1032.56 -648.40 1219.26 212.13 8.37 BP_ MWD+IFR+MS 322 11334.35 84.84 239.96 31.28 9000.93 1066.44 -1048.23 -675.26 1246.91 212,79 6.02 BP _MWD+IFR+MS 323 11364.52 88.74 239.79 30.17 9002.62 1096.48 -1063.35 -701.31 1273.79 213.41 12.94 BP _MWD+IFR+MS 324 11416.52 88.96 233.73 52.00 9003..66 1148.03 -1091.83 -744.77 1321.66 214,30 11.66 BP _MWD+IFR+MS 325 1.1447.59 88.51 230.13 31.07 9004.35 1178.40 -1110.99 -769.22 1351.29 214,70 11.67 BP _MWD+IFR+MS 326 11478.82 88.24 229.71 31.23 9005.23 1208.68 -1131.08 -793.11 1381.44 215.04 1.60 BP _MWD+IFR+MS 327 11509.47 88.58 227.36 30.65 9006.08 1238.20 -1151.37 -816.07 1411.25 215.33 7.74 BP _MWD+IFR+MS 328 11541.60 88.20 227.36 32.13 9006.99 1268.98 -1173.13 -839.69 1442.67 215.59 1.18 BP _MWD+IFR+MS 329 11572.76 87.52 224.59 31.16 9008.15 1298.58 -1194.76 -862.08 1473.31 215.81 9.15 BP _MWD+IFR+MS 330 11604.90 87.34 220.21 32.14 9009.59 1328.43 -1218.47 -883.73 1505.20 215.95 13.63 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 13 of 16 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) 331 11635.58 88.55 217.76 30.68 9010.69 1356.21 - 1242.30 -903.01 1535.82 216.01 8.90 BP_MWD+IFR+MS 332 11667.49 89.34 216.68 31.91 9011.28 1384.69 - 1267.70 -922.31 1567.72 216.04 4.19 BP _MWD+IFR+MS 333 11698.69 88.86 213.79 31.20 9011.77 1412.04 - 1293.18 -940.31 1598.91 216.02 9.39 BP _MWD+IFR+MS 334 11730.27 89.10 212.85 31.58 9012.33 1439.19 - 1319.57 -957.65 1630.45 215.97 3.07 BP _MWD+IFR+MS 335 11762.07 88.10 211.49 31.80 9013.11 1466.20 - 1346.48 -974.58 1662.17 215.90 5.31 BP _MWD+IFR+MS 336 11793.38 87.45 210.12 31.31 9014.33 1492.38 - 1373.35 -990.60 1693.33 215.80 4.84 BP _MWD+IFR+MS 337 11825.51 88.00 205.64 32.13 9015.60 1518.31 - 1401.72 -1005.61 1725.13 215.66 14.04 BP _MWD+IFR+MS 338 11856.12 88.31 202.70 30.61 9016.59 1541.80 - 1429.63 -1018.13 1755.12 215.46 9.65 BP _MWD+IFR+MS 339 11887.70 88.48 200.83 31.58 9017.47 1565.17 - 1458.94 -1029.84 1785.80 215.22 5.94 BP_MWD+IFR+MS 340 11918.97 87.93 197.34 31.27 9018.45 1587.30 - 1488.47 -1040.06 1815.84 214.94 11.29 BP _MWD+IFR+MS 341 11949.31 87.86 195.29 30.34 9019.57 1607.71 - 1517.57 -1048.57 1844.59 214.64 6.76 BP _MWD+IFR+MS 342 11981.72 88.10 193.86 32.41 9020.71 1628.78 - 1548.92 -1056.72 1875.05 214.30 4.47 BP _MWD+IFR+MS 343 12012.66 88.27 192.13 30.94 9021.69 1648.24 - 1579.05 -1063.68 1903.89 213.96 5.62 BP _MWD+IFR+MS 344 12043.73 87.07 193.32 31.07 9022.95 1667.66 - 1609.33 -1070.51 1932.86 213.63 5.44 BP _MWD+IFR+MS 345 12075.86 86.80 192.42 32.13 9024.67 1687.79 - 1640.61 -1077.66 1962.89 213.30 2.92 BP _MWD+IFR+MS 346 12107.92 86.52 190.95 32.06 9026.54 1707.36 - 1671.95 -1084.14 1992.68 212.96 4.66 BP _MWD+IFR+MS 347 12138.06 86.83 187.75 30.14 9028.29 1724.76 - 1701.64 -1089.03 2020.28 212.62 10.65 BP _MWD+IFR+MS 348 12170.62 86.63 184.78 32.56 9030.15 1742.11 - 1733.94 -1092.58 2049.46 212.22 9.13 BP _MWD+IFR+MS 349 12202.49 86.97 182.37 31.87 9031.93 1757.82 - 1765.70 -1094.56 2077.44 211.79 7.63 BP _MWD+IFR+MS 350 12233.74 86.73 181.55 31.25 9033.64 1772.45 - 1796.89 -1095.63 2104.57 211.37 .2.73 BP _MWD+IFR+MS 351 12265.12 87.66 178.39 31.38 9035..18 1786.17 - 1828.22 -1095.61 2131.38 210.93 10.49 BP _MWD+IFR+MS 352 12297.22 88.20 178.99 32.10 9036.34 1799.57 - 1860.29 -1094.88 2158.58 210.48 2.51 BP _MWD+IFR+MS 353 12328.38 87.72 175.20 31.16 9037.45 1811.78 -1891.39 -1093.30 2184.64 210.03 12.25 BP _MWD+IFR+MS 354 12360.25 88.48 173.64 31.87 9038.50 1822.90 - 1923.09 -1090.20 2210.61 209.55 5.44 BP _MWD+IFR+MS 355 12391.34 88.48 172.73 31.09 9039.33 1833.11 - 1953.95 -1086.52 2235.72 209.08 2.93 BP _MWD+IFR+MS 356 12422.88 88.34 170.56 31.54 9040.20 1842.66 -1985.14 -1081.93 2260.83 208.59 6.89 BP _MWD+IFR+MS 357 12453.64 87.96 167.74 30.76 9041.20 1850.70 -2015.33 -1076.15 2284.66 208.10 9.25 BP _MWD+IFR+MS 358 12484.91 89.03 165.06 31.27 9042.02 1857.41 -2045.71 -1068.80 2308.09 207.59 9.23 BP _MWD+IFR+MS 359 12516.36 89.16 162.03 31.45 9042.51 1862.62 -20.75.86 -1059.89 2330.79 207.05 9.64 BP _MWD+IFR+MS 360 12548.43 89.37 158.21 32.07 9042.93 1866.04 -2106.01 -1048.99 2352.80 206.48 11.93 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 14 of 16 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) (f t) (ft) (ft) (deg) 100f) type (deg) 361 12579 16 90 06 155.78 30.73 9043.08 1867.65 - 2134.30 - 1036.98 2372.88 205.91 8.22 BP _MWD+IFR+MS 362 12608.83 89.64 152.74 29.67 9043.16 1867.78 - 2161.02 - 1024.10 2391.40 205.36 10.34 BP _MWD+IFR+MS 363 12641.53 89.82 150.40 32.70 9043.31 1866.40 - 2189.78 - 1008.53 2410.86 204.73 7.18 BP _MWD+IFR+MS 364 12672.69 89.95 146.89 31.16 9043.37 1863.49 - 2216.38 -992.32 2428.38 204.12 11.27 BP _MWD+IFR+MS 365 12702.65 89.92 143.87 29.96 9043.41 1859.00 - 2241.03 -975.30 2444.06 203.52 10.08 BP _MWD+IFR+MS • 366 12734.46 89.88 141.82 31.81 9043.46 1852.85 - 2266.38 -956.09 2459.80 202.87 6.45 BP _MWD+IFR+MS 367 12765.54 90.23 139.05 31.08 9043.43 1845.56 - 2290.34 -936.29 2474.33 202.23 8.98 BP _MWD+IFR+MS 368 12796.70 90.06 137.47 31.16 9043.35 1837.10 - 2313.59 -915.55 2488.16 201.59 5.10 BP _MWD+IFR+MS 369 12829.16 89.20 135.16 32.46 9043.56 1827.24 - 2337.06 -893.13 2501.91 200.91 7.59 BP _MWD+IFR+MS 370 12860.46 89.37 136.21 31.30 9043.96 1817.41 - 2359.46 -871.27 2515.18 200.27 3.40 BP _MWD+IFR+MS 371 12890.35 89.78 136.72 29.89 9044.18 1808.40 - 2381.12 -850.68 2528.52 199.66 2.19 BP _MWD+IFR+MS 372 12922.47 90.23 136.85 32.12 9044.17 1798.90 - 2404.53 -828.69 2543.32 199.02 1.46 BP _MWD+IFR+MS 373 12954.53 90.33 136.78 32.06 9044.02 1789.43 - 2427.91 -806.75 2558.43 198.38 0.38 BP _MWD+IFR+MS 374 12985.90 90.06 136.62 31.37 9043.91 1780.10 -2450.74 -785.23 2573.46 197.77 1.00 BP _MWD+IFR+MS 375 13018.15 89.92 136.53 32.25 9043.92 1770.44 -2474.16 -763.06 2589.16 197.14 0.52 BP _MWD+IFR+MS 376 13049.39 89.64 136.83 31.24 9044.04 1761.14 -2496.89 -741.63 2604.70 196.54 1.31 BP _MWD+IFR+MS 377 13079.94 90.06 137.66 30.55 9044.12 1752.33 - 2519.32. -720.89 2620.43 195.97 3.04 BP _MWD+IFR+MS 378 13111.15 90.43 136.21 31.21 9043.98 1743.17 - 2542.12 -699.58 2636.63 195.39 4.79 BP _MWD+IFR+MS 379 13141.89 90.50 135.93 30.74 9043.73 1733.71 - 2564.26 -678.26 2652.44 194.82 0.94 BP _MWD+IFR+MS 380 13173.69 90.33 135.69 31.80 9043.50 1723.78 -2587.06 -656.09 2668.96 194.23 0.92 BP _MWD+IFR+MS 381 13205.05 90.33 135.66 31.36 9043.32 1713.92 -2609.49 -634.18 2685.45 193.66 0.10 BP _MWD+IFR+MS • 382 13236.08 90.06 135.54 31.03 9043.22 1704.13 -2631.66 -612.47 2701.99 193.10 0.95 BP _MWD+IFR+MS 383 13268.12 89.75 135.25 32.04 9043.27 1693.91 -2654.48 -589.97 2719.25 192.53 1.32 BP _MWD+IFR+MS 384 13299.05 89.27 133.99 30.93 9043.54 1683.65 -2676.20 -567.96 2735.80. 191.98 4.36 BP _MWD+IFR+MS 385 13330.32 89.27 134.35 31.27 9043.93 1673.04 -2697.99 -545.53 2752.59 191.43 1.15 BP _MWD+IFR+MS 386 13361.54 89.47 135.27 31.22 9044.28 1662.78 -2719.99 -523.38 2769.88 190.89 3.02 BP _MWD+IFR+MS 387 13393.26 89.20 134.24 31.72 9044.65 1652.32 -2742.32 -500.86 2787.68 190.35 3.36 BP _MWD+IFR+MS 388 13424.01 89.37 132.20 30.75 9045.03 1641.42 -2763.37 -478.45 2804.49 189.82 6.66 BP _MWD+IFR+MS 389 13455.65 89.34 130.00 31.64 9045.39 1629.10 -2784.17 -454.61 2821.04 189.27 6.95 BP _MWD+IFR+MS 390 13486.50 89.75 126.15 30.85 9045.63 1615.62 -2803.19 -430.33 2836.03 188.73 12.55 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 15 of 16 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) 10Of) type (deg) --- 391 -------- 13517.66 ------ 89.75 ------- 123.47 31.16 9045.77 1600.42 -2820.98 -404.75 2849.87 188.17 8.60 BP_ MWD+IFR+MS 392 13548.87 90.50 121.06 31.21 9045.70 1584.01 -2837.64 -378.36 2862.75 187.59 8.09 BP_ MWD+IFR+MS 393 13579.93 90.19 117.65 31.06 9045.51 1566.36 -2852.86 -351.30 2874.41 187.02 11.02 BP_ MWD+IFR+MS 394 13611.30 89.75 114.58 31.37 9045.53 1547.09 -2866.67 -323.13 2884.82 186.43 9.89 BP_ MWD+IFR+MS 395 13642.69 89.68 111.85 31.39 9045.68 1526.59 -2879.04 -294.29 2894.04 185.84 8.70 BP_ MWD+IFR+MS • 396 13673.87 89.68 110.06 31.18 9045.86 1505.31 -2890.19 -265.17 .2902.33 185.24 5.74 BP_ MWD+IFR+MS 397 13706.40 89.82 107.70 32.53 9046.00 1482.26 -2900.72 -234.39 2910.17 184.62 7.27 BP_ MWD+IFR+MS 398 13737.32 89.71 104.39 30.92 9046.13 1459.30 -2909.26 -204.68 2916.45 184.02 10.71 BP_ MWD+IFR+MS 399 13768.96 89.68 102.80 31.64 9046.29 1434.92 -2916.70 -173.93 2921.88 183.41 5.03 BP_ MWD+IFR+MS 400 13800.86 89.16 100.16 31.90 9046.62 1409.61 -2923.04 -142.67 2926.52 182..79 8.43 BP_ MWD+IFR+MS 401 13832.15 89.64 97.74 31.29 9046.95 1383.97 -2927.91 -111.77 2930.04 182.19 7.88 BP_ MWD+IFR+MS 402 13864.16 89.13 95.52 32.01 9047.29 1357.01 -2931.61 -79.97 2932.70 181.56 7.12 BP_ MWD+IFR+MS 403 13896.38 88.99 92.96 32.22 9047.82 1329.19 -2933.99 -47.85 2934.38 180.93 7.96 BP_ MWD+IFR+MS 404 13927.35 89.71 91.42 30.97 9048.17 1301.89 -2935.17 -16.91 2935.22 180.33 5.49 BP_ MWD+IFR+MS 405 13959.24 90.12 91.60 31.89 9048.22 1273.61 -2936.01 14.97 2936.05 179.71 1.40 BP_ MWD+IFR+MS 406. 13990.60 90.23 91.67 31.36 9048.12 1245.83 -2936.91 46.32 2937.27 179.10 0.42 BP_ MWD+IFR+MS 407 14021.06 90.30 92.12 30.46 9047.98 1218.91 -2937.91 76.76 2938.92 178.50 1.50 BP_ MWD+IFR+MS 408 14052.84 90.40 91.77 31.78 9047.79 1190.83 -2938.99 108.52 2941.00 177.89 1.15. BP_ MWD+IFR+MS 409 14084.08 91.05 90.56 31.24 9047.39 1163.04 -2939.63 139.75 2942.95 177.28 4.40 BP_ MWD+IFR+MS 410 14114.73 91.26 91.04 30.65 9046.77 1135.69 -2940.06 170.40 2944.99 176.68 1.71 BP_ MWD+IFR+MS 411 14145.75 91.08 91.43 31.02 9046.14 1108.11 -2940.72 201.40 2947.61 176.08 1.38 BP_ MWD+IFR+MS , 412 14178.57 91.08 92.26 32.82 9045.52 1079.10 -2941.78 234.20 2951.09 175.45 2.53 BP_ MWD+IFR+MS 413 14209.82 90.19 91.02 31.25 9045.17 1051.42 -2942.68 265.43 2954.62 174.85 4.88 BP_ MWD+IFR+MS 414 14241.27 89.75 88.90 31.45 9045.19 1023.14 -2942.65 296.88 2957.59 174.24 6.88 BP_ MWD+IFR+MS 415 14272.92 89.54 87.45 31.65 9045.39 994.27 -2941.65 328.51 2959.93 173.63 4.63 BP_ MWD+IFR+MS 416 14305.25 89.88 86.40 32.33 9045.55 964.49 -2939.91 360.80 2961.97 173.00 3.41 BP_ MWD+IFR+MS 417 14336.69 89.82 86.32 31.44 9045.63 935.42 -2937.92 392.17 2963.97 172.40 0.32 BP _MWD+IFR+MS 418 14367.57 89.71 86.54 30.88 9045.76 906.87 -2935.99 422.99 2966.31 171.80 0.80 BP _MWD+IFR+MS 419 14398.40 90.06 86.78 30.83 9045.82 878.42 -2934.20 453.77 2969.08 171.21 1.38 BP_ MWD+IFR+MS 420 14430.32 89.88 87.35 31.92 9045.84 849.06 -2932.56 485.65 2972.50 170.60 1.87 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 4-May-2007 18:23:53 Page 16 of 16 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) 421 14461 86 89.88 88.00 31.54 9045.90 820.17 - 2931.28 517.16 2976.55 169.99 2.06 BP _MWD+IFR+MS 422 14492.87 89.92 87.41 31.01 9045.96 791.78 - 2930.04 548.15 2980.87 169.40 1.91 BP _MWD+IFR+MS 423 14525.44 89.75 87.03 32.57 9046.05 761.85 - 2928.46 580.68 2985.48 168.78 1.28 BP _MWD+IFR+MS 424 14556.49 89.88 82.66 31.05 9046.15 732.83 - 2925.67 611.59 2988.91 168.19 14.08 BP _MWD+IFR+MS 425 14588.17 89.75 77.77 31.68 9046.25 702.42 - 2920.29 642.80 2990.20 167.59 15.44 BP MWD+IFR+MS _ 426 14620.02 90.02 77.39 31.85 9046.32 671.47 - 2913.44 673.91 .2990.36 166.98 1.46 BP _MWD+IFR+MS 427 14651.87 90.36 74.46 31.85 9046.21 640.31 - 2905.69 704.80 2989.95 166.37 9.26 BP _MWD+IFR+MS 428 14704.41 90.84 71.01 52.54 9045.66 588.39 - 2890.10 754.96 2987.08 165.36 6.63 BP _MWD+IFR+MS 429 14716.17 90.45 69.86 11.76 9045.53 576.70 - 2886.17 766.04 2986.10 165.14 10.33 BP _MWD+IFR+MS 430 14746.66 89.90 69.64 30.49 9045.44 546.37 - 2875.61 794.65 2983.39 164.55 1.94 BP _MWD+IFR+MS 431 14776.85 90.24 67.86 30.19 9045.40 516.28 - 2864.67 822.78 2980.49 163.98 6.00 BP _MWD+IFR+MS 432 14807.37 89.49 65.00 30.52 9045.47 485.79 - 2852.47 850.75 2976.64 163.39 9.69 BP _MWD+IFR+MS 433 14839.92 89.01 62.38 32.55 9045.90 453.25 - 2838.05 879.93 2971.32 162.77 8.18 BP _MWD+IFR+MS 434 14871.39 89.11 58.73 31.47 9046.41 421.84 - 2822.58 907.32 2964.83 162.18 11.60 BP _MWD+IFR+MS 435 14900.69 89.62 55.10 29.30 9046.74 392.77 -2806.59 931.87 2957.25 161.63 12.51 BP _MWD+IFR+MS 436 14934.26 89.56 53.94 33.57 9046.98 359.66 -2787.11 959.20 2947.55 161.01 3.46 BP _MWD+IFR+MS 437 14963.93 89.97 51.05 29.67 9047.10 330.59 - 2769.04 982.74 2938.26 160.46 9.84 BP _MWD+IFR+MS 438 14994.87 90.17 47.76 30.94 9047.06 300.66 - 2748.91 1006.23 2927.29 159.90 10.65. BP _MWD+IFR+MS 439 15026.99 90.48 45.53 32.12 9046.88 270.00 - 2726.86 1029.58 2914.76 159.32 7.01 BP _MWD+IFR+MS 440 15057.47 91.03 42.72 30.48 9046.48 241.34 -2704.99 1050.80 2901.92 158.77 9.39 BP _MWD+IFR+MS 441 15088.79 91.41 41.46 31.32 9045.81 212.29 -2681.75 1071.78 2888.00 158.22 4.20 BP _MWD+IFR+MS , 442 15121.71 90.82 41.58 32.92 9045.17 181.88 -2657.11 1093.60 2873.36 157.63 1.83 BP _MWD+IFR+MS 443 15152.53 91.03 42.02 30.82 9044.67 153.35 -2634.14 1114.14 2860.07 157.07 1.58 BP _MWD+IFR+MS 444 15184.51 91.34 41.67 31.98 9044.01 123.74 -2610.32 1135.47 2846.59 156.49 1.46 BP _MWD+IFR+MS 445 15216.00 90.58 38.50 31.49 9043.49 94.96 -2586.23 1155.74 2832.73 155.92 10.35 BP _MWD+IFR+MS 446 15247.74 89.86 35.87 31.74 9043.36 66.63 -2560.95 1174.93 2817.61 155.36 8.59 BP _MWD+IFR+MS 447 15279.54 90.07 36.32 31.80 9043.38 38.53 -2535.25 1193.66 2802.20 154.79 1.56 BP _MWD+IFR+MS 448 15308.48 90.21 37.06 28.94 9043.31 12.82 -2512.05 1210.95 2788.69 154.26 2.60 BP _MWD+IFR+MS 449 15365.00 90.21 37.06 56.52 9043.11 -37.57 -2466.94 1245.01 2763.31 153.22 0.00 Pr oject to TD • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska- Inc. Dispatched To: Christine Mahnken (AOGCC) Well No 03-36A Date Dispatched: 9-Apr-07 Installation/Rig Nabors 7ES Dispatched By: Nate Rose LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Johnson RECBIVed By: ~ BP Exploration (Alaska) Inc. r Petrotechnical Data Center (LR2-1) SCI Vw~ ~~'~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com ~ ~~ - c,~~ 05/29/07 d~s~~~~~~s~~~s~ NO.4249 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2x38 Attn: Christine Mahnken ATTN: Beth ~.~~~" ~;~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WPII _Inh $ Inn new ..+L,.. n~+., el r..l.... nn 06-24A 11637328 RST 04/16/07 1 1 L2-16 11414768 RST 70/07/06 1 1 06-07 11637123 RST 05/06/07 1 1 06-21A 11628766 MCNL 04/09/07 1 1 F-09A 11657123 CBL 05/06107 1 09-15 11630475 CEMENT IMAGE LOG 05/06/07 1 03-36A 11745217 USIT CORROSION 05/03/07 1 03-36A 11745217 USIT CEMENT 05/03/07 1 , ~.-.-.vim .~v~~,~v ~~~.~vv~ ,~~v~~ ~IYV RG 1 YRIYIIYV VIYC liVl~ i CNli1'1 1 V: BP Exploration (Alaska) Inc. ~ ~ _ ~ ~ ,~ Petrotechnical Data Center LR2-1 - r 900 E. Benson Blvd. Anchorage, Alaska 99508 ~;p~~ ~ ~~'~~~ Date Delivered: fl ~. ~ per. C~F~a ~ nQ,~'.~°, , ~ F<)1I I Y {:., ._ ~3~#":h i*~:~~` Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,~ ~ ~/ Received by: /lj~-~ .-.,.~. 05/15/07 SChlumber~ge~r NO. 4024 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchors e, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth f ~-- ~ 333 West 7th Ave, Suite 100 J `-.'~~ Anchorage, AK 99501 Field: Prudhoe Bay Well Jeb # Lea Descrintien Data Bt Celnr CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 L3-30 11637115 PRODUCTION PROFILE 03/19107 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 L3-12 11686732 PRODUCTION PROFILE 04/08/07 1 02-29C NIA EMIT & CALIPER IMAGE 04/17/07 1 DS 02-36 11637141 MULTI-FINGER CALIPE 03/14/07 1 F-16A N/A SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20/07 1 A-30A 11628762 MEM CBL 03/13/07 1 03-36A 11637326 USIT (CORROSION) 04112/07 1 03-36A 11637326 USIT (CEMENT) 04!12!07 1 DS 17-05 11594492 USIT 04124107 1 DS 03-01 11630462 USIT 03/11/07 1 YLtASt HIiRNV WLtUlSt KtGtIY I CT 5119NIN19 ANU Kt 1 UKNIN(7 VNt I:UYT tAGK 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. _ - - f,, ~~ Anchorage, Alaska 99508 ~ ' „~~I-- ~~ Date Delivered: ~j ii ii. ~a1 .. .1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth Received by: C~ • BOP Test on Nabors 7ES Subject: BOP Test on Nabors 7ES From: "Gagliardi, S11anE'T" <Shane.Gagliardi ct bp.com> Date: Sat, OS May 2007 11:28:4(1 -0800 ao~- o a v3-~~~ 'to: tom ~~~a~.ndcrr~i:admin.slate.ak.us CC: "NSU, ~~D~~' Drl~ Rig 7ES" ~-NSI_~_~D~VDrI~Ri~ia BP.corll-> "Hobbs. (~cc`~ S (:4\ICl" <~=Grc~. Hobbs~ubp.cori~=~ Tom, Thanks for the speedy response. As per our conversation, we are currently laying down perf guns and will be picking up our completion within the next hour running it to the tie back sleeve in the liner top packer @ 10,416'. We will not need to change the BOP configuration or ram sizes to run the completion. We were due for a BOP test by 23:59 on 5/5/07, but are planning to have the the tree on and well secured by noon 5/6/07. I would suspect that the nipple down process would begin four or five hours after the midnight deadline. We have two BOP tests on record for this well, the first was on 4/10/07 and the second was during the intermediate drilling phase on 4/22/07, both without incident. with the granted verbal approval, we will scheduled BOP test. Thanks again for the concurrence procedure in place. proceed with the operation foregoing the speedy resopnse with the new commissioner Thanks, Shane 1 of 1 5/7/2007 12:26 PM 03-36A FIT for 6-I/8" hole Subject: 03-36A FIT for 6-I/8" hole From: "Gagliardi, Shanc T" <Shane.Gagliardi ~r~bp.com> Date: Sun, 22 Apr 2(1117 ? 1:06:56 -0800 To: fhonr~s ~~Iaundcr ~~tani n7aunder(ci-aclmitl.state.~~k.us-~~ CC: "'~SC1, AD~V Di~lg Rig 7 ES" ~~~NS~`ADWI~rI~~Ri~~ "I-Iobt~s. Grcg ~ (-1~1C)" <Greg.Holibsr~rE3P.corT~-> "Sc}uil~z. Vlik~l" ~-~~likoLSchul(Iru:BP.con>> Tom, ~~~ Q ~-~ Just wanted to clarify the FIT for the 6-1/8" hole on 03-36A. The FIT will be conducted to 10.Oppg, the program had it listed as both 10.0 and 11.Oppg. I know that your concern is that a FIT be conducted, but wanted to let you know of the change to the approved procedure. The 10.Oppg will give infinite kick tolerance and prove adequate strength at the shoe. I apologize for the confusion. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) 1 of I 4/23/2007 7:24 AM Re: 03-36A FIT • Subject: Re: 03-36A FIT From: Thomas E Maunder <tom_maunder@admin.state.ak.us> Date: Sat, 14 Apr 2007 16:25:43 -0800 ~~-~ ~--~ To: "Gag~iar~li, Shane "[ " -Shanc.Ga~~liardi«i>,bp.com> CC. "Schultz. ;~~1ikcl" <_!~tiktl_SehullLrrc:E3P.com>,"Hobbs, C~r~~ S ~~~NC')" ~~C;rc~~J~~~hhs("u't3P.com=: Thanks for the message Shane. The requirement in 25.030 is that a LOT or FIT be conducted when drilling or sidetracking out of a casing and you have accomplished that. It appears that you still have a fair differential between the planned MW and the LO EMW. I have also seen "shoes" strengthen as drilling proceeds. Good luck with the operations. Tom Maunder, PE AOGCC ----- Original Message ----- From: "Gagliardi, Shane T" <Shane.Ga~liard_i~?bp.com> Date: Saturday, April 14, 2007 8:47 am Subject: 03-36A FIT To: Thomas Maunder <tom ma.unde.r~u~adznir:.state.ak.us> Cc: "Schultz, Mikel" <Mikel.Schultz%?BF.com>, "Hobbs, Greg S (ANC)" <Gre~ . Hobbs==%HP . com> Tom, Here is the e-mail you requested when we spoke this morning. Just to recap, we were unable to get the 12.0 ppg FIT listed in the documentation for the drilling permit. we did get 11.0 ppg which givesadequate kick tolerance with an expected 9.4 ppg Cretaceous and 9.6 ppg mud. We feel comfortable proceeding with the drilling operations given the 11.0 ppg FIT. We have seen in the past that the shoe/window gets stronger as we drill ahead and develop a decent mud cake, so the kick tolerance will get even better as we drill ahead. If you have any questions or need any other info, let me know. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) 1 of 1 4!16/2007 8:22 AM • ®~ ~IeT~E~t~A1`I®1`T COle~iISSI®16T ;, Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIAI, GOVERAIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-36A BP Exploration (Alaska) Inc. Permit No: 207-020 Surface Location: 906' FSL, 4381' FEL, SEC. 11, T10N, R15E, UM Bottomhole Location: 1609' FNL, 3162' FEL, SEC. 14, T10N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 Cade, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness required test, contact the Commission's petroleum field inspecto~(90 65 -3607 (pager). C DATED this l~day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMi~N PERMIT TO DRILL ~ ~' 20 AAC 25.005 ~ ~~~E;f\! i '~ 5.., 1=;_~~ 0 6 2007 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory O Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well ~ i~ 16Q-ts. GOtt111N= ^Coalbed Methane [d~d~tes ^ Shale Gas 8 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 03-36A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15365 TVD 9046 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4381' FEL 11 T10N R15E 906' FSL SEC UM 7. Property Designation: ADL 028332 Pool , , , , . , Top of Productive Horizon: 87' FNL, 5053' FEL, SEC. 14, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 10, 2007 Total Depth: 1609' FNL, 3162' FEL, SEC. 14, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,800' 4b. Location of Well (State Base Plane Coordinates): Surface: x-714172 y-5936972 Zone-ASP4 10. KB Elevation Plan (Height above GL): 55.5' feet 15. Distance to Nearest Well within Pool: 610' 16. Deviated Wells: Kickoff Depth: 4900 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3290 Surface: 2410 1&. Casin Pr ram: ' S 'catio ns To >- in De h -Bo m uantit of Cement c.f. or s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1 /2" 7" 26# L-80 BTC-M /TCII 5826' 4750' 4227' 10576' 8678' 169 sx 'G' 565 sx LiteCrete 167 sx 'G' 6-1/8" 4-1/2" 12.6# L-80 TCII 4939' 10426' 8575' 15365' 9046' 583 sx Class'G' 1 g, PRESE NT WELL'GONDITION SUMMARY (To be completed for RedrilLand Re-entry Operations) Total Depth MD (ft): 12569 Total Depth TVD (ft): Plugs (measured): 9170 11728 Effective Depth MD (ft): 11728 Effective Depth TVD (ft): 8590 Junk (measured): 12559 ".Casing Length ize Cement Volume MD TV Conductor /Structural g0' 20" 281 cu ft Arcticset 111' 111' Surface 3946' 13-3/8" 1517 sx CS III 400 sx'G' 165 sx CS II 3977' 3732' Intermediate 11869' 9-5/8" 1210 sx Class'G' 11901' 8708' Pr ducti n Liner 826' 7" 180 sx Class 'G' 11743' - 12569' 8600' - 9170' Perforation Depth MD (ft): 12080' - 12314' Perforation Depth TVD (ft): 8836' - 8998' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Shane Gagliardi, 564-5251 Printed Name Gre o bs Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4191 Date " ;~ ~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number:.?D D D API Number: 50-029-22340-01-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval ~-y If box is checked, well may not be used to explore for, test, or produce Coalbed metJhane, gas hydrates, or gas contained shales: I,-~1/ +i~L°~` ~ ~~~~~ ~~, ` Samples Req'd: ^ Yes L~J No Mud Log Req'd: Yes t!7 No ~' ~ ~~ HZS Measures: [~ Yes ^ No ire onal Survey Req'd: ~ Yes ^ No Other: ~OQ~ P~~` ~~~ ~ST ~~k~v~~.~ ©Q~c'~;~\ ~ ~ I~~~~~ ~~~~~ ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 V (~/ ~~/ Submit In Duplicate r Planned Well Summary Well 03-36A Well Horizontal Target Zone 2 T e Sidetrack Ob"ective AFE Number: API Number: 50-029-22340-01 Surface Northin Eastin Offsets TRS Location 5,936,971.55 714,172.22 906' FSL / 899' FWL 10N, 15E, 11 T r t Northin Eastin Offsets TRS ge a ' ' L ti n 5,935,960 713,530 87 FNL / 227 FWL 10N, 15E, 14 oca o s 5,934,110 715,070 1980' FNL / 1712' FWL 10N, 15E, 14 Bottom Northin Eastin Offsets TRS Location 5,934,493 715,465 1609' FNL / 2118' FWL 10N, 15E, 14 Planned KOP: 4,900' and / 4,319' tvd Planned TD: 15,365' and / 9,046' tvd Ri Nabors 7ES CBE: 27.0' RTE: 55.5' Directional Program A roved Well Ian: Wpb Exit oint: 4,900' and / 4,319' tvd Maximum Hole Inclination: ~90° in the tanned 6-%8" roduction section @ 13,121' md. Proximity Issues: All surrounding wells pass major risk criteria. Wells 03-33 and 03-30 are the closest neighboring wells at 484.1' (7,083' md) and 476.28' (9,097' md) res ectivel . Survey Program: Standard MWD/IIFR/MS. Nearest Well within Pool: 610 ft. to the nearest well 03-20A at to of Ivishak Nearest Pro ert Line 18,800 ft. east to the Prudhoe Ba Unit Bounda Logging Program Hole Section: Required Sensors /Service 8-'/2" Intermediate: Real time MWD Dir/GR/Res/PWDNibration throughout the interval. Will require rotary steerable w/ gamma at bit for intermediate casing pick due to the Lower Cretaceous Unconformit . 6-%6" Production: Real time MWD Dir/GR/Res/ABI. Routine Sam tin for HOT identification. Cased Hole: USIT in Intermediate liner. O en Hole: None 03-36A Sidetrack Page 1 • Mud Program r Hole Section / o eration: Mill window in the 9 5/e" casin at 4,900' and T e Densit MBT PV YP API FL H LSND 9.5 N/C 16-30 30-35 <6.0 9.0 - 10.0 Hole Section /operation: Drilling 8-'/z" interval from 4,900' and to 200' above THRZ T e Densit MBT PV YP API FL H LSND 9.5 - 9.8 <20 10-18 18-28 4,0 - 7.0 9.0 - 10.0 Hole Section / o eration: Drillin 8-'/2" interval from THRZ to TD T e Densit MBT PV YP API FL H LSND 10.3 <20 12-22 18-28 4.0 - 6.0 9.0 - 10.0 Hole Section / o eration: Drillin 6-%8" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.5 >20,000 6 - 12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8-'/2" 7" 26.0# L-80 BTC-M / TC-II 5,826' 4,750' / 4,227' 10,576' / 8,678' 6-%" 4-~/z" 12.6# L-80 TC-II 4,939' 10,426' / 8,575' 15,365' / 9,046' Tubin 4-~h" 12.6# L-80 TC-II 10,426' Surface 10,426' / 8,575' Casing /Formation Integrity Testing Test Test Point Test Type Test Pressure Cement P&A Plu Plu to surface Tubin 30 min recorded 4,000 si surface 9 5/8" casin Bride lu to surface 30 min recorded 4,000 si surface 9 5/8" casin 20' new formation FIT 11.5 EMW 7" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4 ~/2" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface 4-~/z" roduction tubin 7" x 4-~h" acker to surface 30 min recorded 4,000 si surface 03-36A Sidetrack Page 2 Cementing Program Casin Strin 7", 26#, 13Cr-80, BTC-M P&A Plu Slurry Design Basis: Lead slurry: None planned. Tail slurry: 673' of 7" 29# casing, 69' of 9 5/" 47# casing w/ 63' of 4-1/z" 12.6# tubin Pre-Flush None Planned Fluid S /V l S acer None Planned s equence o ume: Lead Slur None tanned Tail Slur 30 bbl / 169 cf / 169 sxs Class `G', 17.0 ; 1.00 cf/sk. Casin Strin 7", 26#, L-80, BTC-M / TC-II Intermediate Liner Lead slurry: 4,676' of 7" x 8-'/z" annulus with 40% excess Slurry Design Basis: Tail slurry: 1,000' of 7" x 8-'/z" annulus with 40% excess, plus 80' of 7", 26# ' " ' " ' ' shoe track, plus 150 of 7 x 9 b/8 liner lap, plus 200 of 9 5/8 x 4 drill pipe annulus. Pre-Flush None tanned Fluid S /V l S acer 40 bbls MudPUSH at 11.0 s equence o ume: Lead Slur 163 bbls / 916 cf / 565 sxs Litecrete; 12.0 ; 1.62 cf/sk. Tail Slur 34.7 bbl / 195 cf / 167 sxs Class `G', 15.8 ; 1.17 cf/sk. Casin Strin 4-'/z", 12.6#, L-80, TC-II Solid Production Liner Lead slurry: none planned Slurr Desi n Basis: y g Tail slurry: 4,789' of 4-~/z" x 6-%8', annulus with 40% excess, plus 80' of 4-~/z", " " " ' 12.6# shoe track, plus 150 of 7 x 4-~/z liner lap, plus 200 of 7 x 4 drill pipe annulus. Pre-Flush None Planned Fluid S /V l S acer 40 bbls MudPUSH at 11.0 s equence o ume: Lead Slur None tanned Tail Slur 121.5 bbl / 683 cf / 583 sx Class `G', 15.8 ; 1.17 cf/sk. 03-36A Sidetrack Page 3 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8-'/z" Intermediate Interval Maximum Anticipated BHP: 3,290 psi at 6,400' TVD; WS2 Cretaceous Leak Maximum Surface Pressure: 2,410 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated Kick Tolerance: 50.0 bbls with 11.5 ppg EMW FIT with 10.3 ppg mud Planned BOPE Test Pressure: 250 psi low / 4,000 psi high for both sets of pipe rams 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations BOPE Configuration for 7" C/O to 7" pipe rams while running 5,526' of 7" liner. Bonnets will be Drilling Liner. tested as per AOGCC regulations. Across over with "TIW" valve will be on hand Burin this o eration. Well Interval: 6-%8" Production Interval Maximum Antici ated BHP: 3,290 si at 8,800' TVD Ivishak Pressure Maximum Surface Pressure: 2,410 pSl (based upon BHP and a full column of gas from TD (~ 0.10 psi/ft) Calculated Kick Tolerance: Infinite with 10.0 EMW FIT w/ 8.5 pp mud. Planned BOPE Test Pressure: 250 si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned Com letion Fluid: 8.4 seawater / 7.1 pp Diesel DISpOSaI Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 03-36A Sidetrack Page 4 • Geologic Prognosis • Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation TVDss feet Yes/No Psi) EMW NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV4 3005 +/- 50' SV7 4220 +/- 50' UG4 4865 +/- 50' UG3 4980 +/- 50' UG1 5855 +/- 50' WS2 6390 +/- 50' WS1 6610 +/- 50' CM3 6845 +/- 50' CM2 7335 +/- 50' CM1 8015 +/- 50' THRZ 8409 +/- 50' BHRZ 8593 +/- 50' LCU 8606 +/- 50' TSHA 8622 +/- 50' TSAD 8672 +/- 30' Y 3250 ~ 8800' 7.1 C 8800' 45N 8681 +/- 30' Y 45P 8684 +/- 30' Y 44N 8713 +/- 30' Y 44P 8715 +/- 30' Y 43N 8732 +/- 30' Y 43P 8736 +/- 30' Y 42N 8780 +/- 30' Y 42P 8814 +/- 30' Y 31 N 8836 +/- 30' Y 31 P 8837 +/- 30' Y 27N 8898 +/- 30' Y 27P 8899 +/- 30' Y 26N 8956 +/- 30' Y 26P 8957 +/- 30' Y 25N 8995 +/- 30' Y MHO/HOT 9005 +/- 30' Y TD Criteria: Drill plan and TD well at Target 6 (BHL ASP Coordinates). Fault Prognosis The proposed 03-36A well has been designed to avoid seismically recognizable faults. 03-36A Sidetrack Page 5 ' ~ 03-36 A Operations Summary Pre-Riq Operations: 1. MITOA to 3,000 psi. 2. Bleed OA, IA and T to 0 psi. Test PPPOT -T&IC to 5,000 psi for 30 minutes. 3. Pull Tailpipe plug at 11,728' md. 4. Run static pressure survey to determine BHP for proper mud weight during drilling operations and BHT for proper cement blend. 5. Circulate out freeze protect and fluid-pack the well to seawater or kill-weight fluid. 6. R/U coiled tubing. RIH and plug and abandon the open perforations (376' from 12,062' -12,438') with a minimum of 891' (>31 bbls) of 15.8ppg class `G' cement from PBTD C~ 12,569' to 11,626'. 7. Pressure test the cement plug to 3,500 psi for 30 minutes. 8. Drift the 5-'/z", 17#, 13Cr80 NSCC tubing to estimated TOC @ 11,626' md. Tag cement to verify TOC depth. 9. Pull lowest GLM Q 11,601: 10. Circulate the well to seawater through the GLM until returns are clean. 11. Bleed casing and annulus pressures to zero. Freeze protect to 2,200' and with diesel. 12. Replace GLM @ 11,601. 13. Pressure test tubing to 3,000 psi for 30 minutes. 14. Function all tubing and casing Lock Down Screws. Repair and replace as necessary. 15. Set a BPV. Well house and flow line are not currently installed. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 7ES 2. Pull BPV. Circulate out diesel freeze protection and displace the well to kill weight fluid. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. Pull TWC. 4. MIRU SWS. RIH with the appropriate jet cutter and cut the 5-'/2" tubing at 11,580' md. 5. R/U. Pull 5-'h" tubing from the cut at 11,580' and and above. Send tubing in for inspection. 6. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH to 5,000' md. POOH. Run USIT from 5,000' and to surface. ~~~~ 7. Evaluate USIT for condition of the 9 5/" casing. Estimated cement top is 2,900' md. 'i ,J"~ 8. RIH with HES EZSV on E-line. Set bridge plug at 4,911 and elm, as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 9. Pressure-test the 9 5/8" casing to 4,000 psi for 30 minutes. Record test. Chase leaks down if necessary. 10. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly on 5" DP. Orient whip stock as desired and set on bridge plug. Shear off of whip stock. 11. Displace the well to 9.5 ppg LSND based milling fluid. Completely displace the well prior to beginning millin o erations. 12. Mill window in 9-5/" casing at ± 4,900' md, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 9 S/8' casing and conduct an FIT to 12.0 ppg EMW. POH. 14. M/U 8-'/2" Dir/ R R PW P ri ki k ff n rill h -'/" i G/ es/ D ower D ve assembly. RIH, c o add t e 8 2 ntermediate section to 100' above the HRZ with 9.5 - 9.8 ppg LSND. ~: ~ 15. By 10,041' and (150' above the top of the HRZ) have the entire circulating system weighted up to >~ 10.3 ppg with spike fluid from the MI plant. y'C7+ 16. Continue drilling ahead in the 8-'/z" hole section to the top of the Shublik, per directional proposal. The (~~~ Sag River has been eroded by the LCU. Circulate well clean, short trip to window as necessary. POOH. 17. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 18. If necessary, run and cement a 7", 26.0#, L-80 scab liner to within 300' of surface casing shoe as needed to cover any potentially bad portions of intermediate casing indicated by USIT. 19. POOH and LD 5" DP. 20. M/U 6-%e" Dir/GR bent housing motor w/ roller cone bit on 4" DP. RIH to the 7" liner landing collar. Test to 4,000 psi. 21. Drill out the 7" liner float equipment and cement to the shoe. 22. Displace the well to 8.4 ppg Flo-Pro SF drilling fluid. 23. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. `~~ ~~~ C~~ 03-36A Sidetrack Page 6 • 24. Drill ahead to the end of the 8°/100' DLS build section. Should be horizontal at this point. POOH. 25. M/U 6-%6" Dir/GR/Res PDM 1.5° assembly. 26. Drill ahead to TD per directional proposal. 27. Circulate well bore clean (at least 3x bottoms up) at max rate. Circulate and short trip to shoe as necessary. POOH. 28. Run and cement 4-~h", 12.6#, L-80, TC-II solid production liner w/ swell packers. POOH. 29. RIH with DPC pert guns. Perf intervals for the first MI bulb will be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 30. R/U and run a 4-~h", 12.6#, L-80, TC-II tubing completion, stinging into the 4-'h" liner tie back sleeve. 31. Reverse circ CI and freeze protect well to 2,200' tvd prior to setting packer. 32. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 33. Set a BPV. 34. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 35. Secure the well. 36. Rig down and move off. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. Phase 1: Move In /Riq Up /Test BOPE Planned Phase Time Planned Phase Cost 66.0 hours $469,156 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - Drill Site 3 is an H2S Pad. Recent H2S data from the pad is as follows: Closest Well to SHL Latest H2S Reading Closest Well to BHL Latest H2S Reading 03-121 N/A 16-15 80 ppm 03-131 N/A 03-35 300 ppm • Max H2S reading on the Pad - 800 ppm 11/24/2001 • There will be H2S treating material for the mud in good condition and sufficient quantity to treat the mud system should H2S be encountered while drilling. • All rig site personnel will have the appropriate H2S training prior to moving on to the well • H2S Training and Drills: • Training. Every person working in an ADW operation in an H2S designated area will have Hydrogen Sulfide and Sulfur Dioxide training. Training will include H2S orientation training provided through the North Slope Training Cooperative, as well as company and rig specific training. Operation-specific training will begin in the Pre-spud meetings, with H2S discussed during Pre- 03-36A Sidetrack Page 7 • • tour HSE meetings, and Weekly Safety meetings for the duration of the operation. Training is to include the following: • explanation of the hazards of H2S and SO2 in produced fluids during drilling operations; • explanation of rig layout including location and use of detection equipment, alarms, prevailing winds, importance of adequate ventilation, use of mechanical blowers, utilization of windsock and wind indictors, and personnel movement in an upwind direction; • emergency response procedures contained in the contingency plan including well control, and evacuation plans (including immediate actions); • location, use and care of self-contained breathing apparatus, emergency escape air bottles, hose lines, etc.; • stationary and portable hydrogen sulfide detection equipment; combustible gas indicator equipment, resuscitation equipment and requirements, portable fire extinguishers, and the emergency alarm system; • use of buddy system, air testing before entering an area, materials selection and the drilling fluid treating procedures. • Drills. Drills with breathing equipment are to be initiated by actuating the H2S alarm. Personnel are to don breathing apparatus and proceed to the previously assigned area in accordance with emergency procedures. Periodically, drills should incorporate working a short period of routine work in the breathing equipment. Following use, cylinders and breathing apparatus shall be refilled and made ready for use. • The Toolpusher will coordinate drills to ensure personnel understand expectations and adequately respond to the alarm. Drills will be conducted before drilling into formations anticipated to contain H2S. • Ensure that the rig H2S monitors have bee calibrated to alarm at 10 ppm and are placed and maintained as per AOGCC regulations and ADW H2S SOP. • Ensure that all personnel have access to respiratory protection as per the ADW H2S SOP. • All personnel are to be clean shaven to the extent that the SCBA face mask seal is effective and a positive fit test is obtained. - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move off of 03-36A. Well 03-12 is 59.69' to the North and well 03-13 is 60.36' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 03-36 well bore will be secured with the following barriers: o Tubing: cement P&A plug (pressure tested), gas lift valves w/ dummies, kill weight fluid, and a BPV (tested from below through GLM). o IA: Annulus valves, kill weight fluid and 9-5/8" x 7" pack-off. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 03-36 well bore will be secured with the following barriers: • Tubing: cement P&A plug (pressure tested), kill weight fluid, and a TWC (tested from below through GLM). • IA: Annulus valves, kill weight fluid and 9 5/" x 7" pack-off. • OA: Annulus valve and kill weight fluid. 03-36A Sidetrack Page 8 - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 38.0 hours $191,116 Reference RP • "De-completions" RP • "Wireline Pressure Control" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - USIT will be run from 4,900' and to surface in cement evaluation and corrosion modes. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 13 5/a" 5,000 psi FMC with 7-'/16" McEvoy tree. Verify with FMC/Cameron that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Records indicate 7" NSCC top and 7" NCSS bottom threads. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 7" Camco Bal-O SSSV at 2,245' md, there are two bare control lines with 55 stainless steel control bands. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 30.0 hours $262,082 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Records from the original primary cement job indicate that the cement top may be as high as 4,391'. The USIT run in the de-complete phase should be used when setting the CIBP / whipstock. - Ensure that the CIBP and whipstock are set at an appropriate depth to avoid mill a collar if possible. - Avoid high WOB. Excessive WOB may cause the mill to walk off of the whipstock face. - Once milling is complete, make sure all BOP equipment is operable. Use jetting/washing tool to ensure that the BOP stack is cleaned thoroughly paying close attention to ram cavities. 03-36A Sidetrack Page 9 • Phase 5: Drill 8-1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 170.0 hours $1,325,810 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Issues and Potential Hazards - Overpressure may exist through the West Sak as indicated by the casing leak @ 8,230' and / 6,426' tvd. Be prepared to weight up to 9.6 ppg and maintain to the top of the HRZ. - For this well, the HRZ/LCU will require a mud weight of 10.3 ppg. Maintain mud weight at 10.3 ppg, minimally, to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 9.6 ppg pore pressure in the WS2 due to injection, a fracture gradient of 11.5 ppg at the 9 5/8" casing window, and 10.3 ppg mud in the hole, the kick tolerance is 50 bbls. If the 11.5 ppg FIT is not reached contact the ODE. - Due to the uncertainty associated with the LCU, gamma at bit on the Power Drive Rotary Steerable system will be used for this hole section to aid in picking the intermediate casing point. Ensure that all hands are familiar with the associated floor hazards due to the increased drill pipe RPM. - If the Kingak is present, there may be an overlaying Lag deposit. This Lag deposit will give similar drilling response to the Sag River Fina. Circulate bottoms up for samples to ensure that Glauconite typical to the Sag River is present. Do not call intermediate casing point without witnessing the Glauconite. - The intermediate hole will be drilled with 5" drill pipe, and the production hole will be drilled with 4" drill pipe. Therefore, there will be additional pipe handling for this well. - Ensure that a Centurion circulating sub is in the string in the event that losses occur. Phase 6: Run and Cement 7" Intermediate Casing and Tieback Planned Phase Time Planned Phase Cost 32.0 hours $577,431 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - The completion design is to run a 7", 26#, L-80, BTC-M solid drilling liner and cement from the intermediate TD of 10,576' to the liner top at 4,750'. - Sufficient 7" liner will be run to extend 150' back up into the 9 5/s" casing. - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ instability problems. 03-36A Sidetrack Page 10 • - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 '/e" Production Hole Interval Planned Phase Time Planned Phase Cost 241.0 hours $1,922,344 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - KICK TOLERANCE: In the worst-case scenario of 7.1 ppg pore pressure, a fracture gradient of 10.0 ppg at the 7" casing shoe, and 8.4 ppg mud in the hole, the kick tolerance is infinite. If this FIT is not reached contact the UDE. - The driller's polygon consists of hard lines due to faults bounding on all sides. Hard lines are not to be crossed. In the event that the drilling assembly does not yield the desired doglegs, a trip will be necessary to adjust the motor bend and/or stabilizer placement. - Ensure that a Centurion circulating sub is in the string in the event that losses occur. - TD will be called upon reaching target 6 in WP6. Phase 9: Run 41h" Production Liner Planned Phase Time Planned Phase Cost 54.6 hours $476,510 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4-'/z", 12.6#, L-80 TC-II solid liner throughout the production interval. - Sufficient 4-~h" liner will be run to extend 150' back up into the 7" liner shoe. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 610 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the 4-'/z" liner top packer is set prior to POH. Phase 10: DPC Perforate Production Liner Planned Phase Time Planned Phase Cost 38.5 hours $141,633 03-36A Sidetrack Page 11 • ~ Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - Ensure that all non-essential personnel are not on the rig floor or in the cellar when the perf guns are being picked up, laid down or are within 100' of the rotary table. - Be prepared for initial losses upon perforating. Phase 12: Run 4-'/z", 12.6#, L-80, TC-II Completion Planned Phase Time Planned Phase Cost 19.5 hours $472,638 Reference RP • "Completion Design and Running" RP • "Casing and Tubing Connections" RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 psia at 100° F. - The completion design will be a 4-~h", 12.6#, L-80, TC-II production tubing string with 7" x 4-'/z" Baker S-3 packer. There will be no GLM's in the completion; therefore, all freeze protection will need to be accomplished prior to setting the packer. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 17.0 hours $57,377 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of 03-36A. Well 03-12 is 59.69' to the North and well 03-13 is 60.36' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. 03-36A Sidetrack Page 12 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The West Sak may be over pressured. A 9.6 ppg EMW may be necessary as indicated by the PC leak 2 8,230' md. The original well drilled this section with a 9.7 ppg, records indicate that a lighter mud weight should be considered. II. Hydrates and Shallow gas A. All hydrates should be covered well above the kick off point. There are significant coal stringers that may present some free gas. The problems most commonly cause by these coal stringers are hole stability and torque problems. III. Lost Circulation/Breathing A. Lost circulation is not expected, but is always possible. The most likely depth for losses to occur in this well close to the intermediate casing point. Due to the uncertainty associated with the Lower Cretaceous Unconformity, losses may be encountered as high as 10,553' md. B. The driller's polygon in the Ivishak Formation is outlined by faults. Losses are not expected, but may be associated to these faults if the directional plan is not maintained. C. Breathing is not expected in this well. IV. Kick Tolerance/Integrity Testing A. The 7" casing will be cemented with 15.8 ppg tail and 12.0 ppg lead cement to the liner top at 4,750' md. a. The Kick Tolerance for the 9-s/8" casing window is 50.0 bbls with 10.3 ppg mud, 11.5 ppg FIT, and a 9.6 ppg pore pressure. Integrity Testing -11.5 ppg EMW FIT B. The 4-'/2" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing is infinte with 8.4 ppg mud, 10.0 ppg FIT and a 7.1 ppg pore pressure. Integrity Testing -10.0 ppg EMW FIT V. Stuck Pipe A. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale give problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. B. Monitor cuttings closely and adjust mud weight accordingly to avoid destabilization. C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide A. Drill Site 3 is designated as an H2S site. Standard Operating Procedures for H2S precautions must be followed at all times. Personal monitors must be worn at all times. Recent H2S data from the pad is as follows: Closest Well to SHL Latest H2S Reading Closest Well to BHL Latest H2S Reading 03-121 N/A 16-15 80 ppm 03-131 N/A 03-35 300 ppm VII. Faults A. 03-36A has been designed to avoid all seismically recognizable faults; therefore, fault related losses are not expected. CONSULT THE E P,AD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 03-36A Sidetrack Page 13 TREE = 7" X 6" CARBON WELLHEAD = _ ACTUATOR = _ ~CM! BAKER KB. ELEV = 60' BF. ELEV = 30' KOP = 2700' Max Angle = 54 @ 5426 Datum MD = 12115' Datum TV D = 8800' SS 13-3/8 Minimum ID = 3.625" @ 12002'-12154' CMT COLLAR 5-1/2" TBG, 17#, 13-CR-80, 4-1/2" TBG, 12.6#, 13-CR-80, 11 11676'-11741' 9-5/8" CSG, 47#, NT-80S 11901' PERFORATION SUMMARY REF LOG: BRCS ON 04/22/93 ANGLE AT TOP PERF: 44 @ 12062' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 6 12062 - 12080 S 10/01/00 12 12080 - 12082 C 10/01/00 6 12082 - 12090 C 10/01/00 12 12090 - 12100 C 10/01/00 6 12100 - 12110 S 10/01/00 6 12206 - 12216 C 07/21 /96 12 12216 - 12226 C 07/21 /96 16 12226 - 12230 C 07/02/96 10 12230 - 12236 C 06/22/96 9 12244 - 12253 S 04/27/96 4 12308 - 12312 C 12/11/93 4 12312 - 12314 C 11/13/93 6 12330 - 12334 S 11/04/93 6 12382-12386 S 11/04/93 6 12430 - 12438 S 07/09/93 7" LNR 29#, 13-CR-80 SA~NOTES: **CHROME TBG 8~ LNR*** 2245, 117" CAMCO BAL-O SSSV NIP, ID = 5.937" 2900' EST CEMENT (06/20/06) 3285' 7" X 5-1/2" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3377 3298 35 LB-1 DMY T-2 0 02/03/00 2 5592 4737 53 LB-1 DMY T-2 0 12/23/96 3 6747 5467 48 LB-1 DMY T-2 0 03/30/96 4 7517 5973 51 LB-1 DMY T-2 0 12/23/96 5 8289 6464 51 LB-1 DMY T-2 0 02/03/00 6 9069 6950 51 LB-1 DMY RA 0 04/29/93 7 9849 7419 53 LB-1 DMY RA 0 04/29/93 8 10631 7904 51 LB-1 DMY RA 0 04/29/93 9 11017 8140 53 LB-1 DMY RA 0 04/29/93 10 11601 8504 49 LB-1 DMY T-2 0 02/03/00 1~ 1621' 115-1/2" PARKER SWN NIP, ID = 4.656" 11676' 5-1/2" X 4-1/2" XO 11678' 9-5/8" X 4-1/2" BAKER, PERMANENT PKR 11711' 4-1/2" PARKER SWS NIP, ID = 3.813" 11728' 4-1/2" PARKER SWN NIP, ID = 3.725" 11728' 4-1/2" PXN TTP (07/19/04) 11741' 4-1/2" TUBING TAIL 11730' ELMDTTLOGNOTAVAILABLE ~ CMT COLLAR, ID = 3.625" ~ 12559' 11 85% OF RUBBER ELEMENT FROM IBP 10/07/97 12564' 1 PERF GUN 07/20!93 1{ 242U' 11 CEMENT REfA INER SET 07/09/93 12569' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 04/29/93 ORIGINAL COM PLEfION 06/20/06 DPS/PJC OA DWN SOZ 04/29/93 LAST WORKOVER 06/27/02 BHGTLH PERF CORRECTIONS 08/09/02 BHGKK PERF CORRECTIONS 07/29/05 LDK/TLH OA DWN SOZ 09/23/05 KSB/TLH PXN TTP SET (07/19/04) PRUDHOE BAY UNff WELL: ~3-36 PERMfT No: 1930190 API No: 50-029-22340-00 SEC 11, T10N, R15E, 2342.75 FEL 3012.63 FNL BP Exploration (Alaska) ~ 03-36 I I 7" TBG, 26#, 13-CR-80, 1 3285' r L0383 bpf, ID = 6.276" " CSG, 68#, NT-80, ID = 3977' TREE = 7" X 6" CARBON WELLHEAD = ACTUATOR = CNV BAKER KB. ELEV = 60' BF. ELEV = 30' KOP = 2700' Max Angle = 91 @ 12450 Datum MD = Datum TV D = 0 3 -3 ~ Pro o s e d sA NOTES: p 13-3/8" CSG, 68#, NT-80, ID = 3977' MINIMUM ID = 3.725" @ 10,48E XN NIPPLE 9-5/8" HES EZSV 4911' 5-1/2" TBG, 17# TBG CUT 11600' 9-5/8" X 4-1/2" BAKER, 11678' PERMANENT PKR 9-5/8" CSG, 47#, NT-80S ~ 11901' 7" LNR, 29#, 13-CR-80 11730'-12.,.,., 4-1/2" HES X NIPPLE, ID = 3.813" EST CEMENT (06/20/06) ,~ 9-5/8" X 7" BOT FLEX LOCK LNR HANGER W/ rte' ZXP PKR W/ 12' TBS 9-5/8" WINDOW 10305' 4-1 /2" HES X NIPPLE, ID = 3.813" 10368' 7" X 4-1/2" BOT S-3 ID = 3.88" 10415' 4-1/2" HES X NIPPLE, ID = 3.813" 10415' 4-1/2" HES XN NIPPLE, ID = 3.725" 10426' 4-1/2" 12.6# L-80 TGII, 0.0152 BPF, ID = 3.958" 10426' 7" X 4-1/2" BOT FLEX LOCK LNR HANGER W~ ZXP PKR W/ 12' TBS 10576' 7" 26# L-80 BTGM, 0.0383 BPF, ID = 6.2760" SWELL PACKER SUMMARY Note: ALL SWELL PACKERS ARE4-1/2" FREECAP 15.75" RUBBER OD TOP SEAL LENGTH MANDREL LENGTH RUBBERTYPE CONNECTION 14779 10 18'8" FSG11 TGII 14279 10 18'8" FSG11 TGII 13779 10 18'8" FSG11 TGII 13279 10 18'8" FSG11 TGII 12779 10 18'8" FSG11 TGII 12279 10 18'8" FSG11 TGII 15279' PBTD 15365' 4-1/2" 12.6# L-80 IBT, 0.0152 BPF, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/06 STG ORIGINAL COMPLETION WELL: 03-36A PERMff No: API No: 50-029-22340-01 SEC 11, T10N, R15E, 2342.75 FEL 3012.63 FNL BP Exploration (Alaska) • • Schlumberger 03-36A (P61 Proposal Report Date: November 16, 2006 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA StructurelSlot: Well: DS-03/03-36 ~~'~~ 03-36 Borehole: ~~ Plan 03-36A ~a UWIIAPI#: 500292234001 Survey Name 1 Date: 03-36A (P6) /November 16, 2006 Tort 1 AHD 1 DDI 1 ERD ratio: 408.954° / 9562.11 ft / 6.822 / 1.057 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location Latllong: N 70.23071908, W 148.27107875 Location Grid NIE YIX: N 5936971.550 ftUS, E 714172.220 ftUS Grid Convergence Angle: +1.62707914° Grid Scale Factor: 0.99995211 Vertical Section Azimuth: 244.000° Vertical Section Origin: TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table TVD Reference Elevation: 55.50 ft relative to MSL Sea Bed I Ground Level Elevation: 27.00 ft relative to MSL Magnetic Declination: 24.151 ° Total Field Strength: 57673.596 nT Magnetic Dip: 80.944° Declination Date: April 21, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corc Mag North -> True North: +24.151 ° Measured Vertical Grevdy Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depdr Section Tool Face ft de de ft ft ft ft ft de d 1100 ft de 100 ft de 100 ft ftUS ftUS Ile-In SUNey 46b`J.IU bl.bU i56.22f 4244.13 42y`J.b3 -l4Z/./b Z4Z.25/ 14/U.IU 67./4L U.bl -U.IU -U.tl4 by3/Zbb.Ub Top Whipstock 4900.00 51.95 82.46 4263 .25 4318.75 -1450.75 245.88 1494.19 60.00E 2.37 1.13 -2.65 5937259.74 Base Whipstock 4916.00 52.93 80.38 4273 .00 4328.50 -1462.85 247.77 1506.73 --- 12.00 6.12 -13.03 5937261.99 KOP Crv 3/100 4929.00 52.93 80.38 4280 .84 4336.34 -1472.81 249.51 1516.95 155.00E 0.00 0.00 0.00 5937264.02 5000.00 51.00 79.22 4324 .58 4380.08 -1526.61 259.41 1571.99 154.29E 3.00 -2.71 -1.63 5937275.47 5100.00 48.31 77.48 4389 .31 4444.81 -1600.44 274.78 1646.63 153.16E 3.00 -2.69 -1.74 5937292.95 5200.00 45.65 75.58 4457 .53 4513.03 -1671.79 291.78 1717.73 151.87E 3.00 -2.66 -1.89 5937311.97 5300.00 43.02 73.51 4529 .05 4584.55 -1740.48 310.37 1785.08 150.38E 3.00 -2.63 -2.07 5937332.47 5400.00 40.44 71.22 4603 .68 4659.18 -1806.32 330.50 1848.52 148.68E 3.00 -2.59 -2.29 5937354.38 5500.00 37.90 68.69 4681 .21 4736.71 -1869.12 352.11 1907.85 146.71 L 3.00 -2.54 -2.54 5937377.67 Crv 4/100 5529.00 37.18 67.89 4704 .20 4759.70 -1886.74 358.64 1924.27 176.9OR 3.00 -2.50 -2.73 5937384.67 5600.00 34.34 68.17 4761 .81 4817.31 -1928.12 374.17 1962.74 176.68R 4.00 -3.99 0.38 5937401.28 5700.00 30.35 68.63 4846 .28 4901.78 -1981.46 393.87 2012.47 17629R 4.00 -3.99 0.46 5937422.38 UG4 5721.60 29.49 68.74 4865. 00 4920.50 -1992.20 397.79 2022.51 176.19R 4.00 -3.99 0.53 5937426.58 5800.00 26.36 69.21 4934 .26 4989.76 -2028.77 410.97 2056.77 175.77R 4.00 -3.99 0.60 5937440.73 UG3 5850.61 24.34 69.57 4980. 00 5035.50 -2050.34 418.60 2077.05 175.45R 4.00 -3.99 0.71 5937448.93 5900.00 22.37 69.98 5025 .34 5080.84 -2069.82 425.37 2095.42 175.O7R 4.00 -3.99 0.83 5937456.22 6000.00 18.39 71.07 5119 .06 5174.56 -2104.41 437.00 2128.23 174.O5R 4.00 -3.98 1.09 5937468.78 6100.00 14.42 72.74 5214 .97 5270.47 -2132.38 445.82 2155.05 172.45R 4.00 -3.97 1.66 5937478.35 6200.00 10.46 75.63 5312 .60 5368.10 -2153.59 451.77 2175.75 169.62R 4.00 -3.95 2.89 5937484.89 6300.00 6.57 81.93 5411 .48 5466.98 -2167.93 454.83 2190.21 163.39R 4.00 -3.90 6.30 5937488.36 6400.00 2.96 104.62 5511 .13 5566.63 -2175.34 454.98 2198.38 14O.77R 4.00 -3.60 22.68 5937488.74 6500.00 2.53 197.69 5611 .05 5666.55 -2175.78 452.22 2200.21 47.76R 4.00 -0.43 93.07 5937486.03 6600.00 6.00 227.29 5710 .77 5766.27 -2169.24 446.57 2195.70 18.23R 4.00 3.47 29.60 593748026 /15ti34./ti N /U.1:S1:Stf11y W 142f.16y'L1S4/ 715658.75 N 70.23139041 W 148.25901906 715671.23 N 70.23139558 W 148.25891785 715681.40 N 70.23140031 W 148.25883531 715736.13 N 70.23142732 W 148.25839110 715810.30 N 70.23146927 W 148.25778863 715880.88 N 70.23151568 W 148.25721478 715947.68 N 70.23156643 W 148.25667110 716010.51 N 7023162137 W 14825615909 716069.21 N 70.23168036 W 148.25568015 716085.43 N 70.23169821 W 148.255 764 716123.45 N 70.23174059 W 148.25 8 716172.59 N 70.23179439 W 148.2 6 716182.52 N 70.23180508 W 148.25475463 716216.39 N 70.23184106 W 148.25447808 716236.44 N 70.23186189 W 148.25431437 716254.61 N 70.23188037 W 148.25416608 716287.08 N 70.23191213 W 148.25390120 716313.64 N 70.23193619 W 148.25368471 716334.15 N 70.23195243 W 148.25351767 716348.53 N 70.23196078 W 148.25340090 716356.69 N 70.23196118 W 148.25333497 716358.60 N 70.23195364 W 14825332019 716354.25 N 7023193820 W 148.25335664 WeIlDesign Ver SP 2.1 Bld( doc4Ox_1OO) 03-36\03-36\Plan 03-36A\03-36A (P6) Generated 11/16/2006 12:00 PM Page 1 of 3 Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft de 100 ft de 1100 ft ftUS ftUS O/UV.w a.oo LJ4.0~ OOV~./y OOW.L~ -L 100.// 4JO.U0 L104.00 IU.yyK 4.VU 1.00 /.Jl Oy3/4/ 1.43 / 10141.00 IV /U.L3.1 `114`13 VV 140.L03444"14 UG1 6746.02 11.69 236.32 5855.00 5910.50 -2147.25 433.17 2177.76 9.29R 4.00 3.94 3.76 5937466.36 716336.70 N 70.23190162 W 148.25350145 6800.00 13.83 237.78 5907.64 5963.14 -2135.41 426.70 2167.75 7.87R 4.00 3.96 2.70 5937459.60 716326.87 N 70.23188394 W 148.25358227 6900.00 17.80 239.57 6003.84 6059.34 -2108.29 412.58 2144.45 6.14R 4.00 3.97 1.79 5937444.83 716303.99 N 70.23184539 W 148.25377034 7000.00 21.78 240.72 6097.92 6153.42 -2074.51 395.76 2115.08 5.06R 4.00 3.98 1.15 5937427.18 716275.11 N 70.23179946 W 148.25400746 7100.00 25.77 241.53 6189.41 6244.91 -2034.26 376.32 2079.78 4.32R 4.00 3.99 0.81 5937406.75 716240.37 N 70.23174638 W 148.25429245 7200.00 29.76 242.14 6277.88 6333.38 -1987.72 354.35 2038.71 3.78R 4.00 3.99 0.61 5937383.63 716199.95 N 70.23168640 W 148.25462393 7300.00 33.75 242.61 6362.90 6418.40 -1935.13 329.97 1992.09 3.38R 4.00 3.99 0.47 5937357.93 716154.04 N 70.23161982 W 148.25500028 WS2 7332.85 35.06 242.75 6390.00 6445.50 -1916.57 321.45 1975.60 3.26R 4.00 3.99 0.41 5937348.95 716137.80 N 70.23159657 W 148.25513338 7400.00 37.74 243.00 6444.05 6499.55 -1876.73 303.29 1940.14 3.06R 4.00 3.99 0.37 5937329.78 716102.86 N 7023154696 W 148.25541967 7500.00 41.74 243.32 6520.93 6576.43 -1812.82 274.43 1883.10 2.82R 4.00 3.99 0.32 5937299.32 716046.68 N 70.23146818 W 148.255 7600.00 45.73 243.59 6593.17 6648.67 -1743.71 243.55 1821.27 2.62R 4.00 4.00 0.27 5937266.70 715985.75 N 70.23138385 W 148.256 WSl 7624.33 46.71 243.65 6610.00 6665.50 -1726.14 235.75 1805.53 2.58R 4.00 4.00 0.25 5937258.45 715970.24 N 70.23136254 W 148.25650624 End Crv 7632.58 47.03 243.67 6615.64 6671.14 -1720.13 233.08 1800.13 --- 4.00 4.00 0.25 5937255.63 715964.92 N 70.23135525 W 148.25654977 CM3 7969.10 47.03 243.67 6845.00 6900.50 -1473.87 123.87 1579.42 --- 0.00 0.00 0.00 5937140.21 715747.40 N 70.23105704 W 148.25833139 CM2 8688.04 47.03 243.67 7335.00 7390.50 -947.78 -109.43 1107.88 --- 0.00 0.00 0.00 5936893.62 715282.71 N 70.23041989 W 148.26213740 CM1 9685.76 47.03 243.67 8015.00 8070.50 -217.70 -433.20 453.50 --- 0.00 0.00 0.00 5936551.42 714637.82 N 70.22953556 W 148.26741881 THRZ 10263.85 47.03 243.67 8409.00 8464.50 205.31 -620.80 74.35 --- 0.00 0.00 0.00 5936353.14 714264.16 N 70.22902309 W 148.27047872 BHRZ 10533.82 47.03 243.67 8593.00 8648.50 402.86 -708.41 -102.71 --- 0.00 0.00 0.00 5936260.55 714089.67 N 70.22878375 W 148.27190766 LCU 10552.89 47.03 243.67 8606.00 8661.50 416.82 -714.60 -115.22 --- 0.00 0.00 0.00 5936254.00 714077.34 N 70.22876684 W 148.27200861 TSHA 10576.37 47.03 243.67 8622.00 8677.50 434.00 -722.22 -130.62 --- 0.00 0.00 0.00 5936245.95 714062.16 N 70.22874603 W 148.27213287 7" Csg 10576.38 47.03 243.67 8622.01 8677.51 434.01 -722.22 -130.63 --- 0.00 0.00 0.00 5936245.95 714062.15 N 70.22874601 W 148.27213294 TSAD 10649.73 47.03 243.67 8672.00 8727.50 487.68 -746.02 -178.74 --- 0.00 0.00 0.00 5936220.79 714014.75 N 70.22868098 W 148.27252116 45N 10662.93 47.03 243.67 8681.00 8736.50 497.35 -750.31 -187.40 -- 0.00 0.00 0.00 5936216.26 714006.21 N 70.22866928 W 148.27259105 45P 10667.33 47.03 243.67 8684.00 8739.50 500.57 -751.74 -190.28 --- 0.00 0.00 0.00 5936214.75 714003.37 N 70.22866537 W 148.27261435 44N 10709.88 47.03 243.67 8713.00 8768.50 531.70 -765.54 -218.19 --- 0.00 0.00 0.00 5936200.16 713975.86 N 70.22862765 W 148.27283956 44P 10712.82 47.03 243.67 8715.00 8770.50 533.85 -766.50 -220.12 --- 0.00 0.00 0.00 5936199.15 713973.97 N 70.22862505 W 148.27285509 43N 10737.76 47.03 243.67 8732.00 8787.50 552.10 -774.59 -236.48 -- 0.00 0.00 0.00 5936190.60 713957.84 N 70.22860293 W 148.27298711 43P 10743.63 47.03 243.67 8736.00 8791.50 556.40 -776.49 -240.33 -- 0.00 0.00 0.00 5936188.58 713954.05 N 70.22859773 W 148.27 7 Crv 81100 10769.02 47.03 243.67 8753.30 8808.80 574.97 -784.73 -256.98 1.03E 0.00 0.00 0.00 5936179.88 713937.64 N 70.22857522 W 148.274 10800.00 49.51 243.62 8773.92 8829.42 598.09 -795.00 -277.69 0.99E 8.00 8.00 -0.19 5936169.03 713917.22 N 70.22854718 W 148.27 4 42N 10809.43 50.27 243.60 8780.00 8835.50 605.31 -798.20 -284.16 0.98E 8.00 8.00 -0.18 5936165.64 713910.86 N 70.22853842 W 148.27337188 42P 10865.30 54.74 243.51 8814.00 8869.50 649.62 -817.94 -323.83 0.92E 8.00 8.00 -0.17 5936144.79 713871.76 N 70.22848449 W 148.27369204 10900.00 57.51 243.45 8833.34 8888.84 678.42 -830.80 -349.61 0.89E 8.00 8.00 -0.15 5936131.20 713846.36 N 70.22844935 W 14827390005 31N 10904.98 57.91 243.45 8836.00 8891.50 682.63 -832.69 -353.37 0.89E 8.00 8.00 -0.15 5936129.21 713842.65 N 70.22844421 W 148.27393043 31 P 10906.87 58.06 243.44 8837.00 8892.50. 684.23 -833.40 -354.80 0.89E 8.00 8.00 -0.15 5936128.45 713841.24 N 70.22844225 W 148.27394198 11000.00 65.51 243.32 8881.00 8936.50 766.24 -870.15 -428.12 0.83E 8.00 8.00 -0.14 5936089.64 713769.00 N 70.22834185 W 148.27453362 27N 11044.00 69.03 243.26 8898.00 8953.50 806.82 -888.39 -464.37 0.81E 8.00 8.00 -0.12 5936070.38 713733.28 N70.22829201 W148.27482614 27P 11046.81 69.26 243.26 8899.00 8954.50 809.44 -889.57 -466.71 0.80E 8.00 8.00 -0.12 5936069.13 713730.98 N 70.22828878 W 148.27484506 11100.00 73.51 243.20 8915.98 8971.48 859.83 -912.27 -511.70 0.79E 8.00 8.00 -0.12 5936045.16 713686.65 N 70.22822676 W 148.27520811 11200.00 81.51 243.09 8937.59 8993.09 957.37 -956.35 -598.73 0.76E 8.00 8.00 -0.11 5935998.64 713600.91 N 70.22810633 W 148.27591039 WeIlDesign Ver SP 2.1 Bld(docAOx_100) 03-36\03-36\Plan 03-36A\03-36A (P6) Generated 11/16/2006 12:00 PM Page 2 of 3 Measured Vertical lira°1~ Comments Inclination Azimuth SutrSea ND 7yp NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de H00 ft de 100 ft de 100 ft ftUS ftUS Iargeil llG8l.l4 88.VV G43.VU 2f`J4D.UV `JUUU.DU "IU3C.lZ -yyZ.yb -b/U./Z yV.44L 25.UU 25.UU -U.1"I by3bybV.UU 11300.00 87.99 241.49 8945.66 9001.16 1056.96 -1001.73 -687.39 90.39E 8.00 -0.06 -8.00 5935950.75 11400.00 87.96 233.49 8949.20 9004.70 1156.17 -1055.40 -771.60 90.10E 8.00 -0.03 -8.00 5935894.72 11500.00 87.96 225.48 8952.77 9008.27 1252.84 -1120.28 -847.51 89.82E 8.00 0.01 -8.01 5935827.72 26N 11591.45 88.00 218.16 8956.00 9011.50 1337.41 -1188.34 -908.41 89.56E 8.00 0.04 -8.00 5935757.95 11600.00 88.01 217.48 8956.30 9011.80 1345.08 -1195.09 -913.65 89.53E 8.00 0.06 -8.00 5935751.06 26P 11620.25 88.02 215.85 8957.00 9012.50 1363.06 -1211.33 -925.74 89.48E 8.00 0.07 -8.00 5935734.49 11700.00 88.09 209.47 8959.71 9015.21 1431.10 -1278.39 -968.73 89.26E 8.00 0.09 -8.00 5935666.24 End Crv 11799.29 88.21 201.53 8962.92 9018.42 1508.69 -1367.88 -1011.41 --- 8.00 0.12 -8.00 5935575.57 Crv 8/100 11952.36 88.21 201.53 8967.70 9023.20 1621.54 -1510.21 -1067.55 90.33E 0.00 0.00 0.00 5935431.71 12000.00 88.19 197.71 8969.19 9024.69 1655.57 -1555.06 -1083.53 90.21 L 8.00 -0.04 -8.00 5935386.43 12100.00 88.18 189.71 8972.36 9027.86 1719.37 -1652.08 -1107.20 89.96E 8.00 -0.01 -8.00 5935288.78 12200.00 88.20 181.70 8975.52 9031.02 1771.86 -1751.45 -1117.13 89.71 L 8.00 0.02 -8.00 5935189.17 12300.00 88.26 173.70 8978.61 9034.11 1812.01 -1851.24 -1113.13 89.46E 8.00 0.06 -8.00 5935089.54 Target 2 12346.24 88.30 170.00 8980.00 9035.50 1826.17 -1896.99 -1106.58 87.54E 8.00 0.08 -8.00 5935044.00 12400.00 88.49 165.70 8981.51 9037.01 1839.03 -1949.51 -109527 87.42E 8.00 0.35 -8.00 5934991.82 12500.00 88.86 157.71 8983.82 9039.32 1852.43 -2044.35 -1063.92 87.23E 8.00 0.37 -7.99 5934897.91 12600.00 89.26 149.72 8985.46 9040.96 1851.93 -2133.93 -1019.67 87.10E 8.00 0.40 -7.99 5934809.64 End Crv 12653.35 89.48 145.45 8986.05 9041.55 1845.97 -2178.95 -991.08 --- 8.00 0.41 -7.99 5934765.44 Crv 8/100 13052.48 89.48 145.45 8989.69 9045.19 1786.66 -2507.69 -764.76 84.55E 0.00 0.00 0.00 5934443.28 13100.00 89.84 141.67 8989.97 9045.47 1778.05 -2545.91 -736.54 84.52E 8.00 0.76 -7.96 5934405.88 Target 3 13120.97 90.00 140.00 8990.00 9045.50 1773.28 -2562.17 -72329 90.00E 8.00 0.76 -7.96 5934390.00 End Crv 13171.66 90.00 135.94 8990.00 9045.50 1759.28 -2599.82 -689.36 --- 8.00 0.00 -8.00 5934353.33 Crv 8/100 13376.84 90.00 135.94 8990.00 9045.50 1695.69 -2747.28 -546.69 90.00E 0.00 0.00 0.00 5934210.00 13400.00 90.00 134.09 8990.00 9045.50 1688.16 -2763.66 -530.32 90.00E 8.00 0.00 -8.00 5934194.09 13500.00 90.00 126.09 8990.00 9045.50 1647.67 -2828.01 -453.89 90.00E 8.00 0.00 -8.00 5934131.94 13600.00 90.00 118.09 8990.00 9045.50 1594.85 -2881.09 -369.23 90.00E 8.00 0.00 -8.00 5934081.28 Target 4 13638.65 90.00 115.00 8990.00 9045.50 1571.35 -2898.36 -334.66 90.00E 8.00 0.00 -8.00 5934065.00 13700.00 90.00 110.09 8990.00 9045.50 1530.75 -2921.88 -278.02 90.00E 8.00 0.00 -8.00 5934043.10 13800.00 90.00 102.09 8990.00 9045.50 1456.60 -2949.57 -182.02 90.00E 8.00 0.00 -8.00 5934018.15 13900.00 90.00 94.09 8990.00 9045.50 1373.86 -2963.64 -83.09 90.00E 8.00 0.00 -8.00 5934006.90 End Crv 13967.33 90.00 88.71 8990.00 9045.50 1314.10 -2965.28 -15.80 --- 8.00 0.00 -8.00 5934007.16 Crv 8/100 14512.99 90.00 88.71 8990.00 9045.50 818.39 -2952.95 529.71 90.00E 0.00 0.00 0.00 5934034.98 14600.00 90.00 81.74 8990.00 9045.50 737.33 -2945.71 616.37 90.00E 8.00 0.00 -8.00 5934044.67 14700.00 90.00 73.74 8990.00 9045.50 640.27 -2924.50 714.01 90.00E 8.00 0.00 -8.00 5934068.65 14800.00 90.00 65.74 8990.00 9045.50 540.85 -2889.91 807.75 90.00E 8.00 0.00 -8.00 5934105.88 Target 5 14809.30 90.00 65.00 8990.00 9045.50 531.55 -2886.03 816.21 90.00E 8.00 0.00 -8.00 5934110.00 14900.00 90.00 57.74 8990.00 9045.50 441.01 -2842.61 895.76 90.00E 8.00 0.00 -8.00 5934155.66 15000.00 90.00 49.74 8990.00 9045.50 342.69 -2783.52 976.34 90.00E 8.00 0.00 -8.00 5934217.02 15100.00 90.00 41.74 8990.00 9045.50 247.80 -2713.79 1047.90 90.00E 8.00 0.00 -8.00 5934288.75 End Crv 15107.99 90.00 41.11 8990.00 9045.50 240.42 -2707.80 1053.19 --- 8.00 0.00 -8.00 5934294.88 TD / 4-1/2" Lnr 15364.67 90.00 41.11 8990.00 9045.50 3.96 -2514.38 1221.94 --- 0.00 0.00 0.00 5934493.00 /1353U.UV N /U.ZZ25UUt)3U VV 1425.2/64y1Yti 713513.58 N 70.22798232 W 148.27662584 713430.93 N 70.22783567 W 148.27730532 713356.90 N 70.22765842 W 148.27791784 713297.96 N 70.22747245 W 148.27840921 713292.92 N 70.22745401 W 148.27845148 713281.30 N 70.22740965 W 148.27854899 713240.23 N 70.22722643 W 148.27889584 713200.10 N 70.22698191 W 148.27924018 713148.03 N 70.22659305 W 14827969301 713133.33 N 70.22647054 W 148.279 713112.42 N 70.22620547 W 148.280 713105.32 N 70.22593398 W 148.280 713112.16 N 70.22566136 W 148.28006041 713120.00 N 70.22553638 W 148.28000749 713132.79 N 70.22539290 W 148.27991620 713166.83 N 7022513381 W 148.27966308 713213.60 N 70.22488912 W 148.27930598 713243.45 N 7022476612 W 148.27907525 713479.01 N 70.22386809 W 148.27724889 713508.30 N 70.22376368 W 148.27702120 713522.00 N 70.22371926 W 148.27691433 713556.98 N 70.22361642 W 148.27664055 713703.78 N 70.22321362 W 14827548940 713720.60 N 70.22316887 W 148.27535731 713798.83 N 70.22299309 W 148.27474058 713884.95 N 70.22284807 W 148.27405762 713920.00 N 70.22280090 W 14827377871 713977.29 N 70.22273666 W 148.27332171 714074.03 N 70.22266100 W 148.27 714173.31 N 7022262258 W 148.2 9 714240.62 N 70.22261810 W 148.27120623 714785.53 N 70.22265173 W 148.26680520 714871.95 N 70.22267149 W 14826610608 714968.94 N 70.22272941 W 148.26531833 715061.66 N 70.22282389 W 148.26456204 715070.00 N 70.22283448 W 148.26449380 71514829 N 70.22295309 W 148.26385193 715227.15 N 70.22311450 W 148.26320183 715296.70 N 70.22330497 W 148.26262437 715301.81 N 70.22332133 W 148.26258173 715465.00 N 70.22384966 W 148.26121996 WeIlDesign Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\Plan 03-36A103-36A (P6) Generated 11/16/2006 12:00 PM Page 3 of 3 by Schlumberger E~, 03-36A (P6) "`~ Prudhoe Bay Unit - EOA ~J`r°er DS-03 -2400 -1600 -800 0 800 1600 4000 4800 5600 s o` ~ 6400 c u a~ rn 7200 8000 8800 ......................:.................................:................................ i .................................. .................................................................... .................... ~._. ...-.._..-..-..-.r-..-..-.._..-..-.._..-..-.._..-..-..-..-..-..-.._..~..-.._.._.._..-..- ..~ ..t..-..-..-.._.._.._..-.._..r.._.._..-..-..-..-.._.._._.._.._.._.._.. r cip -Ri :Crv 81100 Target 1 uuuuuuumiuun~uuuuuuuuutuuunuuuuuuuuniuu~wu~uuuunnuliuumuu uu liuuun^ uiu~ mi'an tt~~n 111/IW1WA7111jt1LtLUU,1U.t1!/U.~371fitU~7lA/111f)317U1Ui31.t:1~31~13//1JUlU.t)l.ti :aU.iU/11171 1:,tU7l1;IJ:i ::is:~ illli/ii18:i iiii::~ ~::a::a:lz::i::ai:a::s::z::~~ ::xf:~::sii:iis ~_ ~_: _::c::ziia::::::::a::e:i:ii~:::::l::i:::::a::::::::_:: ~-::i:::::_:~ :'-...a..=.. - ~~-T:°_~=a r r E -. Ena crv ro 11-I1z- Lnr Entl crv Tarpet 5 crv BHQB Target 1 Entl Crv Crv81188: Crv8I108 ......................:...................................:. ~ End Crv Tarpel J -2400 -1600 -600 0 600 1600 Vertical Section (ft) Azim = 244°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 4000 4800 5600 6400 7200 8000 6600 • by Schlumberger 03-36A (P6) Proposal Report Date: November 16, 2006 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 110.000° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: DS-03 l 03-36 TVD Reference Datum: Rotary Table Well: 03-36 TVD Reference Elevation: 55.5 ft relative to MSL Borehole: Plan 03-36A Sea Bed I Ground Level Elevation: 28.000 ft relative to MSL UWIIAPI#: 500292234001 Magnetic Declination: 24.151 ° Survey Name I Date: 03-36A (P6) I November 16, 2006 Total Field Strength: 57673.596 nT Tort 1 AHD 1 DDI I ERD ratio: 408.954° 19562.11 ft / 6.822 / 1.057 Magnetic Dip: 80.944° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: April 21, 2007 Location LaHLong: N 70.23071908, W 148.27107875 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5936971.550 ftUS, E 714172.220 ftUS North Reference: True North Grid Convergence Angle: +1,62707914° Total Corr Mag North -> True North: +24.151 ° Grid Scale Factor: 0.99995211 Local Coordinates Referenced To: Well Head • Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft d de ft ft ft ft k de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS lilVll yooU. /o ~/.VJ c~rJ.o/ ovlo. vv ov/v.vv o/w. Jc 7HRZ 10263. 85 47.03 243.67 8409. 00 8464.50 282. 19 BHRZ 10533. 82 47.03 243.67 8593. 00 8648.50 145. 77 LCU 10552. 89 47.03 243.67 8606. 00 8661.50 136. 13 TSHA 10576. 37 47.03 243.67 8622. 00 8677.50 124. 27 7" Csg 10576. 38 47.03 243.67 8622. 01 8677.51 124. 26 TSAD 10649. 73 47.03 243.67 8672. 00 8727.50 87. 20 45N 10662. 93 47.03 243.67 8681. 00 8736.50 80. 52 45P 10667. 33 47.03 243.67 8684. 00 8739.50 78. 30 44N 10709. 88 47.03 243.67 8713. 00 8768.50 56. 80 44P 10712. 82 47.03 243.67 8715. 00 8770.50 55. 32 43N 10737. 76 47.03 243.67 8732. 00 8787.50 42. 71 43P 10743. 63 47.03 243.67 8736. 00 8791.50 39. 75 Crv 8/100 10769 .02 47.03 243.67 8753 .30 8808.80 26 .92 10800 .00 49.51 243.62 8773 .92 8829.42 10 .96 42N 10809. 43 50.27 243.60 8780. 00 8835.50 5. 98 42P 10865. 30 54.74 243.51 8814. 00 8869.50 -24. 55 10900 .00 57.51 243.45 8833 .34 8888.84 -44 .37 31N 10904. 98 57.91 243.45 8836. 00 8891.50 -47. 27 31 P 10906. 87 58.06 243.44 8837. 00 8892.50 -48. 37 11000 .00 65.51 243.32 8881 .00 8936.50 -104 .69 27N 11044. 00 69.03 243.26 8898. 00 8953.50 -132. 52 27P 11046. 81 69.26 243.26 8899. 00 8954.50 -134. 32 11100 .00 73.51 243.20 8915 .98 8971.48 -168 .83 11200 .00 81.51 243.09 8937 .59 8993.09 -235 .53 -4JJ. LV 4AJ. OV --- U.VV U.UU V.VV O`JJOD01.4L / 140J/.OL IV /V.LL/OJ000 W 74tf. C0/472JtJ1 -620. 80 74. 35 --- 0.00 0.00 0.00 5936353. 14 714264. 16 N 70.22902309 W 148. 27047872 -708. 41 -102. 71 --- 0.00 0.00 0.00 5936260. 55 714089. 67 N 70.22878375 W 148. 27190766 -714. 60 -115. 22 --- 0.00 0.00 0.00 5936254. 00 714077. 34 N 70.22876684 W 148. 27200861 -722. 22 -130. 62 --- 0.00 0.00 0.00 5936245. 95 714062. 16 N 70.22874603 W 148. 27213287 -722. 22 -130. 63 --- 0.00 0.00 0.00 5936245. 95 714062. 15 N 70.22874601 W 148. 27213294 -746. 02 -178. 74 --- 0.00 0.00 0.00 5936220. 79 714014. 75 N 70.22868098 W 148. 27252116 -750. 31 -187. 40 --- 0.00 0.00 0.00 5936216. 26 714006. 21 N 70.22866928 W 148. 27259105 -751. 74 -190. 28 --- 0.00 0.00 0.00 5936214. 75 714003. 37 N 70.22866537 W 148. 27261435 -765. 54 -218. 19 --- 0.00 0.00 0.00 5936200. 16 713975. 86 N 70.22862765 W 148. 27283956 -766. 50 -220. 12 --- 0.00 0.00 0.00 5936199. 15 713973. 97 N 70.22862505 W 148. 27285509 -774. 59 -236. 48 --- 0.00 0.00 0.00 5936190. 60 713957.84 N 70.22860293 W 148. 2 1 -776. 49 -240. 33 -- 0.00 0.00 0.00 5936188. 58 713954. 05 N 70.22859773 W 148. 7 27 7 -784 .73 -256. 98 1.03E 0.00 0.00 0.00 5936179 .88 713937 .64 N 70.22857522 W 148 .2731 254 -795 .00 -277. 69 0.99E 8.00 8.00 -0.19 5936169 .03 713917 .22 N 70.22854718 W 148 .27331974 -798. 20 -284. 16 0.98E 8.00 8.00 -0.18 5936165. 64 713910. 86 N 70.22853842 W 148. 27337188 -817. 94 -323. 83 0.92E 8.00 8.00 -0.17 5936144. 79 713871. 76 N 70.22848449 W 148. 27369204 -830 .80 -349. 61 0.89E 8.00 8.00 -0.15 5936131 .20 713846 .36 N 70.22844935 W 148 .27390005 -832. 69 -353. 37 0.89E 8.00 8.00 -0.15 5936129. 21 713842. 65 N 70.22844421 W 148. 27393043 -833. 40 -354. 80 0.89E 8.00 8.00 -0.15 5936128. 45 713841. 24 N 70.22844225 W 148. 27394198 -870 .15 -428. 12 0.83E 8.00 8.00 -0.14 5936089 .64 713769 .00 N 70.22834185 W 148 .27453362 -888. 39 -464. 37 0.81E 8.00 8.00 -0.12 5936070. 38 713733. 28 N 70.22829201 W 148. 27482614 -889. 57 -466. 71 0.80E 8.00 8.00 -0.12 5936069. 13 713730. 98 N 70.22828878 W 148. 27484506 -912 .27 -511. 70 0.79E 8.00 8.00 -0.12 5936045 .16 713686 .65 N 70.22822676 W 148 .27520811 -956 .35 -598. 73 0.76E 8.00 8.00 -0.11 5935998 .64 713600 .91 N 70.22810633 W 148 .27591039 WeIlDesign Ver SP 2.1 Bld(doo40x_100) 03-36\03-36\Plan 03-36A\03-36A (P6) Generated 11/16/2006 1:12 PM Page 1 of 2 Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft d d 1100 ft de 1100 ft de 1100 k ftUS ftUS Target 1 11281.14 88.00 243.00 8945.00 9000.50 -290.66 -992. 96 -670.72 90.44E 8.00 8.00 -0.11 5935960.00 713530.00 N 70.22800630 W 148.27649126 11300.00 87.99 241.49 8945.66 9001.16 -303.33 -1001. 73 -687.39 90.39E 8.00 -0.06 -8.00 5935950.75 713513.58 N 70.22798232 W 148.27662584 11400.00 87.96 233.49 8949.20 9004.70 -364.10 -1055. 40 -771.60 90.10E 8.00 -0.03 -8.00 5935894.72 713430.93 N 70.22783567 W 148.27730532 11500.00 87.96 225.48 8952.77 9008.27 -413.24 -1120. 28 -847.51 89.82E 8.00 0.01 -8.01 5935827.72 713356.90 N 70.22765842 W 148.27791784 26N 11591.45 88.00 218.16 8956.00 9011.50 -447.19 -1188. 34 -908.41 89.56E 8.00 0.04 -8.00 5935757.95 713297.96 N 70.22747245 W 148.27840921 11600.00 88.01 217.48 8956.30 9011.80 -449.81 -1195. 09 -913.65 89.53E 8.00 0.06 -8.00 5935751.06 713292.92 N 70.22745401 W 148.27845148 26P 11620.25 88.02 215.85 8957.00 9012.50 -455.61 -1211. 33 -925.74 89.48E 8.00 0.07 -8.00 5935734.49 713281.30 N 70.22740965 W 148.27854899 11700.00 88.09 209.47 8959.71 901521 -473.07 -1278. 39 -968.73 89.26E 8.00 0.09 -8.00 5935666.24 713240.23 N 70.22722643 W 148.27889584 End Crv 11799.29 88.21 201.53 8962.92 9018.42 -482.57 -1367. 88 -1011.41 --- 8.00 0.12 -8.00 5935575.57 713200.10 N 7022698191 W 148.27924018 Crv 8/100 11952.36 88.21 201.53 8967.70 9023.20 -486.65 -1510. 21 -1067.55 90.33E 0.00 0.00 0.00 5935431.71 713148.03 N 70.22659305 W 148.27969301 12000.00 88.19 197.71 8969.19 9024.69 -486.33 -1555. 06 -1083.53 90.21 L 8.00 -0.04 -8.00 5935386.43 713133.33 N 70.22647054 W 148.279 12100.00 88.18 189.71 8972.36 9027.86 -475.39 -1652. 08 -1107.20 89.96E 8.00 -0.01 -8.00 5935288.78 713112.42 N 70.22620547 W 148.280 12200.00 88.20 181.70 8975.52 9031.02 -450.73 -1751. 45 -1117.13 89.71 L 8.00 0.02 -8.00 5935189.17 713105.32 N 70.22593398 W 148.28009283 12300.00 88.26 173.70 8978.61 9034.11 -412.84 -1851. 24 -1113.13 89.46E 8.00 0.06 -8.00 5935089.54 713112.16 N 70.22566136 W 148.28006041 Target 2 12346.24 88.30 170.00 8980.00 9035.50 -391.04 -1896. 99 -1106.58 87.54E 8.00 0.08 -8.00 5935044.00 713120.00 N 70.22553638 W 148.28000749 12400.00 88.49 165.70 8981.51 9037.01 -362.45 -1949. 51 -1095.27 87.42E 8.00 0.35 -8.00 5934991.82 713132.79 N 70.22539290 W 148.27991620 12500.00 88.86 157.71 8983.82 9039.32 -300.54 -2044. 35 -1063.92 87.23E 8.00 0.37 -7.99 5934897.91 713166.83 N 70.22513381 W 148.27966308 12600.00 89.26 149.72 8985.46 9040.96 -228.33 -2133. 93 -1019.67 87.10E 8.00 0.40 -7.99 5934809.64 713213.60 N 70.22488912 W 148.27930598 End Crv 12653.35 89.48 145.45 8986.05 9041.55 -186.06 -2178. 95 -991.08 --- 8.00 0.41 -7.99 5934765.44 713243.45 N 70.22476612 W 148.27907525 Crv 8/100 13052.48 89.48 145.45 8989.69 9045.19 139.05 -2507. 69 -764.76 84.55E 0.00 0.00 0.00 5934443.28 713479.01 N 70.22386809 W 148.27724889 13100.00 89.84 141.67 8989.97 9045.47 178.63 -2545. 91 -736.54 84.52E 8.00 0.76 -7.96 5934405.88 713508.30 N 70.22376368 W 148.27702120 Target 3 13120.97 90.00 140.00 8990.00 9045.50 196.64 -2562. 17 -723.29 90.00E 8.00 0.76 -7.96 5934390.00 713522.00 N 70.22371926 W 148.27691433 End Crv 13171.66 90.00 135.94 8990.00 9045.50 241.40 -2599. 82 -689.36 --- 8.00 0.00 -8.00 5934353.33 713556.98 N 70.22361642 W 148.27664055 Crv 8/100 13376.84 90.00 135.94 8990.00 9045.50 425.90 -2747. 28 -546.69 90.00E 0.00 0.00 0.00 5934210.00 713703.78 N 70.22321362 W 148.27548940 13400.00 90.00 134.09 8990.00 9045.50 446.88 -2763. 66 -530.32 90.00E 8.00 0.00 -8.00 5934194.09 713720.60 N 70.22316887 W 148.27535731 13500.00 90.00 126.09 8990.00 9045.50 540.72 -2828. 01 -453.89 90.00E 8.00 0.00 -8.00 5934131.94 713798.83 N 70.22299309 W 148.27474058 13600.00 90.00 118.09 8990.00 9045.50 638.42 -2881. 09 -369.23 90.00E 8.00 0.00 -8.00 593408128 713884.95 N 7022284807 W 148.27405762 Target 4 13638.65 90.00 115.00 8990.00 9045.50 676.82 -2898. 36 -334.66 90.00E 8.00 0.00 -8.00 5934065.00 713920.00 N 70.22280090 W 148.27377871 13700.00 90.00 110.09 8990.00 9045.50 738.09 -2921. 88 -278.02 90.00E 8.00 0.00 -8.00 5934043.10 713977.29 N 70.22273666 W 148.27 1 13800.00 90.00 102.09 8990.00 9045.50 837.77 -2949. 57 -182.02 90.00E 8.00 0.00 -8.00 5934018.15 714074.03 N 70.22266100 W 148.277 13900.00 90.00 94.09 8990.00 9045.50 935.54 -2963. 64 -83.09 90.00E 8.00 0.00 -8.00 5934006.90 714173.31 N 70.22262258 W 1 4 8 2 71 74909 End Crv 13967.33 90.00 88.71 8990.00 9045.50 999.34 -2965. 28 -15.80 --- 8.00 0.00 -8.00 5934007.16 714240.62 N 7022261810 W 148.27120623 Crv 8/100 14512.99 90.00 88.71 8990.00 9045.50 1507.74 -2952. 95 529.71 90.00E 0.00 0.00 0.00 5934034.98 714785.53 N 70.22265173 W 148.26680520 14600.00 90.00 81.74 8990.00 9045.50 1586.69 -2945. 71 616.37 90.00E 8.00 0.00 -8.00 5934044.67 714871.95 N 70.22267149 W 14826610608 14700.00 90.00 73.74 8990.00 9045.50 1671.19 -2924. 50 714.01 90.00E 8.00 0.00 -8.00 5934068.65 714968.94 N 70.22272941 W 148.26531833 14800.00 90.00 65.74 8990.00 9045.50 1747.44 -2889. 91 807.75 90.00E 8.00 0.00 -8.00 5934105.88 715061.66 N 70.22282389 W 148.26456204 Target 5 14809.30 90.00 65.00 8990.00 9045.50 1754.07 -2886. 03 816.21 90.00E 8.00 0.00 -8.00 5934110.00 715070.00 N 70.22283448 W 148.26449380 14900.00 90.00 57.74 8990.00 9045.50 1813.97 -2842. 61 895.76 90.00E 8.00 0.00 -8.00 5934155.66 715148.29 N 70.22295309 W 148.26385193 15000.00 90.00 49.74 8990.00 9045.50 1869.47 -2783. 52 976.34 90.00E 8.00 0.00 -8.00 5934217.02 715227.15 N 70.22311450 W 148.26320183 15100.00 90.00 41.74 8990.00 9045.50 1912.87 -2713. 79 1047.90 90.00E 8.00 0.00 -8.00 5934288.75 715296.70 N 70.22330497 W 148.26262437 End Crv 15107.99 90.00 41.11 8990.00 9045.50 1915.79 -2707. 80 1053.19 --- 8.00 0.00 -8.00 5934294.88 715301.81 N 70.22332133 W 148.26258173 TD / 4-1/2" Lnr 15364.67 90.00 41.11 8990.00 9045.50 2008.22 -2514. 38 1221.94 --- 0.00 0.00 0.00 5934493.00 715465.00 N 70.22384966 W 148.26121996 WeIlDesign Ver SP 2.1 Bld( doc40x_100) 03-36\03-36\Plan 03-36A\03-36A (P6) Generated 11/16/2006 1:12 PM Page 2 of 2 M O ~ f a ~ ~ 'o &'~o zN ~~ ~oo 3 f ~.n n &~' Q $ ~ ~ W °~~ I r w ~ ~ c ~ s m ~q ~ w t 3 ~~ S' L a o~ ~=3 - ~ 9 S ~~ Q ~ o ~ a o~ M M 5~ O ~ ~~ `s i~ O N O W O O O r O m 0 O O O O M O O 0 ry °o • 0 0 0 0 0 0 0 0 V I~ O M W ~ m M O ............................. ......1........... ..........Ii1..y..la..~.s....1...i.a......1.. ..1a...Q............................................... i iii ii ii i i i i pi ~ i ill 1i 1 i I l i i ;1 1 11 1 // // 1 1 1 1 ; 1 ~ 1 111 It // 1 1 1 1 ;1 J 1 11 1~ li i 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TVD Ref- Relay Tada1555ChaWVe MSLI Mry Oei. B2C St- FS 5]EIJ.6 nT EasUng .tl /331 hUS Sule Fa:f. O'9999S19C8 PUn. Ci-J6A IPe~ Srry Oafa: NovemYar t6. I0Cti -1800 -1200 -600 0 600 1200 1800 2400 0 _600 Z 0 -,200 U ~ -1800 v v -2400 -3000 1800 -1200 -600 0 600 1200 1800 2400 c« W Scale = 1(in):600(ft) E »> goo 1200 1800 ?400 Tnnn • • BP Alasl~a Anticollision Report Cotnpany: BP Amoco Uatc: 11i16i2006 i Field; Prudhoe Bay Reference Sitc: PB DS 03 Reference Nell: 03-36 Reference Wcllpalh: Plan 03-36A NO (.WEAL SCAN: Using user defined selection & scan criteria i Interpolation Method: MD Interval: 5.00 ft j Depth Range: 4900.00 to 15391.14 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date. 11/16/2006 Validated: No Planned From To Survey ft ft Time: 13:26:39 Page: 1 '~. Eo-ordhtate(NLl Reference: Well: 03-36, True North Vertical ('fVDI Reli rence: 03-36A Plan 55.5 Db: Oracle Reference: Principal Plan 8 PLANNED PROGRAM Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 3 '1'oolcode '1'001 Name 57.20 4869.10 1 : Schlumberger GCT multishot GCT-MS Schiumberger GCT multishot 4869.10 10500.00 Planned: Plan #6 V2 MWD+IFR:AK MWD + IFR [Alaska] 10500.00 15364.67 Planned: Plan #6 V2 MWD+IFR:AK MWD + IFR [Alaska] Casing Poin ts . iAll) TVD Diameter Ilole Site \ame h - - fl ` - - in in - i - ---- i 3972.30 - - - 3727.65 - 13.375 . _... 17.500 13 3/8" i 10576.36 8677.50 7.000 8.500 7" 105364.67 ...000 4.500 6.125 41/2" Summary <_---- O(Tsct Wellpath --_~__> Site We1C Wellpath PB DS 03 03-01 03-01 V3 PB DS 03 03-02 03-02 V1 PB DS 03 03-03 03-03 V1 I, PB DS 03 03-04 03-04 V1 PB DS 03 03-05 03-05 V1 PB DS 03 03-06 03-06 V1 PB DS 03 03-07 03-07 V1 PB DS 03 03-07 03-07A VS PB DS 03 03-08 03-OB V1 PB DS 03 03-09 03-09 V1 PB DS 03 03-10 03-10 V1 PB DS 03 03-11 03-11 V3 PB DS 03 03-12 03-12 V1 i PB DS 03 03-13 03-13 V1 PB DS 03 03-14 03-14 V1 PB DS 03 ~ 03-14 03-14A V11 PB DS 03 03-15 03-15 V1 '. PB DS 03 03-15A 03-15A V1 PB DS 03 03-15AL1 03-15AL1 V6 PB DS 03 03-16 03-16 V1 i PB DS 03 03-16A 03-16A V1 PB DS 03 03-17 03-17 V1 i PB DS 03 03-18 03-18 V1 j PB DS 03 03-18A 03-18A V1 PB DS 03 03-19 03-19 Vt ' PB DS 03 I 03-20 03-20 V1 I PB DS 03 03-20A 03-20A V1 PB DS 03 03-21 03-21 V1 PB OS 03 03-22 03-22 V1 PB DS 03 03-23 03-23 V1 PB DS 03 03-24 03-24 V1 PB DS 03 03-24A 03-24A V1 PB DS 03 03-25 03-25 V1 PB DS 03 03-25A 03-25A V1 PB DS 03 03-26 03-26 V4 PB DS 03 03-27 03-27 V 1 PB DS 03 03-28 03-28 V1 PB DS 03 03-29 03-29 V1 PB DS 03 03-30 03-30 V4 PB DS 03 03-31 03-31 V1 PB DS 03 03-32 03-32 V1 Reference 'Offset Ctr-Ctr No-6o AIlow~abte - nw MD Distance Area UetiaNon Warning ft ft ;ft k ft I 8450.00 6090.00 3568.09 114.77 3453.32 Pass: Major Risk 8935.55 6085.00 3408.14 127.07 3281.06 Pass: Major Risk 9748.36 8155.00 1471.50 135.48 1336.02 Pass: Major Risk 6946.21 6970.00 505.68 440.41 65.27 Pass: Major Risk 7838.54 7055.00 1191.45 233.48 957.97 Pass: Major Risk 14477.48 9930.00 507.04 279.13 227.91 Pass: Major Risk 12150.00 8690.00 2686.50 349.30 2337.21 Pass: Major Risk 12350.00 9980.00 2062.72 269.76 1792.96 Pass: Major Risk 12419.81 9535.00 978.64 316.45 662.39 Pass: Major Risk 8946.76 6860.00 5307.67 159.10 5148.57 Pass: Major Risk 5745.41 5835.00 2518.66 197.09 2321.56 Pass: Major Risk 13532.77 9870.00 2211.33 286.37 1924.97 Pass: Major Risk 7886.98 7330.00 541.85 257.79 284.06 Pass: Major Risk 4900.00 5795.00 2171.96 243.11 1928.85 Pass: Major Risk 14531.67 9610.00 1446.47 199.25 1247.21 Pass: Major Risk 14550.00 9555.00 1484.00 168.52 1315.48 Pass: Major Risk ' 12050.00 7415.00 3888.19 324.45 3563.75 Pass: Major Risk 12050.00 7415.00 3888.19 324.45 3563.75 Pass: Major Risk 12050.00 7410.00 3892.87 324.13 3568.74 Pass: Major Risk i, 11700.00 6935.00 4388.91 269.03 4119.88 Pass: Major Risk I 11700.00 6935.00 4388.91 269.03 4119.88 Pass: Major Risk ~ 11482.96 9200.00 2126.78 267.57 1859.21 Pass: Major Risk 9289.69 5970.00 4156.41 111.53 4044.87 Pass: Major Risk 9289.69 5970.00 4156.41 111.53 4044.87 Pass: Major Risk 12100.00 7185.00 4060.53 174.42 3886.10 Pass: Major Risk 11363.28 9070.00 332.94 181.30 151.64 Pass: Major Risk !, 11458.68 8950.00 516.57 164.67 351.91 Pass: Major Risk 12032.86 8825.00 2546.48 217.27 2329.21 Pass: Major Risk 11750.00 6090.00 5342.72 170.35 5172.37 Pass: Major Risk 11681.36 6555.00 4662.43 170.14 4492.29 Pass: Major Risk I 11952.36 6040.00 5836.64 208.78 5627.86 Pass: Major Risk 11952.36 6040.00 5836.64 208.78 5627.86 Pass: Major Risk 9696.01 6335.00 5096.36 135.48 4960.88 Pass: Major Risk 9740.52 6275.00 5082.00 133.43 4948.57 Pass: Major Risk 6966.41 7105.00 823.41 485.61 337.81 Pass: Major Risk 8413.38 6575.00 3420.47 266.21 3154.26 Pass: Major Risk 9052.17 6470.00 4036.23 201.24 3834.99 Pass: Major Risk 11450.00 8105.00 3097.01 193.20 2903.81 Pass: Major Risk 'I 9097.02 7955.00 476.28 300.88 175.40 Pass: Major Risk i 9320.72 7250.00 2659.85 181.21 2478.64 Pass: Major Risk 8115.14 7300.00 1389.24 126.23 1263.01 Pass: Major Risk I L{ ?I u • BP Alaska Anticollision Report i~. Compen~: BPAmoCO - Uare: 11116/2006 __ June: 13_26:39 Page: 2 Fief: Prudhoe Bay ~ Reference Site: PB DS 03 Cbrordina le(sVti.)-Refe rence: Well:' Q3 -36, True No rth :Reference Nell: 03-36 Vertical (fVD) Refere nce: 03-36A Plan 55.5 - Reference ~Ycllpalh: Plan 03-36A Uh: Oracle SUlalnar\ ~i <~---_- _-- Olfsel lScllpath ---- ------> Reference offset Ctr-Ctr No-Go Allowable Sde Well N'cllpath DID iYID Distance Area Deviation Wareing ft ft ft ft ft - PB DS 03 - - 03-32A --. 03-32A V1 8115.14 7300.00 1389.24 126.23 1263.01 Pass: Major Risk PB DS 03 03-33 03-33 V2 7083.36 7135.00 484.10 426.83 57.27 Pass: Major Risk PB DS 03 03-33 03-33A V1 7083.36 7135.00 484.10 426.88 57.23 Pass: Major Risk PB DS 03 03-33 03-336 V3 7083.57 7130.00 484.13 426.96 57.17 Pass: Major Risk PB DS 03 03-34 03-34 V4 13470.60 9500.00 745.83 219.65 526.18 Pass: Major Risk i PB DS 03 03-34 03-34A V1 13771.18 9610.00 735.07 171.34 563.72 Pass: Major Risk I PB DS 03 03-34 03.346 V1 13256.80 9070.00 864.80 164.48 700.32 Pass: Major Risk PB DS 03 03-34 Plan 03-34C VO Pl an: P 13256.80 9070.00 864.80 164.54 700.26 Pass: Major Risk PB DS 03 03-35 03-35 V1 4901.16 5185.00 744.06 104.74 639.32 Pass: Major Risk PB DS 03 03-36 03-36 V1 4905.30 4910.00 0.02 0.80 -0.78 FAIL: NOERRORS PB DS 16 16-15 16-15 V1 15066.01 11389.00 867.58 293.20 574.38 Pass: Major Risk • C~ FieldPrudhoe Bay SitePB DS 03 We11:03-36 ~ WellpathElan 03-36A, szs sao • aoo zoa 200 400 600 szs 2 3 0 s Travelling Cylinder Azimuth (TFOtAZI) (deg vs Centre t Polygon 1 2 3 4 5 6 7 8 9 10 11 12 13 I I Site: PB DS 03 Drilling Target Conf.: 95% Description: Map Northing: 5935960.00 ft Map Easting :713530.00 ft Latitude: 70° 13'40.823N Xft 278.88 -565.78 -1107.44 -499.80 -121.70 235.69 894.77 1711.24 2115.70 2374.93 2047.80 1363.50 278.88 Target: 03-36A Poly Well: 03-36 Based on: Planned Program Vertical Depth: 8945.00 ft below Mean Sea Level Loca] +N/-S: -992.95 ft Local +E/-W: -670.72 ft Longitude: 148° 16'35.369W Yft MapEft MapNft 308.22 713800.00 5936276.00 263.18 712957.00 5936207.00 -279.68 712431.00 5935649.00 -1323.41 713068.00 5934623.00 -1713.32 713457.00 5934244.00 -2092.64 713825.00 5933875.00 -2100.35 714484.00 5933886.00 -2096.53 715300.00 5933913.00 -1734.85 715694.00 5934286.00 -1484.10 715946.00 5934544.00 -990.59 715605.00 5935028.00 -955.14 714920.00 • 5935044.00 308.22 713800.00 5936276.00 __ _ _ ___ __ -500 -1000 -2500 -0000 RE: 03-36A AOR Subject: RE: 03-36A AOR From: "Gagliardi, Shane T" <Shane.Gagliardi~bp.com> Date: Fri, 02 Mar 2007 12:48:22 -0900 To: Thomas Maunder <tom_maunder~adr~ain.state.ak.us> Tom, Sorry it took so long: you know how it is with offsite files. We are looking now at the first or second week of April depending of course on how P2-15 goes. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 02, 2007 11:59 AM To: Gagliardi, Shane T Subject: Re: 03-36A AOR Thanks Shane. When is spud projected? Tom Gagliardi, Shane T wrote, On 3/2/2007 11:22 AM: Tom, Here is my review for 03-36A. Any questions, let me know. Thanks, Shane «03-36A AOR Well Review.ZlP» Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) ~~. 1 oft 3/6/2007 4:05 PM Well Section De the Cmt Vol/ T pe Cmt Len th Cmt Returns / Reci PTest /CBL Comments 03- 9 5/g' Prod 0 - 9215 203 bbls 15.8 3639' Csg to 3000 psi Tag cmt @ 9092, drill soft cmt to FC ~ Cs class G 9128. 03-0~ 9 5/e" Prod 0 - 203 bbls 15.8 3639' Csg to 3000 psi Tag cmt @ 10239, drill cmt to FC @ Cs 10337 class G 10255. 03-20 9 5/8" Int 0 - 8702 101.5 bbls 15.9 1819' Circ and Recip throughout 7/18/83 CBL/VDL Tag cmt @8581, drill firm cmt and Cs class G "ob, ood returns 8600 - 6780 FC/FS to 8702'. 7" Prod Lnr 8409 - -72 bbls 16.2 3202' 7/20/83 CBL 9240 Drilled firm cmt 8169 - 8404 and 9293 class G - 9300 8975 - 9246 P&A 9246 15 bbls inside 404' 1500 si 30 min Ta ed TOC 8394 KOP 8106 - 32 bbls 17.0 ppg 437' Hesitation Sqz Section mill 8106 - 8156 03-20A 8156 class G 2000 si Drill cmt KO lu 7853 - 8111 7" Prod Lnr 7920 - 52 bbls 1.5.9 ppg 2301' Recovered 70 of 75 bbls 9336 class G re-flush from liner to 9 5/8" Int 0 - 9130 101.5 bbls 15.9 1819' Drill cmt to 9155 on drill out. 03 30 Cs class G - 7" Prod Lnr 8821 - 66 bbls 15.8 ppg 2920' Drill cmt from 8465 - 8821 7/9/84 CBL/VDL Circ and Recip throughout Job. TOC 9699 class G 9630 - 8730 9110 from CBL. 9 5/8" Int 0 - 9324 101.5 bbls 15.9 1819' N/A / No recip reported Tagged 9 5/8 FC @ 9241' and drilled 03 34 Cs class G 55' cmt/shoe. - 7" Prod 9073 - 61 bbls 15.9 ppg 2695' Circ and recip throughout 2/27/86 CBL CBL showed good coverage. Liner 9860 class G ~ob 9797 - 8962 P&A PBTD 37.5 bbls 15.8 1011' Hesitation Squeeze. Csg to 2300 psi 9660' class G Ta ed cmt 9320' 03-34A KOP 8073 31 bbls 15.8 ppg 424' Hesitation sqz, held Section mill 8010' - 8075'; milled cmt class G 1500 si for 1 hr and fma 8048-8064'. 7" Int Liner 8056 - 88 bbls 15.8 ppg 3894' Reversed out 20 bbls, circ 9978 class G and reci throu hout ~ob 7" Int Liner 7315 - 86 bbls 15.8 ppg 3805' pH increase when circ off Short pipe recip Set 9 5/$ EZSV @ 7526, whipstock 03-34B 9588 class G liner to towards end of ~ob and mill; FIT to 12.5 EMW 4-%" Liner ~ Slotted Liner 03-34C 2 '/8" Liner ~p'a---d ~~ Pre-drilled /Slotted 9 5/8" Int 0 - 329 bbl 7509' Unable to Racip Csg to 3500 psi Tag cmt @ 11809, drill hard cmt to FS Csg 11906 12.0 ppg lead 90 @ 11819 03-36 bbls 15.8 tail 7" Prod Lnr 11733 - 38 bbls 15.8 ppg 1681' Circ 32 of 70 bbls of pre- Could inject through liner hanger. Set 12569 class G flush from liner to liner to kr and test to 3500 si. 16-15 9 5/8" Int 0 - 101,5 bbls 1819' Tag cmt @ 10704. ~ Cs 10789 15.8 class G ~ " ' 7 Prod Lnr 10574 - 54 bbls 15.8 ppg 2399 Full returns throughout job Test Liner lap to Drill cmt 10165 to 10574 and 11144 11388 class G 3000 psi for 30 min to FC @ 11342. 12/13/85 -Acoustic Lo ? DS 3-36A • lofl Subject: DS 3-36A From: Thomas Maunder <tom_maunder@admin.state.aic.us> Date: Tue, 13 Feb 2007 14:09:01 -0900 To: Shane Gagliardi <gaglst@bp.com> CC: greg hobos <Greg.Hobbs@bp.com> Shane, I just started reviewing the 401 for this well. I see that you have included a plan view showing all the wellbores within 1/4 mile at the payzone horizon. Do you have an assessment of the formation isolation for these identified wells at the penetrations into the Sadlerochit (nominally the 9-5/8" casing shoe)? You might check with Phil Smith, he is working on this information for 9-15A. I know you have identified a number of wells and there is some work required to make the assessments. I plan to confirm what you might find/report, however the primary assessment needs to come from you all. Call or message with any questions. Tom Maunder, PE AOGCC 2/13/2007 2:09 PM • TRAYSI~IITTAL LETTEIa CFIECKLIST VNELL YAItitE ~GPL1 03- 36A PTD# ~?©,~- Oda Development / Service Exploratory Stratigraphic Vest Yon-Conventional Well Circle .4ppropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK I ADD-ONS TEXT FOR APPROVAL LETTER 1~4'HAT ~ (OPTIONS) APPLIES L ~ MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well i (If last two digits in I Permit Rio. , AP[ No. 30- - - API number j between 60-69) are ;Production should continue to be reported as a function of the' original API number stated above. ;PILOT HOLE In accordance with 20 A.4C 25.00~(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both ' j well name ( PH) and API number ~ ' (50- - -_) from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION ~ 23.0». Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j exception. assumes the ~ ~ ~ i liability of any protest to the spacing exception that may occur. ,DRY D[TCH ~ ; AI[ dry ditch sample sets submitted to the Commission must be in i SA!viPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and IO' sample intervals j I through target zones. Please note the following special condition of this permit: Non-Conventional ;' production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCom~anv Name) must contact the !Commission to obtain advance approval of such water well testing j ~ program. 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