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Home My WebLink About204-184STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 6 t u tial hi,,. A IAN 0 2 2n9n la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned RI Suspended ❑ 1b. Well Class: 20MC 25.105 20AAC 25.110 Developm!�� e 10 GINJ ❑ WINJ 11WAG ❑ WDSPL ❑ No. of Completions: Zero Service ❑ Stretigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., or Abend.: 12/16/2019 14. Permit to Drill Number/Sundry 204184 / 3 / 1 - 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 10/30/2004 50-029-20023-02-00 4a. Location of Well (Governmental Section): e. Date TD Reached: 16. Well Name and Number: 11/7/2004 PBU J -02B g Ret Elevations KB 63.39 17. Field/Pool(s): Surface: 1080' FNL, 1245' FEL, Sec. 09, T71N, R13E, UM Top of Productive Interval: 3606 FNL, 2082' FWL, Sec. 10, T1 IN, R13E, UM GL 41,10 BF Surface PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 3639' FNL, 3728' FVVL, Sec. 10, T11N, R13E, UM Surface / Surface ADL 028281 4b, 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number. Surface: x- 643114 y- 5970265 Zone - ASP 4 12028't 9019' 85-24 12, SSSV Depth (MD/TVD): 20. Thickness of Permafrost MO/TVD: TPC x- 646496 y- 5967725 Zone - ASP 4 Total Depth: x- 648140 y- 5967803 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDrrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9916'/ 8779' 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 my, 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 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 30" Surface 96' Surface 96' 36" 175 sx Fondu 20" 94# H40 Surface 937' Surface 937' 26" 2000 sx Fondu 13-3/e" 7#/6/60# N-BOIK-WJ-55 Surface 4595' Surface 4354' 17-1/2" 3150 sx Class'G' 10-3/4"x9-5/8' 55.5#/47# W80 Surface 9916' Surface 8779' 12-1/4" 1370 sx Cless'G', 725 sx Class'G' 7" 26# L-ro Surface 9302' Surface 8232' Tieback 417 sx Clsss'G', 118 sx Arctic Set 5-1/2" 17# LA0 9105' 9916' 8062' 8779' Scab Liner 155 sx Class G 3-1/2" 9.2# L-80 9772' 12028' 8651' 9019' 4-3/4" 168sx Class'G' 24. Open to production or injection? Yes ❑ No Rl 25, TUBING RECORD If Yes, list each interval open (MDrrVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (f iV Size and Number; Date Perfd): 4-1/2" 12.8# 13C180 9096' 9036'/8003* to I._ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. l'1 OV4(�V� O Was hydraulicfractunng used during completion? Yes ❑ No Per 20 AAC 25.283 (i)(2) attach electronic and printed D TE Ainformation 12 VERIFI D DEPTH INTERVAL MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27 PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): WA Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period --11- Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravib- API (oon): Press 24 Hour Rate --► I Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ,#f/�,", M4lp�, RB®MS ''JAN 0 6 2020 V \ 4 28. CORE DATA Conventional Consist Yes ❑ No 0 Sidewall Cores Yes ❑ No If Yes to either question, list formations and intervals coretl (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 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No m Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10373' 9014' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 2B 9980' 8836' Zone 2A 10062' 8906' Zone 1B 10373' 9014' Formation at total depth: Zone 1B 10373' 9014' 31. List of Attachments: Summary of Daily Work, Photo Documentation, 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 or well 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: Olodgewitch, Beau Authorized Title: SIM peciali Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Signature: Date: 171�P` 1j Contact Phone: +1 907 564 4854 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 ib. 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. Review the 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 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. Item 30. Provide a listing of intervals tested and the coresponding 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 10407 Revised 5/2017 Submit ORIGINAL Only TREE= DRY HOLE wroA/ooA CMr SURF -2040' WELLHEAD= CAMERON ACTUATOR= REMOVED OKB. ELEV = 57.33' REF ELEV = _ 63.39' BF. ELEV = KOP = MaX Ang@ _. SURFACE 2400' 94' � 10740 Dahm MD = Dahm TVD = 9939' 8800' SS 30'COND7 96' J 0 / B TBro` GM/oA oA 300'-310' PUNCH (12,95/19) TBGM/OA ro0A 671'-681' PUNCH (11/10/19) TBG CMT 01/10/19) 68 120' CSG, 94#, N40 8 -RD, ID = 19.124- 1- 931' 10-3/4' CSG, 55.5#, N-80, D = 9.76' 2003' 9-5/8' CSG PATCH, D =2063' / TAGGED TOC (6/19/19) & EST BOC T X A (06/04/19) 17' DV COLLAR - 4019' 13-0/8' CSG, 68#, K55, ID = 12.415' 4589' 9-5/B'DV COLLAR 8492' ABANDONED WELLHEAD CUT 5.2' BELOW TUNDRA 12/16/19 Minimum ID = 2.992" @ 9772' 3-1/2" SOLID LINER 4-112- TBG, 12.6#, 13CR40, 9093' .0152 bpf, ID = 3.958- TOP OF 5-12' LNR 9105' 7- TACK LNR 26#, L-80, D = 6276' 9296' TOP OF 3-12' LNR 9777 TOPOF5-1/2' WHIPSTOCK I 9-5/8' CSG, 47#, N-80, D = 8.681' PERFORATION SUMMARY REF LOG: SWS MWD on 11/07/04 ANGLE ATTOP PERF: 89°@ 10450' Note: Refer to Production DB for tistorical perf data SIZE SPF INTERVAL NS z SHOT SOZ 2' 6 10450-10480 S 11/10/13 10/19/14 2' 6 10678 -10948 S 17/14/04 10/19/14 2' 6 10978 -11098 S 11/05/04 10/19/14 2' 6 11328-11428 C 11/05/04 2' 6 11508-11608 C 17/05/04 2' 6 11648 -11808 C 11/05/04 2' 6 11853 -11928 C 11/05/04 SAFETY NOTES_ 7" SCAB LNR CMTD & SET ON EMERGENCY SLIPS DURING RIND. "WELL RENAMED J - 02A WHEN IT WAS DEEPENED FROM TIE PUT RIVER FORM TO THE IVISNIIK.- 4-12" CHROME TBG" 06112177 9-58" DV PKR SQZ (300 sx) & 07107/92 (400 sx)' SURF -300' CMT 00- -000A (12/07/19) SURF -600' GMTTBG(12/07/19) 861' 73-3/8' FOC 2003' 70.3/4' X9-5/8' XO 2030'-2040' TBGPUNCH,(1025/19) 2042' 9-5W FOC 2184' -12- HES X NP, ID=3.813'1 3264' EST TOP OF CEMENT 5955' E6T TOP of c1E,sir GAS LFT MANDRELS rl MD I ND DEV TYPE VLV ILATcHl FoRTI DATE '3 5583 5777 33 KBG2 SO BKL2�O'2 7538 6764 33 KBG2 DMY BK '1 8946 7928 33 KBG2 EMP(Y - STA —#3 2 & 7 = BEHIND CEM ENT 5 901— 4-1/2' HES X NP, D = 3.813- 9036' x--17' X 4-12' BKR PKR, D = 9105' I7- X 6' BKR TEBACK SLV, D = 5.50' 9093' 4-1/2' WLEG, D = 3.958- 9111' 7- X 5-7/2' BKR LTP & HGRD = 4.89' 929G 9-5/13' x 7' BKR TACK LNR PKR SHOE 979W 5-1/2' X 3-1/2- HMC HGR, 1) MILLOUT WINDOW (J-0213) 9916' - 9928' 7� MARKERJOINT 3-7/2' LNR 92#, L-80 12028' .0087 bpf, D = 2.992' DATE REV BY COMMENTS DATE I REV BY I COMMENTS 05115MS INITIAL COMPLETION 10/30/19 STN/JMD TBG PUNCH (1025/19) 11106169 SIDETRACK (J -02A) 77/13/19 JJL/JMD TBGMA/OA/OOACMT 0710682 N48E RIND 77/13/19 NXW1JMO PUNCH TBGM/OA/OOA&TAG CMT 1111784 D46 SIDETRACK (J -02B) 12/30/19 TJS/JMD PUNCH TBG/WOAIO0A(12105/19) 06/10/19 TWJMD ADDED NOTE GLM BEHIND CMT 12130/19 AB/JMD CEMENTED OA & OOA 12/07/19 0625/19 JNUJMD ADD REF, BF, COND, & TAG CMT 12/30/19 JA/JMD FULLYABANDONED (72/16119) PBTD 1-1 11929' PRUDHOE BAY UNIT WELL: J -02B PERmrr No: 1690970 API No: 50-029-20023-02 SEC 9, T11N, R13E, 1080' NSL & 1245' WEL BP Exploration (Alaska) NT"N'LITIIM4 J -02B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 2030'- 2040' Punch Tubing 155 Bbls Class 'G' pumped in OA / OOA 89 Bbls Class'G' pumped in OA 687' 89 Bbls Class'G' 671'- 681' Perforate Tubing and Casing 300'- 310' Perforate Tubing and Casing Surface 196 Bbls Class 'G' Surface 12.6 Bbls AS I ***JOB STARTED ON 25-OCTOBER-2019*** (SLB ELINE PERF)*** PUNCH TBG, IA, OA FROM 2,030'- 2,040' ELMD WITH 2.0" POWERJET, HMX, 6 SPF, 61 SHOTS, 60 DEG PHASED. CONFIRM T x IA x OA x OOA COMMUNICATION. 10/25/2019 ***JOB COMPLETE ON 25-OCTOBER-2019*** T/I/O=SI/0/0 Remove WIA and CIA and instal Integral flanges and block valves. Remove tapped blind flange from OA and install Integral flange. Remove tapped blind flanges from OOA riser pipes and install Integral flanges and Block Valves. FWHP's=Sl/0/0 *** Job 10/27/2019 Complete*** SW/MV=C WIA/CIA/OA/OOA/OOOA=OTG T/I/O = Temp- Shut in. (LRS Unit 72 Plug and Abandonment). Pumped 5 bbls 60/40 Meoh and 192 1 % KCL heated to 200* into TBG Taking returns up IA to OTT. ***Job 11/2/2019 continued on 11/03/2019*** ***Continued WSR from today for daylight savings time*** (LRS Unit 72 Plug and Abandonment) Pumped 83 bbls 180* DSL down TBG taking returns up OA & OOA to OTT. Pumped 90 BBLs 170* 9.8 brine Down TBG up OA & OOA. Pumped 165 bbls surfractant down TBG up IA, OA, OOA to OTT. Pumped 245 bbls 9.8 brine down TBG up IA, OA, OOA to flush out remaining arctic pack and surfactant. Pumped 20 bbis of 60/40 Meoh into the TBG with OOA returns. U-Tube TxIAxOAxOOA. Freeze protected surface equipment with 7 bbls of 60/40 Meoh. See log for more details. T/I/O/00/000 = 0/7/7/6/0. All 1/4 turns valves 11/3/2019 are closed. Dry hole tree valves are open. IA/OA/OOA/OOOA are OTG. Pad Operator ***Job continued from 11/02/2019*** (LRS Unit 72 Plug and Abandonment) Pumped 97 bbls 1 % KCL down TBG up IA taking returns to OTT. Pumped 38 bbls DSL Down TBG up 11/3/2019 OOA taking returns to OTT. ***Daylight savings time Continued WSR*** T/1/0=100/100/0/0 Temp=Sl (PLUG AND ABANDONMENT) Arrive on location, spot equipment, rig up and pressure test. Pump 1 bbls total of 60/40 to confirm surface lines are clear and communication to IA. 11/4/2019 ***WSR Continued on 11-05-2019*** SLB Cementing - OOA/OA Surface Cement plug (PLUG AND ABANDONMENT) Pumped a total of 155 bbls of 15.8 ppg class G cement down TBG with OOA returns - Excess cement required to get clean returns to surface. Pumped a totaFoTB7bUrs-5TW.8 ppg class G cement down TBG with OA returns. Pumped 20 bbls of 9.8 ppg NaCl down TBG with OA returns to clear cement out of TBG down to 1315' MD. Pumped 90 bbls of 9.8 ppg down TBG with IA returns to flush all cement from TAA in preparation for next cement stage. SLB loading out cement to finish job scope. ***Job continued on 11-05-19*** TOC: OOA/OA @ Surface 11/4/2019 BOC: OOA/OA @ 204TIVID SLB Cementers - IA Surface Cement Plug (PLUG AND ABANDONMENT) Pumped the following down TBG with IA returns to OTT: 5 bbls 60/40, 5 bbls freshwater, 89 bbls 15.8 ppg class G CMT, 3 bbls freshwater to flush lines, dropped 7" foam ball, 9.9 bbis 9.8 ppg NaCl, 2.3 bbis 60/40 for surface freeze protect (Total displacement of 15.2 bbls). IA/OA/OOA CSG valves = C. MV/SV/Block valves = C. Pad Op notified. ***Job Complete*** TOC: IA surface, TBG @ 1000' MD 11/5/2019 BOC: TxIA @ 2040' MD ***WSR Continued from 11-04-2019**** Pumped 5 bbls 9.8 Brine down TBG taking returns up IA to open top to confirm communication. Pumped 1 bbl 60/40 to FP tree and 6 bbls total to FP surface lines and confirm communication. 11/5/2019 FTIO= 22/0/0 SV/WV=closed Daily Report of Well Operations PBU J -02B ***WELL SHUT IN UPON ARRIVAL*** (ELINE PERF FOR P&A) INTIAL T/1/0/00=0/0/0/0 RIH W/ 10FT 2.5" POWERJET 6 SPF, 60 DEG PHASING, FIRE CENTERED TAG TOC @ 687' WITH BOTTOM OF GUN PUNCH TUBING= 671'-681', CCL TO TOPSHOT=3.75', CCL STOP DEPTH=667.25'. 11/10/2019 ***JOB COMPLETED, PAD OP NOTIFIED*** T/1/00/00= 0/0/0/0 Temp= S/I (LRS Unit 72 - Verify Tx000A Communication Post Eline Pert) Arrive on location, PJSM, RU to tree cap, Pressure tested surface lines to 1180 psi 11/12/2019 ***WSR Continued on 11-13-19*** ***WSR Continued from 11-12-19*** Temp= S/I (LRS Unit 72 - Verify Tx000A Communication Post Eline Perf) Pumped a total of 3 bbls 60/40 down TBG to verify Tx000A communication, No apparent communication, Pressured TBG up to 200 psi, TBG pressure falls instantly coming off pump, See log for details, 11/13/2019 FWHP= 70/0/0/0/0 T/I/O = 20Nac/0/20/0. Temp = SI. Enclose cellar to thaw. No wellhouse or flowline, dry hole tree installed. Composite cellar grating is installed with drilling scaffolding in place. Laid out high temp visqueen over the top of cellar grating and installed heater. 2nd heater is on 11/14/2019 location if needed. T/I/O/00/000 = 20/Vac/0/20/0. Temp = SI. Check cellar thaw. Visqueen in place and secured to grating with heater aimed in cellar. Cellar looks to be thawed all the way. Called to have cellar Vac'ed out. Heater working properly. 11/15/2019 SV = C. MV = O. IA, OA, ODA, OOOA = OTG. 02:40 T/I/O/00/000 = 10/Vac/Vac/0/30. Temp = SI. Check cellar thaw. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 29" of fluid @ 6 o'clock position, fully thawed. Dispatch contacted to have cellar fluid evacuated. Heater working properly. TP decreased 10 psi, IAP unchanged, OAP went on a Vac, OOAP decreased 20 psi and OOAP increased 30 psi overnight. 11/16/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 01:30 T/I/O/00/000 = 101Vac/Vac/0/20. Temp = SI. Check cellar thaw. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 27 1/4" of fluid @ 6 o'clock position, fully thawed. Dispatch contacted to have cellar fluid evacuated. Heater working properly. TP, IAP, OAP, OOAP unchanged, OOOAP decreased 10 psi overnight. 11/17/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 03:00 T/I/O/00/000 = 10/Vac/Vac/0/30. Temp = SI. Check cellar thaw. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 28" of fluid @ 6 o'clock position, fully thawed. Heater working properly. TP, IAP, OAP, OOAP unchanged, OOOAP increased 10 psi overnight. 11/18/2019 SV = C. MV = O. IA, OA, ODA, OOOA = OTG. 01:00 T/I/O/00/000 = 2/Vac/Vac/30/0. Temp = SI. Check cellar thaw. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 28" of fluid @ 6 o'clock position, fully thawed. Heater working properly. TP lost 08 psi, IAP, OAP unchanged, OOAP increased 30 psi, OOOAP decreased 30 psi overnight- vernight.11/19/2019 11/19/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 13:40 T/I/O/00/000 = 1/Vac/Vac/0+/30. Temp = SI. Check cellar thaw. Integral installed on IA @ 12 o'clock =inspection not current. Dry hole tree and rig scaffold installed. No well house or flow line. Cellar has 30.75" of fluid @ 6 o'clock, fully thawed. OOOA CV is below fluid, top of CV -6" below fluid. TP decreased 1 psi, IAP, OAP, OOAP & OOOAP unchanged since 11/19/19. Heaterworking properly. 11/21/2019 1 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 03:30 Daily Report of Well Operations PBU J-02B T/1/0/00/000 = 0/Vac/Vac/0/30. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 30.75" of fluid @ 6 o'clock position (cellar FL unchanged), fully thawed. OOOA CV is below fluid, top of CV -6" below fluid. WHPs unchanged overnight. Heater working properly. 11/22/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 01:30 T/1/0/00/00 = VacNacNaG0/30. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 31.75" of fluid @ 6 o'clock position, fully thawed, cellar FL inflowed 1" overnight. COCA CV is below fluid, top of CV is -7" below fluid. TP went on a Vac, IAP, OAP, OOAP & OOAP unchanged overnight. Heater working properly. 11/23/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 04:15 T/1/0/00/000 = VacNaG0/0/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock (inspection not current). Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 16.0" of fluid @ 6 o'clock position, fully thawed, cellar FL dropped -16" overnight. OOOA CV is above fluid, TP went on a Vac, IAP, OAP, OOAP unchanged & OOOAP decreased 10 psi overnight. Heater working properly. 11/24/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 00:45 T/1/0/00/000 = VacNac/0/0/30. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26" of fluid @ 6 o'clock position, fully thawed. Cellar FL inflowed 10" overnight, OOOA CV is above fluid. TP, IAP, unchanged, OAP & OOAP changed from vac to 0 psi. OOOAP increased 10 psi overnight. OOOA is flanged up to the tree. There is a blind flange opposite the OOOA. Heater working properly. 11/25/2019 1 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 22:00 T/1/0/00/000 = Vac/VaGVac/Vac/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 16" of fluid @ 6 o'clock position, fully thawed. Cellar FL unchanged overnight, OOOA CV is above fluid. TP, IAP, OAP & OOOAP unchanged, OOAP went on a Vac overnight. Heater working properly. 11/25/2019 SV = C. MV=O. IA, OA, OOA, OOOA = OTG. 01:15 T/1/0/00/000 = VacNaGO/0/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26" of fluid @ 6 o'clock position, fully thawed. Cellar FL unchanged overnight, OOOA CV is above fluid. TP, IAP, unchanged, OAP & OOAP changed from vac to 0 psi. OOOAP decreased 10 psi overnight. COCA is flanged up to the tree. There is a blind flange opposite the OOOA. Heater working properly. 11/26/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 23:00 T/1/0/00/000 = VacNac/0/0/30. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26" of fluid @ 6 o'clock position, fully thawed. Cellar FL unchanged overnight, OOOA CV is above fluid. TP, IAP, OAP & OOAP unchanged. OOOAP increased 10 psi overnight. COCA is flanged up to the tree. There is a blind flange opposite the OOOA. Heater working properly. 11/28/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 00:30 T/1/0/00/000 = VacNac/0/0/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26" of fluid @ 6 o'clock position, fully thawed. Cellar FL unchanged overnight, OOOA CV is above fluid. TP, IAP, OAP & OOAP unchanged. OOOAP decreased 10 psi overnight. OOOA is flanged up to the tree. There is a blind flange opposite the COCA. Heater working properly. 11/29/2019 SV = C. MV=O. IA, OA, OOA, OOOA = OTG. 01:15 Daily Report of Well Operations PBU J-02B T/I/O/00/000 = VacNac/0/0/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26.5" of fluid @ 6 o'clock position, fully thawed. Cellar FL came up 1/2 inch overnight, OOOA CV is above fluid. WHPs unchanged overnight. OOOA is flanged up to the tree. There is a blind flange opposite the OOOA. Heater working 11/30/2019 properly. T/I/0= 0/0/0 Temp-SI. LRS Unit 72 (PLUG AND ABANDONMENT). Pumped 27 bbls DSL down TBG & OOA & OOOA to trouble shoot well. See log for more details. ***Job continued 12/1/2019 on 12/02/2019*** T/1/0/00/000 = VacNac/0/0/20. Temp = SI. Eval cellar thaw. Integral installed on IA @ 12 o'clock position =inspection not current. Dry hole tree and drilling scaffold installed. No well house or flow line. Cellar has 26.5" of fluid @ 6 o'clock position and is partially frozen due to heater being removed. OOOA CV is above fluid. WHPs unchanged overnight. OOOA is flanged up to the tree. There is a blind flange opposite the CODA. Hardline and kelly hoses are rigged to the tree cap, OOA and OOOA from a choke trailer and an OT tank. 12/1/2019 SV = C. MV = O. IA, OA, OOA, OOOA = OTG. 01:15 ***Job continued from 12/01/2019*** Plug & Abandonment issues. Pumped .04 bbls Diesel into OOA to pressure up to 1000 psi in attempt to circ out arctic pack. WFO notified upon departure. FWHP's = 110/0/0/6/6. Valve possitions are Dry Hole SV's (c), CV (c), IA, OA, 12/2/2019 OOA, OOOA (OTG),Choke Trailer 1/4 turns (C) ***WELL SHUT IN UPON ARRIVAL*** (ELINE PERF FOR P&A) INTITAL T/1/0/00/000=50/0/0/0/0 PERFORATED 300'-310'W/ 2.875" POWER JET 6SPF 60 DEG PHASING CENTERED, CCL TO TOPSHOT=3.54', TS TO BS=9.83', CCL TO BOTTOM SHOT=13.33'. ESTABLISH CIRCULATION FROM TUBING TO OOA & OOOA (see Irs report) 12/5/2019 ***JOB COMPLETED, PAD OP NOTIFIED*** T/l/O = -15/0/-5/0/0 Temp-SI. LRS Unit 72 Assist E-Line (PLUG AND ABANDONMENT). Pumped 11 bbls diesel and 33 bbls 60/40 meoh into TBG to establish communication with e pen top tank fluideve upon arrival was15 bbls, currently at 22 bbIs upon departure (5-1 returns). SV and Flow Cross (C); IA, OA, OOA, OOOA all (OTG). WFO 12/5/2019 notified upon departure. FWHP's = -15/0/-5/0/0 Job Scope: Circ Arctic Pack from OOA and OOOA. Circ 11 bbls Arctic pack from OOA w/ 42 bbls 9.8 brine. 60% returns. Attempt to circ Tbg x OOOA w/ no success. Pump Arctic pack down OOOA w/ returns from OOA in two stages. Circ all strings to 9.8 brine. Circ all strings w/ 160 bbls hot FW w/ F103 and U067. Circ all strings to brine. Freeze protect Tbg, OOA, and OOOA w/ 1/2 bbi MW each. Final circulations were losing 25% to formation. Recovered 12/6/2019 -40 bbls water/brine from J-X2 cellar. Circ out complete Job Scope: Pre P&A Cement tbg, OOA, and OOOA to surface OOA and OOOA surface to 300' and Tbg surface to 600'. Pumped total of 96 bbls top down. 15.8 ppg class G uni-slurry cement. Thick.Time 50 be 5.5 hrs. FL 34cc / 30 mins. Filled each string and alternated by pumping additional cement to top of each until out of cement. Final shut in pressure on each string -70 psi Pumped 15 bbls into Tbg (Vol to 600'9 bbls) Pumped 17 bbls into ODA Vol o 300' 11 bbls 12/7/2019 Pumped 64 bbis into OOOA Vol to 300'55 bbls) Plug and Complete Abandonment 3' below Tundra per AOGCC Requirement. Excavate 15' x 15'x 15' deep hole for can shoring box. Picture taken of tundra and gravel pad interface 10' up from bottom of hole. Installed shoring equipment and back filled around it. BP IH and 12/12/2019 WOA Fire Department on site to approve Air movement plan and ERRP. Rig up to well tree and conductOor with crane. Cut window, chip cemetn in between each Csg stirng and test can string for LELs. Completed cut of wellhead and extracted from can 1213/2019 with crane. Cleanup and secure jobsite. Daily Report of Well Operations PBU J -02B Prep wellhead stub for marker plate. Confirmed depths of cement top in IA/OA/OOOA IA= 60', OA= 250', OOOA= 2' Cement pump committed to CTD will be availible to assist 12/14/2019 tomorrow. Secure area for night. Dress top of casing strings for Marker Plate. Rig up and RIH w/ 100' of 1/2" pipe down OA. Batch up Arctic Set 1 Cement. Fill IA w/1.1 bbls, OA w/ 11.1 bbls. OOOA w/ A bbls. Cement to surface in all Csg strings. Notification for witness sent to AOGCC. Mattt Herrera 12/15/2019 responded. Secure area for night. Plug & Abandon. Excavate from pad grade down 15', Install shoring system. Cut wellhead 12' below pad grade. Weld marker plate and bury. AOGCC witness top of cement and marker plate install - Matt Herrera. All final depths are: Pad grade = 39.4', Tundra grade = 12/16/2019 32.6' Wellhead cut = 27.4', Wellhead is cut and abandoned 5.2' below tundra grade. *** Job MEMORANDUM TO: FROM Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: Matt Herrera SUBJECT: Petroleum Inspector 12/16/19 Surface Abandonment PBU J -02B BPXA ✓ PTD 2041840; Sundry 319-315 12/16/2019: Traveled out to PBU J -02B well location and met with BPXA representative Jon Arend and walked down excavation to inspect well casing stub. Previous inspection by BPXA showed well had void in the surface casing by conductor annulus after pumping the surface abandonment cement plug. Repairs had been made with top job cement to seal off voids. Cement inside and outside of casing strings was solid with cement tops at surface. Depth of casing strings cutoff was determined to be at 15 feet below pad and 5 feet below natural grade. Inspection of the marker plate was found to have the correct well name but wrong PTD r number and an incomplete API number. The operator appears to have used an old schematic of the well (J -02A) that had been previously abandoned (plugged back) and redrilled instead of relying on the current completion schematic (and approved sundry) for the marker plate information. Mr. Arend was instructed to have welder grind off plate information and re -weld correct information on the marker plate. After verification of well information I then told them to proceed with welding the marker plate on the J -02B casing stub and backfill when complete. Attachments: Photos 2019-1216_Surface_Abandon _PBU _J-02B_mh.docx Page 1 of 4 Surface Abandonment — PBU J -02B (PTD 2041840 Photos by AOGCC Inspector M. Herrera 12/16/2019 VELL NAME Ja02B v7VNER Prudhoe Bay Unit BP Exploration (Alaska) Inc. PI NUMBER 50-029-20023-02-00 LOCATION NE 1,4, Sec. 09, T11N, R13E ING PERMIT 204 184 2019-1216_Surface_Abandon_PBU_J-02B_mh.docx Page 2 of 4 Well sign Wellhead removed from PBU J -02B 2019-1216_Surface_Abandon_PBU_J-02B_mh.docx Page 3 of 4 Cut-off at proper depth; hard cement to surface Marker plate with incorrect info (PTD 1690970) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -02B Permit to Drill Number: 204-184 Sundry Number: 319-315 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aog c c.a la s k a.gov 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, 0�� Daniel T. Seamount, Jr. Commissioner d n DATED this Z day of October, 2019. RBDMS `^-� OCT 0 71019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUN ^ 9 7019 1. Type of Request: Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair -Well ❑ Operations shutdown ❑ t f Iy Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing EIChange 4Q � Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 204-184 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number 50-029.20023-02-00 99519-6612 StretigrePhiC ❑ Service ❑ 7, If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a sparing exception? Yes ❑ No 0 PBU J-028 9, Property Designation (Lease Number): 10. Field/Pools. ADL 0028281 - PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Tolal Depth MD (6). Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MpSP (psi): Plugs (MD): Junk (MD): 12028 9019 3328 3275 3328 9059 11934 Casing Length Sin MD TVD Buret Collapse Conductor 70 30" 26-96 26-96 Surface 911 20" 26-937 26-937 1530 520 Intermediate 4571 13-3/8" 24-4595 24-4354 5380 13450 13090 2670 11950 / 1540 Intermediate 9884 10-3/4" x 9-5/8" 22-9916 22-8779 6450 / 6870 4020/7460 0 -8232 7240 5410 Tieback Liner 9282 T 20-9302 20-8L Liner 811 5-1/2" 9105-9916 8062 - 8779 7740 6280 Liner 2256 3-1/2" 9772-12028 8651-9019 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 1 Noi I 4-1/2"12.6# 13Cr80 18-9096 Packers and SSSV Type: 4-1/2' Baker Production PKR Packers and SSSV MD (ft) and TVD (ft): 9036/8003 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 ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: July 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH0bp.com Authorized Name: Obrigewitch, Beau Contact Phone: +1907 564 4854 Authorized Title: Well Integrity Engineer Authorized Signature: Date: to 0 2 D C( OF I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. J ✓✓1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Qearance Other /—d s 4co-r;jW .04 Q1"oC ulvtem.a Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMSk,-' OCT 0 7 2019 Spacing Exceplio quired? Yes ❑ No Q' Subsequent Form Required: /Q— 007 APPROVED BYTHE r a �' Approved by: COMMISSIONER COMMISSION Date (I ORIGINAL V'r— t o ` — 'l r.d JZ A?�',—Q9• Submit Form and Form 1023 Revised 04/2017 Approved application is valid for 12 months from the date of approvFal. 9��(�yr pAttachments in Duplicate J-02 Full Plug and Abandon Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Julie Wellman (907) 564-4657 Expected start date: July 15t', 2019 History J-02 was completed with a Gen 1 Permafrost Wellhead and multi -string casing design in 1969. The outer casing string is set in permafrost. GWO has determined wells of this construction are at risk for su en we ea movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSE consequence associated with this potential risk. ✓ In March thru June 2019 reservoir plug and abandonment operations were completed per Sundry 319- 038. On June 19, 2019 AOGCC witnessed a passing CMIT-TxIA and cement tag of the reservoir plug. This was reported on a subsequent 10-404. Please note, this program is designed to complete the P&A in accordance with Docket OTH-18-062. This well was later identified as a potential rig decomplete by AOGCC. Accordingly, the P&A work detailed in this program will not be initiated until Sundry Approval is granted by AOGCC. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. This P&A program is designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviations captured in eMOC 10439. Job Steps 1 V Drop annulus gate valves and install integrals 2 E Perforate 3 J a. Circ out and Surfactant Wash b. Cement IA, OA, and OOA 4 E Perforate 5 J a. Circ out and Surfactant Wash OOOA b. Cement OOOA and Tubing 6 D Bleed WHPs to 0; Monitor after 24 hrs 7 J Excavate for Full P&A; Remove Wellhead; Install Marker Plate; (AOGCC)(Permanent) [Excavate & Install Shoring Box] 2019 Procedural steps Valve Shop 1. Drop all annulus gate valves and install integral valves. Eline Perforate at 2,030' through 4-1/2" Tbg, IA, 7" Csg, Arctic Packed OA, and 9-5/8" Csg, into the Arctic Packed OOA. This creates a circulation path from the tubing into the IA, OA, and OOA. • Haliburton 2" Millennium, 6 SPF, 60° Phasing, 10 -ft perf length; Fire Eccentered • WSL discretion to use unit depth measure or CCL/GR; CCUGR not required for tie-in as depth is not critical Special Projects / Fullbore Note: Rig up in such a way that returns can be taken from the IA, OA, and OOA independent from one another. This step is designed to prepare these annuli for cement, and then cement them to surface, circulating down the tubing. Include a ball launcher in the rigup to chase the final cement. Note: The order of operations can be modified at WSL discretion for operational efficiency and risk reduction, provided the intent of removing Arctic Pack from the annuli and surfactant washing all tubular surfaces is achieved. 3. Clean Arctic Pack out of OA and OOA; Surfactant wash IA, OA, and OOA: Pump at maximum rate or 2,500 psi. • Pumping down tubing, taking returns from OOA: i. 5 bbis meth ii. 110 bbis 160°F heated diesel • After -81 bbis pumped, swap to taking returns from OA (this will put -50 bbls in the OOA) i. Pump remaining diesel, then swap to 180°F heated 9.8 ppg brine ii. Pump 31 bbis of brine, continuing to take returns from the OA (putting -60 bbis of diesel in the OA), displacing all diesel out of the tubing and into the OOA and OA. iii. Freeze protect surface equipment as needed • Shut down and let diesel soak for 1 hr • Resume pumping 1807 9.8 ppg brine down the tubing i. Take 50 bbis of returns from the OA, then swap to take returns from OOA ii. Take 40 bbls of returns from the OOA • Swap to pump 135 bbls hot surfactant wash down tubing (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) i. Take 81 bbis of returns from OOA (putting -50 bbls of surfactant wash in OOA), then swap to take returns from the OA ii. Take 60 bbis returns from OA (putting 60 bbis surfactant wash in OA), then swap to take returns from the IA iii. Pump the remaining 25 bbis of surfactant wash while continuing to take returns from the IA • Swap to pumping 250 bbis 9.8 ppg brine. This does not have to be hot, but can be at WSL discretion. i. Take returns from IA until clean 9.8 ppg brine is at surface, -70 bbls, then swap to OA ii. Take returns from OA until clean 9.8 ppg brine is at surface, - 95 bbls, then swap to OOA iii. Take returns from the OOA until clean 9.8 ppg brine is at surface, - 80 bbis iv. U-tube methanol into the surface as needed for freeze protect. The 9.8 ppg is freeze protected to -5°F. Note: This is a designed break point. It is up to WSL discretion as to continue with the cement or wait for the next shift. 4. Cement IA, OA, and OOA to surface, and leave TOC in tubing at -1,000': Pumping down the tubing, taking returns as noted (start at OOA and work in to IA), pump at max rate or 2,500 psi, per the following pump schedule: • 5 bbls neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 251 bbls Glass G cement per design i. After -108 bbls pumped, cement should be at surface in OOA; continue pumping and taking returns until -10 bbls of clean cement is returned ii. Swap to taking returns from OA iii. Continue pumping cement; after -91 bbis cement should be at surface in OA; continue pumping and taking returns until -10 bbls of clean cement is returned iv. Swap to taking returns from IA v. Pump remaining 32 bbls of cement vi. 1-2 bbls freshwater spacer vii. Drop a wiper ball viii. 13 bbls 9.8 ppg brine; ix. Cement should be at surface in the IA at -5 bbls brine pumped; continue taking returns from IA until 10 bbls of cement are returned x. Freeze protect at surface as needed, leaving TOC at -1,000 A. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead Recording Requirements: Note the recording requirements in RP: Through -Tubing Abandonment, Section 5.9. Volume Calculations -1st Cement Plug ODA volume from 2,030' MD to Surface 9-5/8"&10-3/4" x 13-3/8" 77 bbls OA volume from 2,030' MD to Surface 7" x 9-5/8"&10-3/4" 91 bbls IA volume from 2,0230' MD to Surface 4-1/2" x 7" 37.8 Thickening Time 4-1/2" volume from 2,030' MD to 1,000' MD 0.0152 b 15.6 Bbls Cement Volume with Tbg TOC @ 1,000 30 bbls excess 251 bbls Cement Desi n - 7st Cement Plug; Mixon the FI Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time -1st Cement Plug Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -241 bbls cement + 15 bbis displacement 5 bpm) 2 Safety 3 Minimum required thickening time: 5 Eline 5, Tag TOC at —1,000' 6. Perforate at —845' through 4-1/2" Tbg, Cemented IA, 7" Csg, Cemented OA, 10-3/4" Csg, Cemented OOA, and 13-3/8" Csg into the Arctic Packed OOOA. This creates a circulation path from the tubing into the COCA. Cement in COCA is no higher than 925' because of a RWO that cut and pulled the 13- 3/8" to 918' and burned over the 13-3/8" stub to 925'. • 2.5" Millennium II, 6 SPF, 60° Phasing, 10 -ft perf length; Fire Centered • WSL discretion to use unit depth measure or CCL/GR; CCL/GR not required for tie-in as depth is not critical Special Projects / Fullbore 7. Clean Arctic Pack out of COCA; Surfactant wash OOOA; and Cement OOOA and Tubing from 845' to surface. Pump at maximum rate or 2,500 psi. • Pumping down tubing, taking returns from OOOA: i. 5 bbls meth ii. 75 bbls 160°F heated diesel • Shut down and let diesel soak for 1 hr • Swap to pump 150 bbls 180°F 9.8 ppg brine down the tubing, continuing to take returns from OOOA • Swap to pump 50 bbls hot surfactant was down tubing (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067), continuing to take returns from OOOA • Swap to pump 165 bbls 9.8 ppg brine down tubing, taking returns from OOOA (this does not have to be hot, but can be at WSL discretion). • Continue taking returns until clean 9.8 ppg brine is returned from the COCA • U-tube methanol into the surface as needed for freeze protect. The 9.8 ppg is freeze protected to -5°F. Note: This is a designed break point. It is up to WSL discretion as to continue with the cement m to 5 r wait for the next shift. If it is desired to continue to cementing, adjust the volume of 9.8 ppg bbis (instead of 165) to flush the surfactant wash from the COCA and proceed directly to the cementing operation below. 8. Pumping down the tubing, taking returns from the OOOA, pump at max rate or 2,500 psi, per the following pump schedule: • 5 bbls neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 187 bbls Glass G cement per design i. After —167 bbls pumped, cement should be at surface in COCA; continue pumping and taking returns until —20 bbls of clean cement is returned Note: The excess volume of 20 bbls is to account for the possibility of perforation holes in the surface casing. If mechanical integrity has been verified in previous pumping operations, this can be reduced accordingly at WSL discretion, ensuring that clean cement is returned to surface in the OOOA. ii. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a mo itorable space to check f pr sure%rior to cutting the �S��Tv Recording Requirements: Note the recording requirements in RP: Through -Tubing Abandonment, Section 5.9. 4 Volume Calculations - 2nd Cement Plug F-OOOA volume from 845' MD to Surface (0.1815 bpf) 1 154 i DDIS 4-1/2" volume from 845' MD to Surcae (0.0152 bpf) 13 Bbls I Total Cement Volume to Pump (20 bbls excess) 187 bbls Cement Desi n - 2nd Cement Plu ;Mix on the FI Cement Type !Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Tem erature 800 to 110° F Fluid Loss 40-200cc 20-100 cc/ 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time - 2nd Cement Plug Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -187 bbls cement a 5 bpm) 2 Safety 3 Minimum required thickening time: 5 DHD 9. Bleed tubing and IA pressures and monitor after a minimum of 24 hours. Special Projects .I- 10. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubulars with cement as needed. Install marker cap on outermost casing string (conductor, if present). Provide a minimum of 24 hours notice to AOG_� Inspector of the timing of welding the marker plate onto the casing stub. Photo document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. • Marker Plate to meet requirements in RP: Through -Tubing Abandoment, Section 5.8: i. Minimum %" Thick ii. Minimum 18" Diameter • Bead weld to the marker plate the following information: BP Exploration (Alaska) PTD: 1690970 Well: J -02B API: 50-029-20023-02 Ot / J ot/ / )4A /'K Check Off Date: Engineer: Well Name: oO.A 1lnvi n+inn Aecacemant 1/31/19 Beau Obrigewitch J -02B The region will complete a verification on the individual wells to determine it tney tan witnm u,e ntdteu boundary conditions. If a well falls outside of the boundary due to particular downhole conditions, this will typically be handled by the engineer seeking email approval for a scope change to this deviation from the Zonal Isolation SETA or Area Wells Engineering Authority. In cases where the scope change results in a significant increase in risk as determined by the Zonal Isolation SETA or Area Wells Engineering Authority, the well shall have a specific deviation and eMOC performed. Reservoir Plug x a) No evidence of sustained casing pressure on the OA or OOA from DPZ3 and/or DPZ4. x b) Tag top of cement in tubing to verify placement, and pressure test where possible. Intermediate Plug x a) If DPZ2 is not present; a minimum of 200 ft MD lateral barrier between DPZ3/DPZ4 and DPZ1. b) If DPZ2 is present; a minimum of 200 ft MD lateral barrier between DPZ3/DPZ4 and DPZ2. A minimum N/A of 200 ft MD lateral barrier above DPZ2. x c) Tag top of cement inside tubing, and pressure test. Negative pressure test when DPZ2 is present. Surface Plug a) Control line and/or chemical injection line has injectivity to place cement slurry. NA No Control line in this well. x b) Tubing, IA and OA cemented from surface a minimum of 1300 ft MD to form lateral barrier to DPZ1. c) Where possible place a lateral barrier at least 200 ft MD in length below the end of the control line and above the surface casing shoe. NA No Control line in this well. d) Where possible cement the entire OA from surface to surface casing shoe. This is typically done by x doing an OA down squeeze or punching tubing and circulating up the wellbore. Risk Level Xa) There are no well integrity issues that would increase the risk level determined in the Risk Assessment and standard well abandonment protocol. IFQi= a- tI1+YOaw1 WELLHEAD- CAM3M ACRWTOR = NA 7 - Top 13-3/8" Cement (est) 925' BF. KOP= Mu A%b=_ 91•a 10740 .34V CSC- PATCH 0 = -L O, 040, K 40 8-F0, 0 = 19.124• Top 9-5/8" Cement (est) 2,580' .VB• CSG. an. K-55.10 e 12 415• P5W OV OOLLAR 6492' Tbg TOC Cement 3,328' SLM Top 9-5/8" Cement (est) 6,900' Minunum ID - 2.992" @ 9772' 3-112- SOLD LINER GLM #1/Bottom Cmt 8,946' 4-111- TBG, 1260, 13CRA0, 0152 bof. )=3956' F Ij 5-/12- P1EKOHATIONSAM0.RT W LOC' SV%%I W10 on 11107111 ANGLE AT TOP P9*. 6W 0 10/5(y Werb Rod hon B fu hslwcolF 7 6 law -1 r 6 1087a 2' 6 I=- I 2' 6 1132a -1 r s 1+6nw + 2' 6 11616 1 7 8 11863 - 1 os' rSCASLNRCMTD&SC ON Current Status "mor os; SLIPS DURING MO. - BELL PBIAM® J - 02A WHEN IT WAS DAB®FROM THE PUT RIVER FORM TO THE NISKAK" 4-112" CHROME TRG- OBN2J77 9 -FH -OV PKR SOZ (300 cc1 11710719[ 1400 szl•• Aar v+arn- FM Top DPZ 1/BPRF — 2,001' Base DPZ 1— 6,273' a, .1 IVV LCv 11MI ILrU RA+ l —I-- 11113114 PJC MLLCBP&FISIIOH(1013614) 29 20 11/13/14 9GLV 00 (11,02114) D UK 16 11(13!13 ciskI O SEr C>BBAOF9"(11113113) 3 5563 5177 33 KBG4 SO 6C 20 11112JI 2 7536 6764 33 JI KBG2 OIuN SK 0 IIII02J 11119,0 1 6940 70¢6 33 KBG2 OUV 8K o 1,1119N1 a 4v 4M-HSXNP.0=3.813' 63V H7X I-I%.R 4R- 0— =_--- -. r•F 4• FR ZXPLTP. D M6. LOUT WINDOW (J-02919916-.9928' I Top DPZ 3 — 9,506' Base DPZ 3 — 10,291' �. _"�c�1. j PTD H 11929' ,)L CIBPS RSH 0H H1193 3112' LNi, B2#, L-80 - .0067 W D = 2.992' DATE IREV BY I CR -U �N5 617E REV BY OONOM 016161 NTIAL COMFLEnom TWO -114 Wjko PEIF55QIEEZID(16119+14) 11100169 SDETMCKIJ412A) 11113114 PJC MLLCBP&FISIIOH(1013614) 07101112 WISE IM 11/13/14 9GLV 00 (11,02114) 11117114 MIS SDErRACK(JLM o2J17116 AV A0 ADO®FIW M92VAL(11114114) 11(13!13 ciskI O SEr C>BBAOF9"(11113113) o6122J17 Z7v/JA0 SEFP1(PL(1G 0612/1 17l1(V13 OLW GLV C/U (12J11113) PRJCK E BAY LNI WELL: J-0213 PEMU W: 1690970 AR Nr 50.0294002102 5tf� 9, T11N, KI 3E, 1080' NSL d 1245 VAI BP bpli ario (AImkal 7 ELV= 5733 .EV - Perforete'"845' 94'IRS lW4UI Top 13-3/8" Cement (est) 925' TOC IA/Tbg Cement —1,000' -1 Perforate - 2,030' ( Top 9-5/8" Cement (est) 2,584 T6g TOC Cement 3,328' SLM r Top 9-5/8" Cement (est) 6,900' Minimum D = 2.992" @ 9772' 3-1/Z" SOLID LINER GLM NI/Bottom Cmt 8,946' - 3.95W TTIBAACKLW 26S. L -W D"8.278' SAFETY NOTES: T' SCAB LNR CMTD 6 SET ON EMERGENCY SLPS D MNG RM. -WELL RENAMEDJ- O2A WREN IT WAS DEEPENED FROM THE PUT FOV ER FORM TO THE NISHAK" 4-112- CHROME TBO" OILMV77 9-F4r VV FICR SOZ 1300 sal R GYM7192 (400 sa)" Top DPZ 1/BPRF — 2,001' Base DPZ 1— 61273' 8018 4In- IE8X NIPD•3619' _. _.. ' 1 1,. v e• woe �mC.w ci v T = 4 ill' WLEC, D - 3.058• 9-516' 4 7'BM TF9ViCK LNR PI .E I.D TVD 021 ME VLV ILAlU1 WHI UA It _»I 4 ?000 2976 20 103('.2 e��\\r�.\. \ 16 11"!14 3 5583 5177 33 XBG2 J© � NZ • • .- DPZ 3 • 20 11"!14 2 7536 6781 33 IBG2 7=DWBK 0 11119A4 i 8846 7926 33 IBGY 0 1119!04 8018 4In- IE8X NIPD•3619' _. _.. ' 1 1,. v e• woe �mC.w ci v T = 4 ill' WLEC, D - 3.058• 9-516' 4 7'BM TF9ViCK LNR PI .E FRLDIOE BAY UNF V1BL: 1020 POW No: IMS70 ARM* 50.029-20023-" 1IN M3E 1080' WK81245 OP Eadoratkln (Alaska) 8 MILLOUT :. N. +, • • t • ." e��\\r�.\. \ -•s .. . 1. ♦I IIII�II I\I LvtIIGI I\I J© � NZ • • .- DPZ 3 • 2- FFa:F mLL —cops KjsH OH 11934- CTM ,i: 92' FRLDIOE BAY UNF V1BL: 1020 POW No: IMS70 ARM* 50.029-20023-" 1IN M3E 1080' WK81245 OP Eadoratkln (Alaska) 8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 2 5 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ OperafiA4 DIGCr ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved ProgramV ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 204-184 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stratigraphic ❑ Service ❑ 1 6. API Number. 50-029-20023-02-00 7. Property Designation (Lease Number): ADL 028281 S. Well Name and Number: PBU J -02B 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: Total Depth. measured 12028 feet Plugs measured 3328, 9059 feet We vertical 9019 feet Junk measured 11834 feel Effective Depth: measured 3328 feet Packer measured 9036 feet true vertical 3275 feet Packer true vertical 8003 feet Casing: Length: Size. MD: TVD: Buret: Collapse: Conductor 70 30" 26-96 26-96 Surface 911 20" 26-937 26-937 1530 520 Intermediate 4571 13-3/8" 24-4595 24-4354 5380 / 3450/3090 2670/1950 / 1540 Intermediate 9884 10-3/4" x 9-5/8" 22-9916 22-8779 6450/6870 4020/4760 Tieback Liner 9282 7" 20-9302 20-8232 7240 5410 Liner 811 5-1/2" 9105-9916 8062-8779 7740 6280 Liner 2256 3-1/2" 9772-12028 8651-9019 10160 10540 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4-1/2"12.6# 13Cr80 18-9096 18-8054 Packers and SSSV (type, measured and 4-1/2" Baker Production PKR 9036 8003 true vertical depth) 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: Shut -In Subsequent to operation: Shut -In 14. Attachments kegmred Per 20 MC 25.07025.071, s 252831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-038 Authorized Name: Worthington, Area J Contact Name: Obrigewitch, Beau Authorized Title: Interventions & Integrity Engineer Contact Email: BEAU.OBRIGEWITCH(cbbp.com Authorized Signature: Date: r7 Contact Phone: .1 907 564 4854 Form 10-404 Revised 04/2017 �� I�M1:�•7. lal��g 3BDMS-I*L-/JUN 2 6 2019 Submit Original Only - v, uviwwu. rtu Tree to Dry -Hole. RU CIW lubricator #68-840 with 4" CIV\ 'H' BPV #152. PT to 350/3500psi (PASS). Rundown and set at 125 RD lubricator and remove 4" CIW upper tree. Install FMC 4" HWO PA -03. Torque to API specs. RU CIW lubricator with 4" 'H' pulling tool and PT to 350/5000 (PASS) Rundown and pull BPV #152 at B5" RD lubricator and install tree cap. PT to 500psi (PASS) RDMO -'Job Complete*— SEE LOG FOR DETAILS -"`"u- emp = 51. WHPs (LTSI). No AL ffold, Well house, or Scaing. Dry hole tree installed. Cellar full of snow unable to ve 19 position. rify OOOA vlv Ump = 51. WHPs (WIE Req). No AL, well house, flowline, or scaffolding. Dry hole tree installed. Cellar full of snow unable to verify OOOA valve position. TP, IAPOAP,OOAP, OOOAP unchanged since 2/27/19. /2019 SV, MV = C. IA, OA, OOA = OTG. 16:00 UP SWCP 4518. RAN 3.805" G -RING, 4 1/2" BLB BRUSH TBG DOWN TO PLUG @ 9071�SLM SET 4 1/2" WCS ON PLUG @ 9071' SLM PULLED ST#1 BK-DGLV FROM 8968' SLM (8946' Mrn PULLED WHIDDON CATCHER FROM 9065' SLM...STATE WITNESS TAG BYAOGCC REP ADAM EARL (good) OF THE PX -PLUG W/ CATCHER. PASSING STATE WITNESS CMIT. `**CONTINUE WSR TO 3/m110*** CMIT-TxIA) ' - - ^""' O"CKime: Urc Well, AOGCC Pump the following down the tubing, up the IA, to JX -02's flowline: 2 bbls 60/40 meth followed by 76 bbls Hot Freshwater w/ F103 & U067 363 bbls 9.8 ppg NaCl brine. Sample of 9.6 ppg taken from IA. 5 bbls neat MEOH. U -Tube for 30 min between TBG & IA for freeze protect. Freeze protected Outlet Wells JX -02's Flowline w/ 30 bbls crude and 4 bbls 60/40 meth. AOGCC CMIT-TxIA ***PASSED*** (Adam Earl) to 2110/2129 psi (Max 2200 psi, Target 2 Psi) umpe s nea own o reac es pressure. st 15 min I lost psi. 2nd 15 min T/IA lost 19/18 psi for a total loss of back - 2 bbls. RDMO. 42/41 psi in 30 min. Bleed T/IAP. Bled SL in control of well upon LRS departure. IA/OA/OOA=OTG RIG DOWN SWCP 4518. ***WELL LEFT S/I ON DE wenhouse, scaffold removed. Drilling scaffold installed 3/15/2019 ISVMV=C. IA, OA = OTG i r,-sn - „„ X, 1,/ 14. t emp = hole tree. Temp scaffold installed. 22: or wellhouse. Daily Report of Well Operations J -02B T/I/O/OA/OOA=15/0/28/0/0 Temp=Sl Assist SL (PLUG AND ABANDONMENT) CMIT-TxIA ***PASSED PER STATE AOGCC*** (AOGCC witnessed by Brian Bixby) to 2690/2597 psi , Max Applied Pressure=2750 Target Pressure=2500 psi. Pressure A to 2736/2747 psi with 2.4 bbls Meth. CMIT-TxIA lost 25/83 psi in 1 st 15 minutes and 21/67 psi in 2nd 15 minutes for a total of 46/150 psi during 30 minute test. CMIT-TxIA Last Test ***FAILED BP Standards*" to 2500/2512 psi, Max Applied Pressure=2750 Target Pressure=2500 psi. Pressured T/IA to 2731/2743 psi with 2.6 bbls Meth. CMIT-TxIA lost 27/27 psi in 1st 15 minutes and 26/26 psi in 2nd 15 minutes for a total of 51/51 psi during 30 minute test. Bled TBG/IA to 10/20 psi. 6/19/2019 SL in control of well upon departure. Tags hung on MV/IA CV's OTG FWHP=245/145/30 ***WELL S/I ON ARRIVAL*** (p&a) TAGGED TOC AT 3328' SLM W/ 3.00" S.BAILER (Sample of cement) LRS PERFORMED STATE WIT see Irs log for details TAGGED TOC AT AGAIN AT SAME 3328' SLM DEPTH W/ 3.00" S.BAILER (Sample of cement) LRS PERFORMED STATE WITNESSED CMIT'S (see Irs log for details) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***TAGGING TOC AND CMIT's WERE STATE WITNESSED BY B.BIXBY (see Ins log for 6/19/2019 details)*** VU37.HEAD= CAMERON ACTUATOR= REMOVE) 0103. E -B/ = 57.33' REF BEV = 63.39' BF. E LEV = 41.64' KOP= 2400' Max Angle = 94' @ 10740 Datum MD= 9939' DalumTVO= 8800'SS I w I 113-3/8' CSG PATCH, D = - I- 916' 0- CSG, 94#, 1140 8 -RD, D = 19.124'931' 10-3/4' CSG, 55.5#, N-80, D= 9.76' 2003- S-5/8- CSG PATCH, D = _• 2(153' TAGGED T: (6(19/19) & PST 3328' -$946' RX BOC T X N (06/04119) 7' DV COLLAR 4019' 13-3/8' CSG, 68#, K-55, D = 12.415' 45$9' 3518' D✓ COLLAR IJ C- r. Minimum ID = 2.992" @ 9772' 3-1/2" SOLID LINER J O /' Y SAFETY NOTES: 7' SCAB LNR CMTD & SET ON L EMERGENCY SLIPS DURING RWO.-WELL REIAMEDJ- 02A WEEN IT WAS DEEPENED FROM THE PUT RIVER FORM TO THE TVISHAK- 4-12• CHROME TBG" 061127T7 9-518' DN PKR SOZ (300 sx) & 07107192 (400 sx)- 86T 13-318' FOC 2184' I-I412'HEBXNP,11)=3.813' 3254' ESTTOPOFCEnENT ESTTOPOF GAS LFT ST MD I ND I DEV I TYPE VLV I LATCH FORT I DATE 4 3000 2976 20 KBG2 DOME BK 16 11/02/14 -3 5583 5177 33 KBG2 SO BK 20 11/02/14 '2 7538 6784 33 KBG2 OMY BK 0 11/19/04 '1 8946 7928 33 KBG2 EMPTY - - 03/06/19 2 & 1 = BEHIND CBS ENT 4-1rr mm x Ip_ n= X 4-12- PERFORATION SLAWARY 9093' ANGLEAT TOP FPEiF: 89° @ 10450' AN NY, IU=J.ILY G, 12.6#, 13cR-80, I,D=3.958' INTERVAL OWSgz JI■ SOZ r TOP OF 5-12' LN 9106' 10450 -10480 S 11/10/13 10119/14 'BKR LIP&FGR 0=4.89•#, F L-80, D = 6276' 9296' P97W ' BKR TEBACK LMR FKR SH TOP OF 312'LMR 9772''FRZXPLTP,D-1/r 10978-11098 S 11515/0410/19/14 r 6 HMC FGR D=_' 11/05/04 WINDOW (J-026)9916'-9928' svr vYt6PSTaaR 9916' 11/05/04 PERFORATION SLAWARY REF LOG: SVVS MADon 11/07/04 ANGLEAT TOP FPEiF: 89° @ 10450' Note: Refer to Production DB for WstDrical peri data SIZE SPF INTERVAL OWSgz SHOT SOZ r 6 10450 -10480 S 11/10/13 10119/14 T 6 10678 - 10948 S 11114/04 10/19/14 2' 6 10978-11098 S 11515/0410/19/14 r 6 11328-11428 O 11/05/04 2' 6 11508 - 11608 O 11/05/04 Z' 6 11648 - 11806 O 11105/04 Z' 6 11953 - 11928 O 11/05/04 is ��771T:71 D=2.99r DATE REV BY COWENTS DATE I REV BY I COMMENTS 05/15169 INITIAL COMPLETION 06/22/17 ZV/JMD SETPXPLUG(06/12/17) 11/06169 SIDEMACK(J-02A) 03/07/19 KPYJMD DRY HOLETREE 07516182 W18E RINO 03/19/19 ED(JMD GLV CVO(03/16/19) 11117104 D-16 SIDETRACK(J-02B) 06/06/19 TWJM) SET CMT R.LG N TX A(06/04/19) 11113/14 SVYC,`PJC GLV CJO(11/02/14) 06/10/19 TWJHD ADDED NOTE GLM BEHIND GMT 02/17/16 JVWJkD ADDED PERF PITHZVAL (11/14/04) 0625/19 JNIJ W ADD REF, BF, COW, & TAG CMT 11929' PRYDHOE BAY UW WELL: J -02B PERMIT No: 1690970 AR No: 50-02320023-02 SEIC 9, T11µ R13E 1080' NSL & 1245' VYEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed t Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutd?Wn Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approve&r%�!, Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Secure Reservoir E 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 5. Permit to Drill Number: 204784 3. Address: P.O. Box 196612 Anchorage, Development ® Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 1 8. API Number: 50-029-20023-02-00 7. Property Designation (Lease Number): ADL 028281 8. Well Name and Number: PBU J-028 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: Length: Size: Conductor 70 30" Surface Total Depth: measured 12028 feet Plugs 9 measured 9059 feet true vertical 9019 feet Junk measured 11934 teat Effective Depth: measured 9059 feet Packer Measured depth: 11328 - 11928 feet True vertical depth: 9010-9014 feet measured 9036 feet true vertical 8023 feet Packer true vertical 8003 feet Casing: Length: Size: Conductor 70 30" Surface 911 20^ Intermediate 4571 13-3/8" Intermediate 9884 10-314" x 9-5/8" Tieback Liner 9282 7" Liner 811 5-1/2" Liner 2256 3-1/2" Perforation Depth: Measured depth: 11328 - 11928 feet True vertical depth: 9010-9014 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): MD: 26-96 26-937 24-4595 22-9916 20-9302 9105-9916 9772-12028 4-1/2"12.6# 13Cr80 4-1/2" Baker Production PKR Treatment descriptions including volumes used and final pressure: KI 26-96 26-937 24-4354 22-8779 20-8232 8062-8779 8651-9019 18 - 9098 9036 Burst: 1530 5380/3450/3090 6450/6870 7240 7740 10160 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: Shut -In 14.Attachments: (Mgmred Per 20 MG 25X015 071 25.283) 15, Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development a Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil [a Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-038 Collapse: 520 2670 11950 / 1540 4020/4760 5410 6280 10540 18-8054 8003 Authorized Name: Lastufka, Joseph N Contact Name: Obri9ewitch, Beau Authorized Title: CNIMSpet st A Contact Email: BEAU.OBRIGEWITCHWbp.com Authorized Signature: \ L� Daate: 3 ,/j1 Contact Phone+1 907 564 4854 Form 10404 Revised 04/2017 'gN RMA�/ 2 0 2019 Submit Original Only Daily Report of Well Operations J -02B ACTI V ITYr)ATF 01 u e• e A ov T/1/0/00/000 = 0/400/0/0/0. RD Tree to Dry -Hole. RU CIW lubricator #68-840 with 4" CIW 'H' BPV #152. PT to 350/3500psi (PASS). Run down and set at 125". RD lubricator and remove 4" CIW upper tree. Install FMC 4" HWO PA -03. Torque to API specs. RU CIW lubricator with 4"'H' pulling tool and PT to 350/5000 (PASS) Rundown and pull BPV #152 at 85" RD lubricator and install tree cap. PT to 500psi (PASS) RDMO ***Job Complete*** SEE 2/22/2019 LOG FOR DETAILS T/1/0/00/000 = 20/400/10/10/10. Temp = SI. WHPs (LTSI). No AL, Well house, Flowline, or Scaffolding. Dry hole tree installed. Cellar full of snow unable to verify OOOA vlv 2/27/2019 position. T/1/0/00/000 = 20/400/10/10/10. Temp = SI. WHPs (WIE Req). No AL, well house, flowline, or scaffolding. Dry hole tree installed. Cellar full of snow unable to verify OOOA valve position. TP, IAP,OAP,OOAP, OOOAP unchanged since 2/27/19. 3/1/2019 SV, MV = C. IA, OA, ODA = OTG. 16:00 ***WELL S/I ON ARRIVAL SWCP 4518***(plug & abandommnt) RIG UP SWCP 4518. 3/5/2019 ***CONTINUE WSR TO 3/6/19*** T/I/O/00/000=0/450/0/0/0 Temp=S/I (LRS Unit 42 - Assist Slickline: Circ Well, AOGCC CMIT-TxIA) Pump the following down the tubing, up the IA, to JX -02's flowline: 2 bbls 60/40 meth followed by 76 bbls Hot Freshwater w/ F103 & U067 363 bbls 9.8 ppg NaCl brine. Sample of 9.6 ppg taken from IA. 5 bbls neat MEOH. U -Tube for 30 min between TBG & IA for freeze protect. Freeze protected Outlet Wells JX -02's Flowline w/ 30 bbls crude and 4 bbls 60/40 meth. OGCC CMIT-TxIA ***PASSED*** Adam Earl),to 2110/2129 psi (Max 2200 psi, Target 2000 psi) Pumped 2.04 bbls neat MEOH down IA to reach test pressure. 1st 15 min T/IA lost 23/23 psi. 2nd 15 min T/IA lost 19/18 psi for a total loss of 42/41 psi in 30 min. Bleed T/IAP. Bled back - 2 bbls. RDMO. SL in control of well upon LRS departure. IA/OA/OOA=OTG 3/6/2019 FWHP=76/70/24 ***CONTINUE WSR FORM 3/05/19 SWCP 4518***(plug & abandonment) RAN 3.805" G -RING, 4 1/2" BLB BRUSH TBG DOWN TO PLUG @ 9071' SLM SET 4 1/2" WCS ON PLUG @ 9071' SLM PULLED ST#1 BK-DGLV FROM 8968' SLM (8946' MD) LRS CIRC OUT WELL. PULLED WHIDDON CATCHER FROM 9065' SLM...STATE WITNESS TAG BYAOGCC REP ADAM EARL (good) OF THE PX -PLUG W/ CATCHER. PASSING STATE WITNESS CMIT. 3/6/2019 ***CONTINUE WSR TO 3/07/19*** ***CONTINUE WSR FROM 3/06/19 SWCP 4518***(plug and abandonment) RIG DOWN SWCP 4518. 3/7/2019 ***WELL LEFT S/I ON DEPATURE*** TRff= DRY HOLE WELLHEAD GO MMN AT0R= REMDVED. ELEV = 57.33'E" = E 20.0'0= SHOT 2400'Angle = 94'tD 10740 Datum MD= 9939' Dawn TVD = 8800' SS USG PATCH, D = " V. N-40 8 -RD, D = 19.124" 3G, 55.5#, N80, D = 9.76" CBG PATCH. D= 1 401W I 13-3/8' CSG, 68#, K-55, ID= 12.415• Minimum ID = 2.992" @ 9772' 3-1/2" SOLID LINER 4-12' TBG, 12.80, 13CR-80, .0152 bpf. D = 3.958" 1 7" TEBACK LNR, 269, L-80, D = 6.276. 1 1 9772' 1 9-51W CSG, 47#, N-80, D = 8.681• J -02B FISH- MILL CEP& 113-318• FOC I 2184' F-14-12' FES X NP, ID = 3. 3254' EST TOP OF Ct3VIB1T 5955' EST TOP OF C9u1BdT GAS I FT MAMIRR S ST PERFORATION SUMMARY REF LOG: SWRS MWD on 11/07/04 ANGLEATTOPPEZF: 89° Q 1045U Note: Refer to Production DB for historical perf data 1 DEV SQE SPF INTERVAL OpmSgz SHOT SQZ 20 KBG2 2" 6 10450-10480 S 11/10/1310/19/14 33 KBG2 SO BK 20 2" 6 10678- 10948 S 11114/04 10/19/14 DMY BK 0 11119/04 2' 6 10978 -11098 S 11/05/04 10/19/14 11/19104 2" 6 11328-11428 O 11105/04 2• 6 11508-11608 O 11/05/04 2" 6 11648-11808 0 11/05104 2" 6 11853-11928 O 11/05/04 J -02B FISH- MILL CEP& 113-318• FOC I 2184' F-14-12' FES X NP, ID = 3. 3254' EST TOP OF Ct3VIB1T 5955' EST TOP OF C9u1BdT GAS I FT MAMIRR S ST MD TVD DEV TYPE I VLV LATCH PORT DATE 4 3000 2976 20 KBG2 DOW BK 16 lIlUB14 3 55M 5177 33 KBG2 SO BK 20 11102/14 2 7538 6784 33 115G2 DMY BK 0 11119/04 1 8946 7928 33 KBG2 Dk4Y BK 0 11/19104 1 903V 1 HES X NP, ID = 3.813" 1/2' BKR R(R 13= 1 tl1Ub" 1-1/-Xe-UKRT�ACK SLV,D=5.50' 9083' 4-12" WLEG, D=3.958" 9111' 7•X5-12"BKR LTP&FIGR, D=4.89• { 9298' H 9-5/8' x 7" BKR TESACIC LNR PKR SFN 9787' 5-12"X4"HR ZXP LTP, D=_ 9799' 5-12' X3-12• HMC HGR, D _• MILLOUT WINDOW (J-02819916' - 9928' LMS 9.2#, L-80 W, D = 2.992' 10173' MARKER JOM DATE REV BY I CDN%13f M DATE REV BY COMVENTS 05/15/69 INITIAL COMPLEnON 1028/14 TWJIVU PEWS SQUEEZED (10/19114) 11/061/1 07106/02 N -19E 91DERACK(J-02A) IVO 11/13/14 PJC IVLLCBP&PJSHOH(10/30/14) 11/13/14 MORK GLV CIO (11102114) 11/77/04 616 SIDEI'RACK(J-02B) 02117/16 JW/JMD ADD® PERFNTE2VAL(11N4/04) 11/13/13 CJS/JMD SETCIBRADPEiFS(1V13/13) 06/22/17 ZV/JMD SETPK R -x16(06/12117) 1220/13 DLWJ GLV OO(12/11113) 03/07/19 KP`AU DRY HOLETRff 9Q^r "1.l PRIDFOE BAY UMT WELL: J -02B PE Mrr Na: 91690970 AR No: 5D-029-2002302 11 N, R13F 1080' PBL & 1245' VA L BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J -02B Permit to Drill Number: 204-184 Sundry Number: 319-038 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov 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, fil T. Se ount, Jr. Commissioner DATED this 7 day of March, 2019. V113pN1544'� to A 110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 9 '019 1. Type of Request: Abandon ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other' L,,CW y"% 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 1+7 5. Permit to Drill Number: 204-184 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ❑ 8. API Number: 50-029-20023-02-00 r 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU J -02B 9. Property Designaltion (Lease Number): 1 10. Field/Pools: ADL 0028281 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD. Effeclive Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12028 9019 9059 8023 9059 11934 Casing Length Size MD TVD Buret Collapse Conductor 70 30" 26-96 26-96 Surface 911 20" 26-937 26-937 1530 520 Intermediate 4571 13-3/8" 24-4595 24-4354 5380 13450 / 3090 2670 11950 / 1540 Intermediate 9894 10-3/4" x 9-5/8" 22-9916 22-8779 6450 / 6870 4020/4760 Tieback Liner 9282 7" 20-9302 20-8232 7240 5410 Liner See Attached Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 11328- 9010 - 9014 4-1/2" 12.6# 13Cr80 18-9096 Packers and SSSV Type: 4-1/2' Baker Production PKR Packers and SSSV MD (ft) and TVD (ft): 9036/8002 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development RI Service ❑ 14. Estimated Date for Commencing Operations: February 15, 2019 • 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigawitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCHgbp.com Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity Engineer Authorized Signature: Date: Z O 1 COMMISSION U1 E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: LJ• Plug Integrity ❑ BOP Test ❑ MechanicalIntegrityTest 11VLocation Clearance L/J� IL/II — / Other: r6 4. �-- - I1 L - /n Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 131" Subsequent Form Required: 16-1.7 APPROVED BYTHE %/ 7// '///' Approved by: L''�/ COMMISSIONER COMMISSION Date: 3� 9 Cl ' ,k°\ ORIGINAL RBDMSA MAR 0 81019 5 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. � 3 chments in Duplicate X" Casing / Tubing Attachment J -02B Casin Length Size MD ND Burst Colla se Liner 811 5-1/2" 9105 - 9916 8062 - 8779 7740 1 6280 Liner 2256 3-1/2" 9772 - 12028 6651 - 9019 10160 1 10540 J-02 Full Plug and Abandon Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Julie Wellman (907) 564-4657 Expected start date: February 15', 2019 History with a Gen 1 Permafrost Wellhead in 1969. The suhea movemen , as emonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Job Steps 1 S a. b. c. Pull DGLV from STA # 1 Tag existing plug and CMIT-TxIA; Requires AOGCC Witness Notification Punch Tubing 2 F Assist Slickline: a. Surfactant Wash IA and Tbg b. Circ well to 9.8 ppg b . e ZztO© c. CMIT-TxIA to si; Requires AOGCC Witness Notification I`t 3 V Drop annulus gate valves and install integrals psi O c- –ems -6— In PeFfer te d OOA 00' 0 -9— d a. b. are out AFetie Peek: SuFfeetent Wash G OA eeme. it eeeA and Tubing to Sanace –W– Fxsayate, Notoficabon Plate,-- eut off Wellhead, and Install Maike, Requires AOGCC Witness 3� Procedural steps Slickline / Fullbore 1. Pull DGLV from Sta #1 2. Surfactant Wash IA and Tubing; Circ to 9.8 ppg Brine; Pump at max rate down Tubing and up IA per the following pump schedule: • 75 bbls hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • 320 bbls 9.8 ppg brine. 9.8 ppg brine is freeze protected to -5°F. U-tube some methanol to prevent ice plugs at surface. Note: The calculated volume is 305 bbls. Pump additional as needed to confirm a good sweep. Verification of a good sweep is accomplished by one of the following two methods, at WSL discretion: • Rig up to take returns through a micro -motion to check density • Lead with an appropriately -sized pill (-10-20 bbls) of dyed brine 3. Tag existing PXN PI at 9,059' MD 4. CMIT-TxIA to 1,,50'6 psi Z zDa Note: Bothhe tag and the CMIT-TxIA req ire minimum 24 -hr AOGCC witness notification +10-1 Cese_�'b m yG� sere..:- / Hold Point: If CMIT-TxIA fails, con act Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c). If CMIT-TxIA Passes: Punch 4-1/2" tubing just above packer, at — 9,025' MD, tag plug at 9,059' for depth control. Use 5' tubing 1pnch as recion1mended by tu,/ bing punch supplier and verified by WSL. '- CL S S cNe ©©cl/ G I rG ✓ lc.A�rC,-�..rt<- Fb A 7-,),6 �. Volume Calculatiofis — 9.8 Circ and 1st Cement Plug f / 7" x 4-1/2" volume from 9,025' MD to Surface 0.0186 b 168 bbls 4-1/2" volume from 9,025' MD to 2,200' MD 0.0152 b 104 ✓ bbls 4-1/2" volume from 2,200' MD to Surface 0.0152 b 33 ✓ Bbls Total Cased Hole Capacity See details for excess to um 305 bbls Cement Volume with Tbg TOC @ 2,200 See details for excess 272 bbls Valve Shop 6. Drop all annulus gate valves and install integral valves. Fullbore / Special Projects 7. Circulate cement down the tubing, taking returns from the IA, cementing the IA from 9,025' to Surface and leaving TOC in the Tubing at 2,200', at max rate or 2,500 psi per the following pump schedule. Include a ball launcher in the rigup to chase the cement. • 5 bbls neat Meth or 60/40, at WSL discretion 91 4 5 bbl FW spacer 282 bbls Class G cement per design ✓ • Drop a wiper ball • 1-2 bbls freshwater spacer • 30 bbls 9.8 ppg brine • Freeze protect at surface as needed, leaving TOC at —2,200' Cement returns should be at surface @ —305 total bbls pumped. Continue pumping cement until full planned volume of 315 bbls (should return 10 bbls clean cement). The IA will be cemented to surface and TOC in the tubing should be at 2,200'. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead off. Recording Requirements: Note the recording requirements in SOP: Through -Tubing Abandonment, Section 5.9. Note, this document may become an RP by the time this job is executed. Cement Design -1st Cement Plug; Mix on the Fly Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Tem erature 800 to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -380 bbls @ 5 bpm) 2 Safety 3 Minimum required thickening time: 5 DHD 10. MIT -T to 2,500 psi • This is testing the intermediate plug TOC at 2,200'. It can be swapped to Fullbore at WSL discretion or due to equipment availability and scheduling accomodations. Eline 11. Tag TOC at -2,200' QG cc i o 4' - 12. Perforate at -2,030' through 4-1/2" Tbg, Cemented IA, 7" Csg, Arctic Packed OA, and 9-5/8" Csg, into the Arctic Packed OOA. This creates a circulation path from the tubing into the OA and the OOA. • Haliburton 2" Millennium, 6 SPF, 60° Phasing, 10 -ft pert length; Fire Eccentered • WSL discretion to use unit depth measure or CCUGR; CCL/GR not required for tie-in as depth is not critical Special Projects / Fullbore Note: Rig up in such a way that returns can be taken from the OA and the OOA independent from each other. The intent of this step is to prepare these annuli for cement, and then cement them to surface, circulating down the tubing. Include a ball launcher in the rigup to chase the final cement. 13. Clean Arctic Pack out of OA and OOA; Surfactant wash OA and OOA; Cement OA and OOA to surface, and leave TOC in tubing at -1,000'. Pump at maximum rate or 2,500 psi. • Pumping down tubing, taking returns from OOA: i. 5 bbls meth ii. 175 bbls 160°F heated diesel • After 115 bbls pumped, swap to taking returns from OA (this will put -80 bbls in the OOA) i. Continue pumping, swapping to 180°F heated 9.8 ppg brine ii. Pump 31 bbls of brine, continuing to take returns from the OA (this will put -95 bbls of diesel in the OA. iii. Freeze protect surface equipment as needed • Shut down and let diesel soak for 1 hr • Resume pumping 180°F 9.8 ppg brine down the tubing i. Take 100 bbls of hot brine returns from the OOA, then swap to take returns from OA ii. Take 70 bbls of hot brine returns from the OA • Swap to pump 150 bbis hot surfactant wash down tubing (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) i. Take 105 bbls of returns from OA (putting -75 bbls of surfactant wash in OA), then swap to take returns from the OOA ii. Pump the remaining 45 bbls of surfactant wash while continuing to take returns from the OOA Swap to pumping 200 bbls 9.8 ppg brine. This does not have to be hot, but can be at WSL discretion. i. Take returns from OOA until clean 9.8 ppg brine is at surface, -108 bbls, then swap to OA ii. Take returns from OA until clean 9.8 ppg brine is at surface, - 91 bbls iii. U-tube methanol into the surface as needed for freeze protect. The 9.8 ppg is freeze protected to -5°F. Note: This is a designed break point. It is up to WSL discretion as to continue with the cement or wait for the next shift. 14. Pumping down the tubing, taking returns from the OCA, pump at max rate or 2,500 psi, per the following pump schedule: • 5 bbls neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 204 bbls Glass G cement per design i. After -108 bbls pumped, cement should be at surface in OOA; continue pumping and taking returns until -10 bbls of clean cement is returned ii. Swap to taking returns from OA iii. Pump remaining 86 bbls of cement iv. Drop a wiper ball v. 1-2 bbls freshwater spacer vi. 13 bbls 9.8 ppg brine; vii. Cement should be at surface in the OA at -2 bbls brine pumped; continue taking returns from OA until 10 bbls of cement are returned viii. Freeze protect at surface as needed, leaving TOC at -1,000 ix. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead Recording Requirements: Note the recording requirements in SOP: Through -Tubing Abandonment, Section 5.9. Note, this document may become an RP by the time this job is executed. Volume Calculations - 2nd Cement Plug OOA volume from 2,030' MD to Surface 9-5/8"&10-3/4" x 13-3/8" 77 bbls OA volume from 2,030' MD to Surface 7" x 9-5/8"&10-3/4" 91 bbls 4-1/2" volume from 2,030' MD to 1,000' MD 0.0152 b 15.6 Bbls Cement Volume with Tbg TOC @ 1,000 20 bbls excess 204 bbls Cement Desiqn - 2nd Cement Plua; Mix on the Flv Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -204 bbls cement + 15 bbls displacement @ 5 b m 2 Safety 3 Minimum required thickening time: 5 Eline 15. Tag TOC at -1,000' 16. Perforate at -845' through 4-1/2" Tbg, Cemented IA, 7" Csg, Cemented OA, 10-3/4" Csg, Cemented OOA, and 13-3/8" Csg into the Arctic Packed OOOA. This creates a circulation path from the tubing into the OOOA. • 2.5" Millennium II, 6 SPF, 60° Phasing, 10 -ft perf length; Fire Centered • WSL discretion to use unit depth measure or CCL/GR; CCUGR not required for tie-in as depth is not critical Special Projects / Fullbore 17. Clean Arctic Pack out of OOOA; Surfactant wash OOOA, and Cement OOOA and Tubing from 845' to surface. Pump at maximum rate or 2,500 psi. • Pumping down tubing, taking returns from COCA: i. 5 bbls meth ii. 165 bbls 160°F heated diesel • Shut down and let diesel soak for 1 hr • Swap to pump 150 bbls 180°F 9.8 ppg brine down the tubing, continuing to take returns from COCA • Swap to pump 75 bbls hot surfactant was down tubing (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067), continuing to take returns from OOOA • Swap to pump 165 bbls 9.8 ppg brine down tubing, taking returns from OOOA (this does not have to be hot, but can be at WSL discretion). • Continue taking returns until clean 9.8 ppg brine is returned from the OOOA • U-tube methanol into the surface as needed for freeze protect. The 9.8 ppg is freeze protected to -5°F. Note: This is a designed break point. It is up to WSL discretion as to continue with the cement or wait for the next shift. If it is desired to continue to cementing, adjust the volume of 9.8 ppg brine to 50 bbls (instead of 165) to flush the surfactant wash from the OOOA and proceed directly to the cementing operation below. 18. Pumping down the tubing, taking returns from the COCA, pump at max rate or 2,500 psi, per the following pump schedule: • 5 bbls neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 177 bbls Glass G cement per design i. After -167 bbls pumped, cement should be at surface in OOA; continue pumping and taking returns until -10 bbls of clean cement is returned ii. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the Recording Requirements: Note the recording requirements in SOP: Through -Tubing Abandonment, Section 5.9. Note, this document may become an RP by the time this job is executed. 5 Volume Calculations - 3rd Cement Plug OOOA volume from 845' MD to Surface (0.1815 bpf) 154 bbls 4-1/2" volume from 845' MD to Surcae (0.0152 bpf) 13 Bbls Total Cement Volume to Pump (10 bbls excess) 177 bbls Cement Design - 3rd Cement Plug; Mix on the Fly Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -167 bbls cement @ 5 bpm) 2 Safety 3 Minimum required thickening time: 5 DHD 19. Bleed tubing and IA pressures and monitor after a minimum of 24 hours. Special Projects 20. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubulars with cement as needed. Install marker cap on outermost casing string. Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of the cut. Photo document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. Marker Plate to meet requirements in SOP: Through -Tubing Abandoment, Section 5.8: i. Minimum %" Thick ii. Minimum 18" Diameter Bead weld to the marker plate the following information: BP Exploration Alaska, Inc. PTD: 169-097 Well: PBU J -02B API: 50-029-20023-02 yv:16 C:�=31. MELEE D= CAMPON ACnLATCR=— m CKB. E EV =_ 9F. B.LV == _ _ 57.33' MOO KCP= Mw Angle = LTI pm ._--_ 2400' 94' 0 10740 9939' mhmTVD. 8800' SS 2B Current Status SAFETY NOTES: 7" SCAB LNRCMM& SET ON BIOWE4CY SLIPS DURING %W. "WELL RENAMED J - 92A MEN IT WAS DEEPENED FROM THE PUT MYER F010L1 TO n4E IV 1811AK" 4-1 /2' CHROMETBO" 08MV7 9-619" DV PKR SQZ (300 sxl S 47107192 1400 sx1" 13-319• GSC"PATC.H D 918' 0' CSC, 9", 1-40 8-W, D = 79.12a• —g3' 19104-csc.esss. NttO.o-e>e' 9 -SW CSG PATCH. -ID —� rr ov CL7LlAR i-{ 4019' 13-3ai' CSO, 889. K-55, D= 12.ais- 9.51rW COLLAR - Minimum ID • 2.997'@ 9772' 3.1f1" SOLID LINER 0152 W, D =3.956' IrTIEBACK Udt."<89.L-61.0=5.276'1-1 9296' I Top DPZ 1/BPRF — 2,001' Base DPZ 1— 6,273' IJII N IIYVILCVI IIILI Il. ILIY 041.111111 II.IC I ioaa' Hrx4=1a'"Rc D= 44IT F D= 5.50' I ';��. DO .•. .. 95115169 MTIALCOMPLETION 101281M TIMM PERFS SOUEEKED(10119114) I 16 1142!14 3 5563 5177 33 KBM 50 BK 20 11102!14 2 7536 67& 33 KBM M& BK 0 11119104 7 8DW 7928 33 KDO2 aft DK 0 11119/04 ioaa' Hrx4=1a'"Rc D= 44IT F D= 5.50' (SATE RLV BY I ';��. DO .•. .. 95115169 MTIALCOMPLETION 101281M TIMM PERFS SOUEEKED(10119114) I :-.. •.. . .�iA.r�ipm, sz, h. Tip �� a�A� �� 8110 11113174 9APOPLIC GLV (`JO(1 f/02114) ANGLE AT TOP Pg* SWEMCK(J428) Noic Peter to . .: ,' hislommi perf dote1111%�%%�%A%.v 11,13103 CJSUM SEFCBRADIWS(11/131131 DUM17 ZV/AMID SET Px FLUE(06117l171 1210/13 "JLC GLV M (12111113) 10678 10S48S1 , ��C� ai iirli ., ., :. 1097S-11098 s11328 1. 1, - 11428 0J r.. 1 ••'i, h -11128 0 x: I1: .� 1 •,:1 J. (SATE RLV BY 00MMMIS 041E REV SY COM ENM 95115169 MTIALCOMPLETION 101281M TIMM PERFS SOUEEKED(10119114) 11x18189 SWE7RACK(J412A) MUM PJC MLCBP&RJSH(H(1d3)II4) 97x1982 N-1SE 8110 11113174 9APOPLIC GLV (`JO(1 f/02114) -I—A744 DIS SWEMCK(J428) 171% JWJW AOO®FERFMEWAL(11/14104! 11,13103 CJSUM SEFCBRADIWS(11/131131 DUM17 ZV/AMID SET Px FLUE(06117l171 1210/13 "JLC GLV M (12111113) PRJO10ESAY LM INELL: J -02B PEFOX No: 9 0970 AA Ila50.0247002102 11IL RUE. 1080 N5L 81245 WR SP Exploration (Abs gal 7 4" CA --- AD= CASBtON J-028 Proposed P&A SA�RO�: r-SCABLRR CMTD&SET ON MEME ICY SLIPS VMKG FM. -VKLLPHIAMEDJ- 02A Wn811r WAS DOPBM FROM THE PUT RI'M Top 13-3/8" Cement (est) 925' FORM TO TWF NISHAK-4-12- CHROMETBG- WI 077 9-610.OV P%R SOZ 1300 sx) & 07MV92 1400 sx1" µl x Arig 94 Perforate'" 845' Top 9-5/8" Cement (est) 2,580' O W4'CS .SM N D -Q7 -+ b' Perforate'" 2,030' 2067 RAY• H11-4llC tilt I Top DPZ 1/BPRF – 210011 TOG 2n4 Stage Gement "'1,o00'~ . Base DPZ 1 — 6,273' TOC 1n Stage Cement "'2,200' I Top 9-5/8" Cement (est) 6,900' Minimum ID . 2.992" @ 9772' 3-112" SOLD LINER Tubing Punch'" 9,025' 4-12• TSG 12.80, 13CR80, .0152 bpf, D = 3958' TO' OF 5- 112• LNR —C 7'T®ACK LW 264. L -80,D=6.276' -C TCP OF 3-1/2• Di 977; TOPOF!51W-W1i187OCK 9914 �sre'csG.vi, 480,10=B.eer 1841 F93ORATION SIAO.MRY Ft+ LUU. SWS MA17on 11101104 AMIE AT TCPF 9*: 8W Q 10450 = 3.813' i 9030 'rjr x 4-12. M44 ROR, D -- WWW -[4-IIT -)4-112• FLS x NP, D = 813- 1 9w 41? P,( PLUG (66117/17) - tlfl —R5AR tr. D = 3.725' �.S�ii�7liil:I:[r:F+SSI �737t�i x 1 9799' MILLOUT WINDOW (J -02M 9916' 9928' I Top DPZ 3 – 9,506' SME DATE 3000 6 ZO NBG2 DOPE I 16 11707!14 11/1O3 5563 5717 33 x6G2 SO OK 20 11=14 143 2 1536 6754 33 K= CW BK 0 11/19104 Y 6846 7928 33 Im02 GM BK 0 1/11904 = 3.813' i 9030 'rjr x 4-12. M44 ROR, D -- WWW -[4-IIT -)4-112• FLS x NP, D = 813- 1 9w 41? P,( PLUG (66117/17) - tlfl —R5AR tr. D = 3.725' �.S�ii�7liil:I:[r:F+SSI �737t�i x 1 9799' MILLOUT WINDOW (J -02M 9916' 9928' I Top DPZ 3 – 9,506' SME DATE "LIHI °AL LW"�' SI INITIAL COMPLETION Base DPZ 3 –10,291' I 6 114W-1(480 5 11/1O3 IU19114 IVIN14 %%'0P GLV nn(ttm9114) 11117M4 B-16 SIDEIRACKIJ411A 0211706 AVJ.O ADO®FEf NUERVAL(11114104) 'V13113 CJSIJMJ SETCEPADFSWS(11113113) 05122117 ZVIJMD SETPAPLLG(0611217) 7 6 10878-10148 S 11114,04 10'19114 PB1D 11928' ROM 2' 6 10978-11098 S 1IM5113410`/9114 7 6 113W-11428 O 11105104 RSH - IJLL CSP K POSH DH 11930 CTM ?' 6 116mr 116]6 n 11106x10 j1013U/14) 7 6 11648 - 11806 O 111061W ---- Y 8 11853 - 11128 0 1IMM4 3 112- LA62, 0.20, L-80 12028' .0087 bpf, D= 2992- 997 DATE RBJ BY OOMENTS DATE REV BY ; COMANIS 16116/89 INITIAL COMPLETION 1928114 TMJW PBSS SIDLEEZED(1011914) 11105189 SIOETRACKIJ-OTA) 1V13114 PJC LLL CBP& RSHCH(1930114) 07108182 K18E IMO IVIN14 %%'0P GLV nn(ttm9114) 11117M4 B-16 SIDEIRACKIJ411A 0211706 AVJ.O ADO®FEf NUERVAL(11114104) 'V13113 CJSIJMJ SETCEPADFSWS(11113113) 05122117 ZVIJMD SETPAPLLG(0611217) '212V13 DLHJLID GLV C11O 021'1113) P'F&CHUEBAY UMT VYELL J-028 PEF4U b:9690970 An )k.� 50-071'AfY2]-02 11K R13E 1DW NSL & 1245' WB SP BVbration (Abskal 8 �ym11 _ Alaska Oil & Gas Conservation Commission Subject�I Page No, 01 File J - Z PTS 1� -a� 16 7 C/9 llz 7 z �s v' � 8 ' .•� �Z,y�S/ �• / 0375 2 L o7V9��_ ioz9• y Pe�� Zo3o 7 ySa� —q3S: �7ty 3�S�r zGiP raSbl. 7ZS�! 7 o/SL Lam' /6Zj • d I I Tk,xo�+u P.tn+v�'�a K3.S 261 3' 16 �y 109x6 9, 7-- ?-:Pr c9-% - a,, �3- j 2. — pv Collar Tc c t T 6Q00'vwb c%e- 2 L sr 9634 Pic k• r - y/z-r��,•,,� 5'6`73 3.��', (I 7' �— a 4z9G-3319 ° ___ d I I Tk,xo�+u P.tn+v�'�a K3.S 261 3' 16 �y 109x6 9, 7-- ?-:Pr c9-% - a,, �3- j 2. — pv Collar Tc c t T 6Q00'vwb c%e- 2 L sr 9634 Pic k• r - y/z-r��,•,,� 5'6`73 3.��', (I 7' MEMORANDUM TO: Jim Regg� �-zS1 �9 P.I. Supervisor l 1 FROM: Adam Earl Petroleum Inspector Section: 9 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Jeremy Grimes Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" - O.D. Shoe@ Intermediate: 10 3/4" x 9 5/8" O.D. Shoe@ Production: 7' O.D. Shoe@ Liner: 5 1/2" x 3 1/2" O.D. Shoe@ Tubing: 41/2" -O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 6, 2019 SUBJECT: Well Bore Plug & Abandonment PBU J -02B BPXA PTD 2041840; Sundry 319-038 11N Range: 13E Meridian: Umiat NA Total Depth: 12028 ft MD Lease No.: ADL 028281 Suspend: P&A: X 96 Feet 937 Feet 4595 Feet 9916 Feet 9302 Feet 12028 Feet 9096 Feet Type Plug Casing Removal: Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Tbg Cut@ na Feet Type Plug Founded on De th Btm De th To MW Above Verified Tubing 9052 ft MD' 9.6 brine Wireline tag 2170 1 2147 1 2129 P OA 25 25 1 25 1 Initial 15 min m min d5 min Romdf Tubing 2186 1 2152 1 2129 2110 IA 2204. 2170 1 2147 1 2129 P OA 25 25 1 25 1 25 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I traveled out to PBU J -02B for verification of the reservior plug by slickline tag and a combo tubing -IA pressure test. Jeremy Grimes was the BP rep on location. I witnessed the slickline depth veification tag which showed the plug was indeed set in the tubing nipple @ 9059 ft MD. Little Red conducted the pressure test combo Tubing and IA. No Sundry was produced but I did have an email showing AOGCC approval for the work. Attachments: none rev. 11-28-18 2019-0306_Plug_Verification_PBU_J-02B_ae · . Image Project Well History File Cover 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. cQQ 4: - J ß Y- Well History File Identifier Organizing (done) o Two-sided 11111111111111 1111I o Rescan Needed III 11111111" 111111 RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. ;l. o Other, NofType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: Id-/Iglo~ f I 151 vy\p BY: ~ Date: 1:J-!ltJ/00 ~ + 1111111111111111111 151 .~ 1? = TOTAL PAGES ~ <6 (Count does not include cover sheet)·· 1\110 151 ( V \I Project Proofing Scanning Preparation BY: 111111111111111111I Production Scanning Stage 1 Page Count from Scanned File: b q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES BY: ~ Date: I ~II tó/ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 mp NO BY: Maria Date: 151 III 111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned /111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11111111I111 1111111 10/6/2005 Well History File Cover Page. doc • STATE OF ALASKA RECEIVED AL A OIL AND GAS CONSERVATION COMM!. )N REPORT OF SUNDRY WELL OPERATIONS DEC 12 2013 1.Operations Abandon U Repair Well U Plug Perforations U - Perforate U• Other PC) CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 204-184-0 3.Address: P.O.Box 196612 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20023-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281 • PBU J-02B • 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 12028 feet Plugs measured 11270 feet true vertical 9019.46 feet Junk measured None feet Effective Depth measured 11270 feet Packer measured See Attachment feet true vertical 9010.71 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 911 20"94#H-40 26-937 26-936.98 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9278 7"26#L-80 18-9296 18-8227.15 7240 5410 Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10450-10480 feet 10678-10948 feet 10978-11098 feet 11328-11428 feet 11508-11608 feet 11648-11808 feet 11853-11928 feet True Vertical depth 9016.78-9017.07 feet 9016.04-9011.82 feet 9.012.06-9011.69 feet 9009.67-9006.76 feet 9004.96-9003.86 feet 9003.51-9007.69 feet 9009.76-9013.73 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-9119 23-8073.68 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 20 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 649 30850 236 0 2068 Subsequent to operation: 618 24742 288 0 2163 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ei • Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCO 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 Garry Catron Email Garry.Catrort(U7BP.Com Printed Name Garry Catron Title PDC PE Signature .1/64A1- C Phone 564-4424 Date 12/12/2013 U Vi--/- W'CIr v=•:- DEC 16 / / // // i. Form 10-404 Revised 10/2012 </ Submit Original Only / // Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription J-02B _ PACKER 9059 7959.22 4-1/2" Baker ZXP Packer J-02B PACKER 9111 8003.46 5-1/2" Baker LT Packer J-02B PACKER 9779 8593.5 3-1/2" Baker Liner Top Packer II Ili a) o. OO ° 00000 O O N CO 0 Cn O — O in N O O N- C)) 0) U) � 0 CO NI- T- I� V C• O 0 U) NN- O U) COY) UC) N a T' co N O CO CO CO CO CO 0) OO 0V CANCOU) (00 0) CA ONO 0�0 N N Oc0 0 O • llllll ce) CEO O 00 N 00 co O N .- N N N 00000NO M 0 0 N O) C CO N0MO NCD N O co N _Nr LO 00)) 00) N N 00) O V' 0) V i ■ • c Q CO CO co OR � NLOcoCO Ca N N N- NNNON C 0 I-• e O 0 Q 0 00 co 9 co C) .4. a , YYc� co J Z = dJ Aao0o *k • N co CO LO V y � NN (N Co 0 �0\- N ca? M M N A 0 CA Cr) () r � � 4 Z ▪ co co a cg cg co C N • N 0 C CCD O a) O 0) 0 N N N- CA 01 0) W CC H Z Z — 00 W 0 CL CL CC 0 0 0 Q V Z Z W W W O O m �U ? _ Maa Cr) COOI- « E2 E / e a. / 0_ 0a. C 2 § co \ / O . o4- o & H ? - f ..-z E % » / \ k / # o f22 » \ 2 Q W2 / E n = . To \ % / k / § H cow k_ - o E o $ _ • u) ƒ m c e\ m o H a $ � $ ƒ Ca/ \ \ % - 0) �H QED ^� � < 0) § U - . 7 a - k C 2 7 (t i 2 § 2 s / $ \ $ co \ O $ J - 3 a co ee oe � � ooh 5 �± 6 O & - Ao ± S / �° ky cn g $ W 5 > W / ® C) - / OS k\ k\ •\I k. - ƒ a \ co/ \ 0- 7 < 7 e- = w & m000 O ,- mI 66 \ / § m5 DES / Z 0 CO i % i 0 - § _ƒ \ $ \ 0 / \ 6 0 CO CO @ ono R q O # G \ / G \ 5 / O » m © O 4- o s \ \ co \ / \ - Cl- , § / � 0 _1 O ~ O ® o O 3 a E -< ; _ < t Ci m e m k g / m m ° O I ^ O o Q o a 0 c 2 2 O 3 > O \ CD / / ® / - 22 / / E0 kt & _ ƒ Ce \ k / \ § / / } \ $ 6 / \_ \ \ / --- \ , - Dee 0co \\ 0c\ / \ / > EoE > ■ 5 2 g o r / .[ -- 2 p R / •s R / I E .§ 1- 42 .- P 7 r U- O ± O ± E e o o ± 7 .2 0 > _ . > 1 G 0 ® ± G 0 \ ± / • G 0 & ( co ? \ k co / E m \ / 2 -0 - co - .1_13 a 9 ± ± o � � WTI ° � ) < / � � \ \ 6 E E « § / / \ 6 = 0 c _ n .» eeeco .> R0 & , er .. < E ^ 2 2 .- $ ® t / \ /® t / E 2 ° U® 5 A 0 II < 0 m / CIS 0 / - g cl/ ( \ n$ &2 E$ \ _ / ® II $ o b ii 0 O 2 cr £ 0 0 0 7 J / 3 0 O m E % / \ $ i / f $ CO CO co co CO r / d d @ / 6 N- CO „ TILE s 4”CAMERON WELLHEAD= CAMERON SAFE 1TES: 7"SCAB LNR CMTD&SET ON ACTUATOR= NA J 0 2 B BM ERb_ :Y SLIPS DURING RWO."WELL RENAM ED J- OKB.EFEV= 57.33' 02A WH EN IT WAS D TI DEEPENED FROM E PUT RIVER BF.ELEV= 20.00 FORM TO THEIVISHAK"4-1/2"CHROME TBG**06/12/77 - - 9-518"DV PICR SQZ 1300 sal 8 07/07/92(400 sx1" KOP= 2400' . Max Angle= 94°©10740 I I 861' H13-3/8"FOC I Datum MD= 9939' '. OratumND= 8800 SS 918' H13-3/8"CASING PATCH 20"CONDUCTOR,94#,N 40,8 RD H 931 II 2003' 10-3/4•X 9-5/8•XO 11 �;� ►;�, ■ 2042' H 9-5/8"FOC 110-3/4"CSG,55.5#,N-80 I- 2003' / ■ 2053' H 9-5/8"CASING PATCH . 1 I 111 I 2184' H4-1/2"HES X NP,D=3.813" I 7"DV COLLAR H 4019' II,+ 1 3254' H EST TOP OF CEMENT 13-3/8"CSG,68#,K-55, D=12.415" —I 4589' I li M 5955' H EST TOP OF CEMENT 9-5/8"DV COLLAR H 6492' 11 #; GAS LFT NIANDTiEFS 111 �� ST MD ND DEV TYPE VLV LATCH PORT DATE 7"TEBACK LNR,26#,L-80,ID=6.276" ---I 9296' s•j 4 3000 2976 20 KBG2 DOSE BBC 16 12/14/04 '' '1 3 5583 5177 33 KBG2 SO BK 20 12/14/04 Minimum ID = 2.992" @ 977T 111 �/ 2 7538 6784 33 KBG2 DM1' BK 0 11/19/04 111 ■∎1 1 8946 7928 33 KBG2 DMY BK 0 11/19/04 3-1/2" SOLID LINER • \p,; �•�� a�,, I 9015' H4-1/2"HES X NP,D=3.813" I 1 1f1 111 fi 9036' I—7"X 4-1/2"BKR PKR 4-1/2'TBG,12.6#,13CR-80, — 9093 111 N 0152 bpf,D=3.958" ..4 4 9059' H4-1/2"HES X NP,D=3.813" I 1�1 •; 9080' H4-1/2'HES XN NP,D=3.725" I TOP OF 5-112'LNR H 9105' 111 �4 1. 1 9-5/8-x r BKR TEBACK LNR PKR SHOE — 9296• • /� 1��1 9093' —I4-112"WLEG 1111• 11111 TOP OF 3-1/2•LNR 9772' :' 11111 111•W ►��V71� 9787' 5-1/2"X 4"HR ZXP LNR TOP PKR N1 ■ ■; 1111. IV.. 44444 1'41+4 9799' H5-1/2"X 3-1/2"HMC LNR HANGER TOP OF 5-1/2"WHPSTOCK —I 9916' 14.440' 14111111 111 . `11 11114 ��. �,.i MILLOUT WINDOW (J-02B)9916'-9928' 111 ∎. 11111 �1` - PBTD H 9937' 1•'•' '1'1 01•,1 10173' MARKER JOINT Ve∎►1�1�1I1�V 11/16 H 111111111111 , 9-5/6"CSG,47#,N-80,D=6.681• 10410' 11 4 111111111 44 *4 1111 11 H 111 111111 41 X111/1111111111111111 ■ 11270 —I3-1/2"CESP(11/10/13) 1111111444 11 444 1.1.1.1.1.1,111 fir, PERFORATION SUMMARY 14,'. . .�. . . 11 PBTD 11929' 1111t••11/1/ 11111: \1144 REF LOG:SWS MD on 11/07/04 W.I.VW.1.0.1 ANGLE AT TOP PERF:89°@ 10450' '1'1'1'1/4'1'1'1'1"1'4 11/14 11111111111111 Note:Refer to Production DB for historical pert data 14141V�41A1a1e1ge4ve1i .■ SQE SFF INTERVAL Opn/Sgz SHOT SQZ . 2" 6 10450-10480 0 11/10/13 10217' —KEVLAR NYLON CENTRAL 2" r 6 10678-10948 0 11/05/04 ARM(06/11/91) 2" r 6 10978-11098 0 11/05/04 3 UR ARMS(05/12/91) 2" F 6 11328-11428 C 11/05/04 12028' I--3-1/2'SOLID LNR 9.2#,L-80 2" ' 6 11508-11608 C 11/05/04 .0087 bpf,D=2.992" 2' 6 11648-11808 C 11/05/04 2' 6 11853-11928 C 11/05/04 DATE REV BY COWENTS DATE REV BY CONSENTS PRUDHOE BAY UNIT 11/06/69 ORIGINAL COMPLETION 11/13/13 CJS/JMD SETCBRAOPERFS(11/13/13) WELL: J-02B 07/06/82 LAST RENO PER NIT No:'1690970 11/19/04 DOYON 16 SIDETRACK(J-028) AR No: 50-029-20023-02 05/07/04 ??/KAK WELL NAIVE CLARIFICATION SEC 9,T11 N,R13E 1080'NSL&1245'WE I.. 12/14/04 ? GLV C/O 09/15/06 JGMI PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • • ~- ,~,, ~' ~x- r .~ a- ,~ MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth W 02/22/2007 NO. 4158 dCl-I- /15L/ -# IL{54b Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 b# L D Field: Prudhoe Bay D t BL CD ell Jo og escrlptton ae o or MPS-33A 11676926 CH EDIT USIT (PDC-GR) 01/31/07 1 1 W·35 11486088 RST 12/15/06 1 1 J-02B 10964121 RST 01/26/05 1 1 C-36A 11209600 MCNL 04/24/06 1 1 04-38 11477734 RST 12/02/06 1 1 A·05A N/A USIT (CEMENT EVALUATION) 01109107 1 A-05A 11626272 USIT (CEMENT EVALUATION) 01130107 1 - CI . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: liAR ~¿ '.. 2 ZODl sCANNED APR 0 3. 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth \ ì Received by: 7 r\i~ska Oill,~ Commission Anchoragp, PBU J-02B . . Andy, No open hole logging data was submitted for PBU J-02B API 50-029-20023-02. Please send over bluelines, reproduceables, and digital logging data for this well. TNX Howard 1 of 1 11/29/2006 8:20 AM Sc~luInb8rger N(~V ~~ 9 2006 NO. 4038 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay W ell Job# Loa DescriDtion Date BL Color CD J-02B PB1 40011126 OH EDIT OF MWD/LWD 11104/04 2 1 J-02B 40011126 OH EDIT OF MWD/LWD 11107/04 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950~3_28~ ATTN: Beth ê Received by: . ~ - . ----------- Date Delivered: NOV 2. 9 g {)ö4 -/ri -It 1L./;;JC:.,Lj ~ ¡L(è905 11/10/06 . . c ) 7 D~c- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041840 Well Name/No. PRUDHOE BAY UNIT J-02B Operator BP EXPLORATION (ALASKA) INC 5'4-cL J ò D~~\o API No. 50-029-20023-02-00 MD 12028 r-- TVD 9019 ---Completion Date 11/17/2004.--- Completion Status 1-01L Current Status 1-01L UIC N ~-- ~~~.,~- -~-~~,--- REQUIRED INFORMATION sam~ NO__~______~~~~~naISu~ ..- Mud Log No --- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name ~ D Asc Directional Survey t Directional Survey D D Asc Directional Survey ~~~______~__ Direction~_urvey Well CoreslSamples Information: (data taken from Logs Portion of Master Well Data Maint Interval OH 1 Start Stop CH 9906 12028 9906 12028 9906 10848 9906 10848 Received Comments 11/18/2004'-~~---~--] I 11/18/2004 I 11/18/2004 PB 1 . 11/18/2004 PB 1 . Log Log Run Scale Media No . ._".~_._--~-_._--,---~-~-"--..~,- .._--~._----,...- Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y íQ) Chips Received? '-Y 1 t~ - Formation Tops (0/N ~ . Daily History Received? Analysis ~- Received? Comments: -$ ---'.,_..,~ --~---- ),1:.~ .. - ---=--'C=~~_~-=: Date: ._' ~~_~_~~~ --- -"._-._---~ Compliance Reviewed By: ., _ STATE OF ALASKA R-E· -C"EW'\/'I='D,¡ ALASKWJL AND GAS CONSERVATION C04s10N ... - --,"" ~ , ¡,...., WELL COMPLETION OR RECOMPLETION REPORT AND LOGDEC 3 02004 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1080' SNL, 1245' WEL, SEC. 09, T11N, R13E, UM Top of Productive Horizon: 3685' SNL, 2082' EWL, SEC. 10, T11N, R13E, UM Total Depth: 3639' SNL, 3728' EWL, SEC. 10, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 643114 y- 5970265 Zone- ASP4 TPI: x- 646496 y- 5967725 Zone- ASP4 Total Depth: x- 648140 y- 5967803 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD DIR I GR I RES One Other 5. Date Camp., Susp., or Aband. 11/17/2004 6. Date Spudded 10/30/2004 7. Date T.D. Reached 11/7/2004 8. KB Elevation (ft): 63.39' 9. Plug Back Depth (MD+ TVD) 11928 + 9014 10. Total Depth (MD+TVD) 12028 + 9019 11. Depth where SSSV set (Nipple) 2184' MD 19. Water depth, if offshore NIA MSL CASING, LINER AND -C-EMENTING RECORD HOLlO SIZE 26" 22. CASING SETTING EPTH MO : SETTING [ EPTHTVO SIZE WT,PER .FT. GRADE TOp BOTTOM TOP IBOTTOM 20" 94# H-40 Surface 931' Surface 931' 13-3/8" 72# / 68# I 61 # N-ao I K-55 / J-55 Surface 4589' Surface 4348' 7" 26# L-80 Surface 9296' Surface 8226' 10-3/4" x 9-5/8" 55.5# 147# N-80 Surface 9916' Surface 8779' 5-1/2" 17# L-80 9105' 9916' 8062' 8779' 3-1/2" 9.2# L-80 9772' 12028' 8651' 9019' 23. Perforations open to Production (MD + TVD of Top and 24 Bottom Interval, Size and Number; if none, state "none"): . 2" Gun Diameter, 6 spf MD TVD 10678' - 10948' 9016' - 9012' 10978' - 11098' 9012' - 9012' 11328' - 11428' 9010' - 9007' 11508' - 11608' 9005' - 9004' 11648' - 11808' 9004' - 9008' 11853'-11928' 9010'-9014' MD 26. Date First Production: December 24,2004 Date of Test Hours Tested 12/28/2004 4 Flow Tubing Casing Pressure Press. 1,04C 1,700 27. 17-112" Tieback 12-1/4" 7" 4-3/4" TVD 4-1I2",12.6#,13Cr80 SIZE AI(lsv.a Oil & Cormnissiçm ACID, nn", WATER-BBl 215 W A TER-BBl 1,290 1 b. Well Ct'fftfthorsge 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-184 13. API Number 50- 029-20023-02-00 14. Well Name and Number: J-028 15. Field 1 Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028281 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) - =- 2000 sx Fondu I Fly Ash 3150 sx Class 'G' 417 sx Class 'G', 118 sx Arcticset 1370 sx Class 'G', 725 sx Class 'G' 155 sx Class 'G'TScab Liner) 168 sx Class 'G' T jSI/II(; DEPTH SET (MD) 9096' PACKER SET (MD) 9036' ÆB DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected wI 75 Bbls of Diesel 25. GAs-McF 2,880 GAs-McF 17,282 CHOKE SIZE TGAS-Oll RATIO 96° 4,286 Oil GRAVITy-API (CORR) 37.1 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing PRODUCTION FOR Oll-BBl TEST PERIOD .. 672 CALCULATED ...... Oll-BBl 24-HoUR RATE""'" 4,032 Ü(:i:',:~', None ø~'¡ ~ v;-· -t""u,;;}J- ~ ,_..4.: r '--"'-" Form 1 0-407 Revised 12/2003 OR,'G\~\ll\L CONTINUED ON REVERSE SIDE RBDMS 8Ft JAN 0 4 2005 (..f 28. GEOLOGIC MARKER NAME MD 25N 9980' 25P 9992' 24N 10037' 23N 10062' 22N 10086' 21N 10160' 14N I Zone 18 10373' 29. ORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8836' None 8847' 8885' 8906' 8924' 8971' 9014' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys Signed Terrie Hubble Title Technical Assistant Date l 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. J-02B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ken Allen, 564-4366 204-184 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only of 1 9,942.0 (ft) FIT 10/29/2004 0:20:22 AM 122/2004 Printed: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: 10/18/2004 06:00 - 09:00 3.00 MOB P PRE Prepare for rig move 109:00 - 09:30 0.50 MOB P PRE Move off well S-119 to center of pad. Pad Operator present due to close proximity of S-1 08 and S-11 O. 09:30 - 10:30 1.00 MOB P PRE Install rear boosters. 10:30 - 20:00 9.50 MOB N WAIT PRE Move rig to "Y" in S Pad access road and park while waiting for plugs to be set in J-02. 20:00 - 00:00 4.00 MOB P PRE Move rig down S Pad access road to junction with Spine Road. 10/19/2004 00:00 - 03:00 3.00 MOB P PRE Moving rig down Spine Road toward J Pad from S Pad Access Road/Spine Road junction. 03:00 - 03:30 0.50 MOB P PRE Leak of less than 1 gallon of hydraulic fluid released on Spine Road due to fitting failure. Spill Response notified. Leak cleaned up and bagged by rig crew. 03:30 - 10:00 6.50 MOB P PRE Continue with rig move to J Pad. Park rig on pad. Waiting for J-02B to be prepared for rig operations. 10:00 - 00:00 14.00 MOB N WAIT PRE Remove rear booster and steam heater. Repaired off driller side cellar door sheave. Install new standpipe manifold. Change shaker screens. Service TDS, skate, iron roughneck and change air slips to 4" body. Inspect drawworks chains. Change hydraulic filters. Repair 2" Demco valve on cement line. Coil tubing unit arrived on J-02 at 2200 hrs. Rigging up. Move camps to J Pad at 2100 hrs. 10/20/2004 00:00 - 00:00 24.00 MOB N WAIT PRE Rig and all equipment on location. Waiting for well to be prepared for the rig to move on. Coil unit on J-02. Rig Detail: Clean and prime gen #1. Change out valves and seats on Mud Pump's # 1 &2. Hang cellar pump. Service crown and tugger sheaves. Perform derrick inspection. Change #1 shaker screens. Repaired steam leak in pump room. Work on #2 mud pump charge pump. Working on water softener system. Inspect, repair and adjust drag chain. Fabricate steam lines in new pit complex. Prepare rig floor for upcoming decompletion operations. General cleaning and painting. Coil Tubing Detail: Rig up. Pump 1.25" ball through coil. Perform weekly BOP test. MU/RIH with 1.75" BDN BHA. Pump 400 bbls 1% down tubing to kill well. Tag TD at 10,213'. Pump diesel down tubing and IA. Lay in 27.8 bbls cement. 1:1 returns, 0 bbls behind pipe. Pressure test 400 psi over shut in well head pressure. POOH replacing coil displacement. Estimate TOe at 9,824'. Circulate well to 1% KCI. 10/21/2004 00:00 - 14:00 14.00 MOB N WAIT PRE Rig and all equipment on location. Coil tubing unit on well. Coil pumped diesel freeze protect and allowed to U-tube. Waited for cement compressive strength to reach 1,000 psi prior to CT performing casing pressure test. Rig performing maintenance and repairs. Little Red pressure tested casing to 2,500 psi, good test. CT Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A j-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: 10/21/2004 00:00 - 14:00 14.00 MOB N WAIT PRE rig down and move off location. 114:00 - 22:00 8.00 MOB P PRE Lay herculite and set mats. Move over well and shim rig. I Nipple up annulus valves and rig up to circulate. Spot slop I tank. Berm around rig and slop tank. ¡ I Accept rig for well work on J-02B at 22:00 hours. 122:00 - 00:00 2.00 RIGU P PRE Pre-spud meeting with crews. Take on sea water. 10/22/2004 ,00.00 - 00.30 0.50 RIGU P PRE Hold Pre-Spud meeting and PJSM for displacement with crew i and truck drivers. 100:30 - 01 :00 0.50 RIGU P PRE Test surface lines to 2,500 psi. 101 :00 - 04:00 3.00 RIGU P PRE Displace well to seawater, 5 bpm at 500 psi. Pump down IA 1 taking returns from tubing directly to cuttings tank until all I I diesel out of tubing. Pump down tubing taking retums directly to cuttings tank until diesel cleared from IA. Pump 40 bbls I detergent sweep followed by 400 bbls heated seawater to clean i up well bore. r 04:00 - 05:00 1.00 RIGU P PRE . ObseNe well on tubing and annulus sides for 30 minutes. No flow or losses. Blow down lines. 105:00 - 08:00 3.00 RIGU PRE Nipple down tree and adapter flange. 108:00 - 12:00 4.00 BOPSU DECaMP Nipple up BOP's. 12:00 - 14:00 2.00 BOPSU DECOMP Modify flow nipple. Connect turnbuckles and drain hoses. 114:00 - 14:30 0.50 BOPSU DECOMP Test BOP/well head connection to 2,500 psi and record on chart. Good test.. Rig up control line spooler. 114:30 - 15:30 1.00 BOPSU DECOMP Nipple up flow nipple and flow lines. 15:30 - 19:00 3.50 PULL DECOMP Rig up and make up 3.947" OD grapples on spear assy. Attempt to engage tubing. Spear assy would not enter crossover on hanger. Lay down spear assy. Make up 3.885" OD grapples on spear assy. RIH and engage grapples in tubing. Pull hanger (140K up weight) free and pull to rig floor. LD fishing assy and hanger. Note: There was no control line on hanger. It was investigated and found that the completion string has a "K" valve nipple, thus control lines were never installed. 19:00 - 21 :30 2.50 PULL P DECOMP Lay down 50 joints 4.5",12.6# tubing. Lay down K Valve landing nipple. 21 :30 - 22:00 0.50 PULL P DECOMP Rig down control line spooler. Rig up to run storm packer. 22:00 - 23:00 1.00 RIGU P PRE Make up storm packer, run in hole and set at 65'. Test from above with 250 psi. Lay down packer running assy. Note: Approximately 70,000# buoyed weight of tubing hanging below packer. 23:00 - 00:00 1.00 BOPSU P PRE Drain stack and nipple down BOP and tubing spool. 10/23/2004 00:00 - 01 :00 1.00 BOPSU P DECOMP Continue Nipple Down BOP. 01 :00 - 02:30 1.50 WHSUR P DECOMP Remove existing tubing spool. Change out primary packing seals (12 x 7). 02:30 - 04:00 1.50 WHSUR P DECOMP Install new tubing spool. Set BOP down on spool for weight. Fill packing void with plastic and test same to 3,500 psi for 10 minutes. Good test. 04:00 - 06:00 2.00 BOPSU P DECOMP Nipple up BOP, flow nipple and flow lines. 06:00 - 10:30 4.50 BOPSU P DECOMP Rig up and test BOP's to 250 psi low and 3,500 psi high. Hold all tests for 5 minutes and record on circular chart. Rig down test equipment, pull test plug, set wear bushing and blow down Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: Note: Witness of BOP test waived by Chuck Scheve, AOGCC Rep. 10:30 - 11 :30 1.00 DHB P DECOMP Pick up two joints of drill pipe, engage and release storm packer. 11 :30 - 12:30 1.00 WHSUR P DECOMP Circulate bottoms up. 12:30 - 13:00 0.50 WHSUR P DECOMP POOH and lay down storm packer. Rig up to pull 4.5" tubing. 13:00 - 19:30 6.50 PULL P DECOMP Lay down 175 joints 4.5", 12.6# tubing, K-Valve, and 19.84' cut off joint. Calculated top of stub in hole at 9,060.98'. 19:30 - 20:00 0.50 PULL P DECOMP Rig down tubing equipment. Clean rig rloor. 20:00 - 22:00 2.00 PULL P DECOMP PJSM. Make up overshot BHA. 22:00 - 00:00 2.00 PULL P DECOMP RIH picking up drill pipe singles from pipe shed. At midnight, 50 joints PU, depth 2,010'. 10/24/2004 00:00 - 06:00 6.00 PULL P DECOMP Continue picking up drill pipe singles from pipe shed and RIH from 2,010' to 8,817' with overshot BHA. 06:00 - 06:30 0.50 PULL P DECOMP Service rig and TDS 06:30 - 07:00 0.50 PULL P DECOMP Continue to PU drill pipe and RIH to 9,110'. Wash to 9,157' (TOF). 07:00 - 07:30 0.50 PULL P DECOMP Engage fish. 07:30 - 11 :30 4.00 PULL P DECOMP Blow down TDS. POOH from 9,157' to BHA. 11 :30 - 13:30 2.00 PULL P DECOMP POOH with BHA. Lay down recovered fish, 42.06' tubing stub and SBR. Slick stick stiIJ in hole. 13:30 - 14:30 I 1.00 PULL P DECOMP Redress and make up overshot assy and RIH to 414'. 14:30 - 17:30 I 3.00 PULL P DECOMP RIH on 4" drill pipe to 9,110'. 17:30 - 18:00 0.50 PULL P DECOMP Wash from 9,110 to 9,182'. Engage fish and release K anchor. 18:00 - 21 :30 3.50 PULL P DECOMP Flow check the well, OK. Blow down TDS. POOH with fishing assy to BHA 21 :30 - 23:00 1.50 PULL P DECOMP POOH with BHA. Fish completely recovered. Lay down same. Break out and lay down fishing assy. 23:00 - 00:00 1.00 PULL P DECOMP Make up packer milJs and retrieving tool assy and RIH with same. 10/25/2004 00:00 - 02:30 2.50 I PULL P DECOMP RIH with packer milling BHA to 8,561 '. 02:30 - 03:00 0.50 I PULL P DECOMP Service rig and TDS 03:00 - 03:30 0.50 PULL P DECOMP RIH and engaged packer at 9,204'. 03:30 - 08:30 5.00 PULL P DECOMP Milling packer from 9204' to 9205.5'. Verify packer free. 175K UP 160K DN 155K RT 5K WOB 5K-6K TORO 193 GPM 600 psi 08:30 - 12:30 4.00 PULL P DECOMP POOH to BHA 12:30 - 15:00 2.50 PULL P DECOMP Rack back collars, LD fishing BHA. Retrieved 139.28' fish (Packer and tailpipe assembly). Bottom packer slips and half of the bottom cone not retrieved. 15:00 - 16:00 1.00 PULL P DECOMP Clean and clear rig floor. Make up junk miIJ BHA. 16:00 - 17:30 1.50 CLEAN P DECOMP RIH with junk mill BHA to 3,279'. 17:30 - 18:30 1.00 CLEAN P DECOMP Slip and cut drill line. 18:30 - 19:30 1.00 CLEAN P DECOMP RIH picking up drill pipe singles from pipe shed from 3,279' to 3,729'. Picked up a total of 24 joints to allow reaching 9,985'. 19:30 - 22:30 3.00 CLEAN P DECOMP RIH from 3,729' to 9,706'. Wash from 9,706' to 9,835'. 22:30 - 00:00 1.50 CLEAN P DECOMP Mill junk and dress cement from 9,835 to 9,908' 178K UP 156K DN 168K RT 268 GPM 900 PSI 90 ROTARY 5K WOB 4K-5K TORO Printed: 11/22/2004 10:20:28 AM Legal Well Name: j-02A Common Well Name: j-02A Spud Date: 9/24/1969 Event Name: REENTER+COMPLETE Start: 9/16/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/17/2004 Rig Name: DOYON 16 Rig Number: CÖde 10/26/2004 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to dress cement from 9,908' to 9,985'. 00:30 - 01 :30 1.00 CLEAN P DECOMP Pump hi vis sweep surface to surface to clean hole. 01 :30 - 02:00 0.50 CLEAN P DECOMP POH 2 stands and run back in hole to bottom to verify hole clean. Tagged bottom at 9,985', no fill or debris noted. 02:00 - 04:30 2.50 CLEAN P DECOMP POH from 9,985' to 4,048'. 04:30 - 05:00 0.50 CLEAN P DECOMP Service rig and TDS. 05:00 - 06:30 1.50 CLEAN P I DECOMP Continue POH from 4,048' to BHA. 06:30 - 07:00 0.50 CLEAN P I DECOMP - Stand back DC's & LID Baker tools. 07:00 - 08:00 1.00 CLEAN P I DECOMP - Clear & clean rig floor. 08:00 - 08:30 0.50 CASE P DECOMP - RlU 5 1/2" casing equip't. 08:30 - 10:00 1.50 CASE P DECOMP - PJSM - M/U 51/2" 17# 521 Hydril shoe track & Bakerlock 1st 2 jts. 10:00 - 10:30 0.50 CASE P DECOMP - Repair leak on casing fill up line. 10:30 - 13:00 2.50 CASE P DECOMP - Continue RIH w/5 1/2" 17# 521 Hydril. Ran 20 jts total & 1 I x-over jt from 5 1/2" 521 Hydril Pin x 5 1/2" BTC B. I - M/U liner hanger / packer. 13:00 - 13:30 0.50 I CASE P DECOMP - Circulate 1 liner volume @ 3 BPM 170 psi. - P/U wt 55K, S/O wt 57K. 13:30 - 20:00 6.50 CASE P DECOMP - Run 5 1/2" liner on 4" DP & tag bottom @ 9985'. 20:00 - 20:30 0.50 CASE P DECOMP - LID DP single & M/U TD head & pup jts. 20:30 - 22:30 2.00 CASE P DECOMP - Circulate liner & DP volume x 1.5 @ 1 to 3 BPM. - Packing off while reciprocating pipe - Stop reciprocation & finish circulation @ 2.3 BPM 330 psi. 22:30 - 23:00 0.50 CEMT P DECOMP - Pump 5 bbls fresh water & test lines to 4000 psi. - Pump 32 bbls 15.8 ppg Class G cement @ 2 - 2.5 BPM, 200- 300 psi. 23:00 - 23:45 0.75 CEMT P DECOMP - Close valve on TD head & wash up cement line. Open valve & release wiper dart. - Turn over to rig pump & displace cement w/115.8 bbls S/W @ 2.5 - 3 BPM. P/U hanger 3' off bottom to 9982' after cement turned corner. Bump plug & pressure up to 3500 psi. - CIP @ 23:45 hrs. 23:45 - 00:00 0.25 CEMT P DECOMP - S/O 30K to ensure liner hanger set. Bleed off pressure & check floats. Floats holding. 10/27/2004 00:00 - 00:30 0.50 CASE P DECOMP - Rotate DP 15 turns & pressure up to 800 psi. P/U string & unsting running tool from hanger. - S/O 35K & set packer. Good indication of shear. - P/U string to clear running tool from packer & CBU x 1.25 @ 8 -11 BPM, 2500 - 3100 psi. - Approximately 4 bbls cement back to surface on B/U. 00:30 - 01 :00 0.50 CEMT P DECOMP - RID cement head. 01 :00 - 01 :30 0.50 CEMT P DECOMP - CBU @ 10 BPM, 2070 psi, 100 RPM & reciprocating. - B/D TD. 01 :30 - 05:00 3.50 CEMT P DECOMP - Monitor well - static. - POH from 9107'. Dog sub sheared. 05:00 - 05:30 0.50 CEMT P DECOMP - P/U plug dropping head & break out pup jt. LD same. 05:30 - 06:00 0.50 CEMT P DECOMP - Lubricate rig. 06:00 - 08:30 2.50 CLEAN P DECOMP - M/U & RIH w/ clean-out BHA. 4 3/4" mill, bit sub, 6 DC's, jars, x-over, 24 jts 2 7/8" DP & 2 x-overs. 08:30 - 12:30 4.00 CLEAN P DECOMP - RIH & tag landing collar on depth @ 9935'. 12:30 - 13:30 1.00 CLEAN P DECOMP - CBU @ 4 BPM 650 psi. 13:30 - 14:00 0.50 CLEAN P DECOMP - Test 7" x 5 1/2" casing to 3500 psi for 30 min. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 10/27/2004 14:00 - 16:00 2.00 CLEAN P DECOMP - POH from 9935' to 4208'. 16:00 - 17:00 1.00 CLEAN P DECOMP · RIH w/4 3/4" DC stands - POH & UD. 17:00 - 18:00 1.00 CLEAN P DECOMP - POH from 4208' to 1526'. 18:00 - 20:00 2.00 STWHIP P DECOMP - POH & UD BHA & 18 jts 4" DP. 20:00 - 23:30 3.50 STWHIP P ¡WEXIT - M/U whipstock BHA - scribe & orientto MWD. · P/U 11 x 2 7/8" DC's & RIH w/6 stands 2 7/8" DP. · Shallow test MWD - BID TD. 23:30 - 00:00 0.50 STWHIP P IWEXIT - RIH wI whipstock to 1200' 10/28/2004 00:00 - 05:00 5.00 STWHIP P WEXIT · RIH wI whipstock from 1200' to 9920'. - Fill pipe and break circ at 4000'. I - Cont RIH to 9920'. Attempt to break circulation wlo success. I I Pressure up to 2500 psi & bleed off several times in attempt to I unplug string. 05:00 - 06:00 1.00 STWHIP N DPRB IWEXIT - POH to 5 1/2" liner top & attempt to unplug string by applying I pressure & bleeding off wlo success. 06:00 - 09:30 3.50 STWHIP N DPRB IWEXIT - POH from 9050' to 5296' attempting to unplug drill string every 1000' wlo success. I I 09:30 - 12:30 3.00 STWHIP N DPRB IWEXIT · Drop ball & open up circ sub - continue POH to BHA @ 1003'. 12:30 - 14:00 1.50 STWHIP N DPRB iWEXIT · UD 2 7/8" DP & 31/2" DC's. 14:00 - 16:00 2.00 STWHIP N DPRB iWEXIT - Break down & clean out BHA. BHA plugged wI fine metallic I I scale from bumper sub to mills. · Recovered approx 6 gal of scale from BHA. 16:00 - 17:30 1.50 STWHIP N DPRB !WEXIT - M/U whipstock assy. 17:30 - 19:30 2.00 STWHIP N DPRB IWEXIT - P/U 2718" DP & 3 1/2" De's & RIH. i - Empty active pits containing S/W. (pits 2 & 4) Clean suction i I i pit. Suction pit was clean wI no material in bottom that i resembled material that was found in drill string. Fill pits wI I clean S/W. 19:30 - 20:00 0.50 STWHIP N DPRB iWEXIT - Shallow test MWD. 20:00 - 00:00 4.00 STWHIP N DPRB WEXIT - RIH to 6734' & break circ every 10 stands. 10/29/2004 00:00 - 01 :00 1.00 STWHIP N DPRB WEXIT - RIH wI whipstock from 6734' to 8654' breaking circ every 1000'. 01 :00 - 01 :30 0.50 STWHIP P WEXIT - Lubricate rig & service TD. 01 :30 - 03:00 1.50 STWHIP N DPRB WEXIT - RIH wI whipstock from 8654' to 9916'. - Orient whipstock @ 5 1/2" liner top. - Wash down whipstock throughout 5 1/2" liner @ 2 BPM 550 psi. - P/U wt 185K, S/O wt 145K wlo pump @ 9916'. 03:00 - 04:00 1.00 STWHIP P WEXIT - Attempt to get tool face from MWD. Out of sync wI S/W. 04:00 - 04:30 0.50 STWHIP P WEXIT - Set whipstock anchor w/15K & shear mill set screw wI 25K. - Set whipstock 36 deg LHS. 04:30 - 09:30 5.00 STWHIP P WEXIT - Mill window through 5 1/2" & 9 5/8" casing @ 190 GPM 1980 psi, 80 - 100 RPM, Tq 8 - 10K, Wt on mill 1 - 5K. - TOW @ 9916', BOW @ 9928'. - Drill 20' new hole from middle of window to 9942'. - P/U wt 185K, S/O wt 145K, Rot wt 167K. 09:30 - 10:30 1.00 STWHIP P WEXIT - CBU wI S/W @ 190 GPM, 1980 psi, 100 RPM. 10:30 - 11 :00 0.50 STWHIP P WEXIT - PJSM for displacement. 11 :00 - 14:00 3.00 STWHIP P WEXIT - Pump S/W followed by 245 bbl used flo-pro sweep & displace well to new 8.4 ppg flo-pro drilling fluid. Pump @ 190 GPM, 1980 - 2250 psi. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A j-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 10/29/2004 14:00 - 15:00 1.00 STWHIP P WEXIT - Conduct FIT to 9.8 ppg EMW - 600 psi surface pressure. 15:00 - 16:30 1.50 STWHIP P WEXIT - Open circ sub & circulate hole clean @ 11 BPM 1400 psi. - BID TD, choke & kill lines. 16:30 - 21 :00 4.50 STWHIP P WEXIT - POH & rack back 4" & 2 7/8" DP. 121 :00 - 22:30 1.50 STWHIP P WEXIT - UD BHA - Starter mill & lower string mill 1/4" out of gauge, upper string mill full gauge. 22:30 - 00:00 1.50 STWHIP P WEXIT - R/U & flush stack - function all rams - RID. . BID TD, choke & kill lines. 10/30/2004 00:00 - 00:30 0.50 STWHIP P WEXIT - RIU handling equip't for BHA. 00:30 - 02:00 1.50 STWHIP P WEXIT - M/U 4 3/4" drilling BHA. 102:00 - 03:00 1.00 STWHIP P WEXIT - RIH w/6 stands 2 7/8" DP from derrick - shallow hole test MWD @ 160 GPM 850 psi. 03:00 - 04:00 1.00 STWHIP P WEXIT - P/U 24 jts 2 7/8" DP from pipeshed & RIH to 1525'. 04:00 - 08:30 4.50 STWHIP P WEXIT - C/O to 4" handling equip't & RIH wI 4" DP to 8234' filling every 108:30 - 09:30 30 stands to 5100' & filling every 10 stands after 5100'. 1.00 STWHIP P (EXIT - C/O saver sub. 09:30 - 10:00 0.50 STWHIP P WEXIT . Service TD 10:00 - 11 :00 1.00 STWHIP P ¡WEXIT - Cut & slip 95' of drilling line. 11 :00 - 12:30 1.50 STWHIP P WEXIT - RIH from 8234' to 9730'. 12:30 - 14:00 1.50 STWHIP P WEXIT - Mad pass from 9730' to 9942' @ 2.8 BPM 940 psi. 14:00 - 14:30 0.50 STWHIP P IWEXIT - Establish baseline ECD @ 9.01 ppg. 14:30 - 16:00 1.50 DRILL P PROD1 - Drill directional in 4 3/4" hole from 9942' to 9962'. 100% slide. 16:00 - 17:00 1.00 DRILL N SFAL PROD1 - Attempt to get survey. MWD signal lost. - Regain MWD signal. 17:00 - 19:30 2.50 DRILL P PROD1 - Drill directional in 4 3/4" hole from 9962' to 10031'.100% slide. 19:30 - 22:00 2.50 DRILL N SFAL PROD1 - Attempt to get survey - MWD signal lost. Adjust pump rates & reduce pump pulsation dampener pressures in attempt to get surveys. - Regain MWD signal. 22:00 - 00:00 2.00 DRILL P PROD1 - Drill directional in 4 3/4" hole from 10031' to 10059'. 100% - WOB 5 - 10K, 160 GPM 1480psi, P/U wt 165K, SIO wt 150K. - AST 3.6 hrs 10/31/2004 00:00 - 00:30 0.50 DRILL P PROD1 - Drill directional in 4 3/4" hole from 10059' to 10074'.100% slide. 00:30 - 01 :30 1.00 DRILL N DPRB PROD1 - CBU @ 160 GPM 1420 psi. - Due to lack of cement behind 9 5/8" casing, original wellbore was tracked. Will not be able to hit target wi current 1.69 deg bent housing motor. Discuss options wI Anchorage Geologist & Drilling Engineer. Decision made to POH for 2.38 deg bent housing motor. 01 :30 - 07:00 5.50 DRILL N DPRB PROD1 - POH to change out motor. Note additional hour on time for to daylight savings. 06:00 - 07:00 1.00 DRILL N DPRB PROD1 - UD jars, De's, motor, & bit. 07:00 - 08:30 1.50 DRILL N DPRB PROD1 - P/U BHA - 4 3/4" XR15DPS bit, mud motor wI 2.38 deg bent housing, float sub, XO, PWD, XO, MWD collar, flow sub, XO, 3 NM flex collars, Circ sub, XO, jars & XO. 08:30 - 10:00 1.50 DRILL N DPRB PROD1 - RIH w/2 7/8" DP. - Shallow hole test MWD @ 190 GPM 1070 psi. 10:00 - 15:30 5.50 DRILL N DPRB PROD1 - RIH wI BHA to 10074' on 4" DP filling every 25 stands. - Lose & regain MWD signal. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Phase 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 10/31/2004 15:30 - 21 :30 6.00 DRILL P PROD1 - Drill directional & finish build in 4 3/4" hole from 10074' to 10310'.100% sUde. - Drilling parameters: WOB 10 - 20K, 160 GPM 1570 psi, P/U wt 170K, S/O wt 150K. - AST 4.15 hrs. 21 :30 - 23:30 2.00 DRILL P PROD1 - Pump 20 bbl hi-vis sweep & circ surface to surface @ 160 I GPM 1420 psi. 123:30 - 00:00 0.50 DRILL P PROD1 - Monitor well - static. - Pump out of hole (4 stands) @ 160 GPM 1420 psi. 11/1/2004 00:00 - 01 :00 1.00 DRILL P PROD1 - POH to 9292'. 01 :00 - 01 :30 0.50 DRILL P PROD1 - Drop dart & shear open circ sub. wI circ sub @ 5 1/2" liner - CBU @ 270 GPM 1250 psi - Small amount of cuttings on B/U. 01 :30 - 05:30 4.00 DRILL P PROD1 - POH from 9292' to BHA. 05:30 - 07:00 1.50 DRILL P PROD1 - UD 2 7/8" DC's & BHA. 07:00 - 07:30 0.50 BOPSU P PROD1 - R/U & flush stack. 07:30 - 08:00 0.50 BOPSU P PROD1 - Pull bowl protector & RIU test equip't. 08:00 - 13:00 5.00 BOPSU P PROD1 - Test BOPE per BP & AOGCC Regs to 3500 psi 1250 psi for 5 5 min. Test witnessed by AOGCC Rep John Crisp. - RID test equip't & BID TD. 13:00 - 18:30 5.50 DRILL N WAIT PROD1 - Service TD, drawworks, crown, sheaves, iron roughneck, & clean rig while waiting on PWD tool to return from machine shop. - PWD tool was egged when breaking out wI iron roughneck. PWD was sent to Tuboscope wI MWD Rep to remove batteries & to assess any potential damage. 18:30 - 20:30 2.00 DRILL P PROD1 I- M/U 4 3/4" BHA - MDT285 PDC bit, mud motor w/1.5 deg I bent housing, float sub, XO, PWD, XO, MWD collar, flow sub, XO, 3 NM flex I collars, circ sub, XO, jars, & XO. 20:30 - 23:30 3.00 DRILL P PROD1 I- RIH wI 14 stands of 2 7/8" DP from derrick & P/U 48 2 7/8" DP singles from pipeshed. 23:30 - 00:00 0.50 DRILL P PROD1 I- RIH wI BHA on 4" DP. 11/212004 00:00 - 03:00 3.00 DRILL P PROD1 - RIH wI BHA to 9846'. 03:00 - 03:30 0.50 DRILL P PROD1 I- Orient & RIH from 9846' to 10160'. TOW @ 9916'. 03:30 - 04:30 1.00 DRILL P PROD1 ,- Wash from 10160' to bottom @ 10310' @ 1 BPM 540 psi. 04:30 - 00:00 19.50 DRILL P PROD1 I- Drill directional in 4 3/4" hole from 10310' to 10679' pumping high-vis sweeps as needed. 1- Drilling parameters: WOB 5 -12K, 160 GPM, off bottom pressure - 1460 psi, on bottom pressure - 1650 psi, 40 RPM, off bottom Tq 5K, on bottom Tq 6K, P/U wt 165K, S/O wt 145K, Rot wt 150K. - AST 10.2 hrs, ART 1.6 hrs, ADT 11.8 hrs. 11/3/2004 00:00 - 09:30 9.50 DRILL P PROD1 - Drill directional in 43/4" hole from 10679' to 10848'. - Drilling parameters: WOB 5 - 12K, 160 GPM, off bottom pressure 1460 psi, on bottom pressure 1650 psi, 40 RPM off bottom Tq 5K, on bottom Tq 6K, P/U wt 165K, SIO wt 145K, Rotwl 150K. 09:30 - 10:00 0.50 DRILL P PROD1 - Circulate cuttings above 5 1/2" Uner top @ 160 GPM 1470 Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 11/3/2004 09:30 - 10:00 0.50 DRILL P PROD1 psi. 10:00 - 11 :00 1.00 STKOH C PROD1 - POH to 10190'. 11:00 -15:00 4.00 STKOH C PROD1 - Built trench for open hole sidetrack from 10190' to 10220'. 15:00 - 00:00 9.00 STKOH C PROD1 - Time drill @ 3 FPH in new 4 3/4" hole from 10220' to 10250'. - Drilling parameters: WOB 5K, off bottom pressure 1500 psi, Ion bottom pressure 1550 -1650 psi, P/U wt 165K, SIO wt 145K. 11/4/2004 00:00 - 12:00 12.00 DRILL C PROD1 1- Drill directional in open hole sidetrack from 10250' to 10381'. i 100% slide for angle & landing pt. - Drilling parameters: WOB 5K, 160 GPM, off bottom pressure 1500 psi, on bottom pressure 1550 - 1650 psi, P/U wt 165K, S/O wt 145K. - AST 6.97 hrs. 12:00 - 00:00 12.00 DRILL C PROD1 - Drill directional in 4 3/4" hole from 10381' to 10550'.100% slide for angle & landing pt. - Drilling parameters: WOB 5-12K, 160 GPM, off bottom pressure 1500 psi, on bottom pressure 1550 - 1700 psi, P/U wt 160K, S/O wt 143K. - AST 7.0 hrs. 11/5/2004 00:00 - 12:00 12.00 DRILL C PROD1 - Drill directional in 4 3/4" hole from 10550' to 10810'. - Drilling parameters: WOB 5K, 160 GPM, off bottom pressure 1500 psi, on bottom pressure 1550 - 1750 psi, 40 RPM, off bottom Tq 5K, on bottom Tq 6K. P/U wt 160K, SIO wt 145K, Rot wt 153K. - AST 4.87 hrs, ART 1.64 hrs, ADT 6.51 hrs. 12:00 - 00:00 12.00 DRILL C PROD1 - Drill directional in 4 3/4" hole from 10810' to 10955'. - Drilling parameters: WOB 5 -7K. 160 GPM, off bottom pressure 1530 psi, on bottom pressure 1580 - 1820 psi, 40 RPM, off bottom Tq 5K, on bottom Tq 6K, P/U wt 160K, SIO wt 145K, Rot wt 155K. - AST 5.8 hrs. ART 1.1 hrs. ADT 6.9 hrs. 11/6/2004 00:00 - 12:00 12.00 DRILL C PROD1 - Drill directional in 4 3/4" hole from 1 0955' to 11291'. - Drilling parameters: WOB 5 - 8K, 160 GPM, off bottom pressure 1530 psi, on bottom pressure 1580 - 1860 psi, 40 RPM. off bottom Tq 5K. on bottom Tq 6K, P/U wt 160K, SIO wt 145K, Rot wt 155K. - AST 2.31 hrs. ART 7.05 hrs. ADT 9.36 hrs 12:00 - 00:00 12.00 DRILL C PROD1 - Drill directional in4 3/4" hole from 11291'to 11527'. - Pumped low-vis sweep followed by 1.0 ppg over MW weighted sweep. - Pumped 20 bbl pill w/1 drum of lube-tex wI 350 Ibs of beads to aid sliding. - Drilling parameters: WOB 4- 5K, 160 GPM, off bottom pressure 1640 psi, on bottom pressure 1940 psi, 40 RPM, off bottom Tq 5K. on bottom Tq 5.5K, P/U wt 165K, SIO wt 145K, Rot wt 155K. - AST 2.2 hrs, ART 3.24 hrs, ADT 5.44 hrs 11/7/2004 00:00 - 17:30 17.50 DRILL C PROD1 - Drill directional in 4 3/4" hole from 11527' to 12028'. - Drilling parameters: WOB 5 - 10K, 160 GPM, off bottom pressure 1850 psi, on bottom pressure 1900 - 2080 psi, 40 RPM, off bottom Tq SK, on bottom Tq 6K, P/U wt 165K, S/O wt 145K. Rot wt 160K. - AST 1.42 hrs. ART 7.88 hrs, ADT 9.3 hrs. 17:30 - 19:00 1.50 DRILL P PROD1 - CBU @ 180 GPM. 2030 psi, 40 RPM & reciprocating 70'. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A j-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: 11/7/2004 19:00 - 20:30 1.50 DRILL P PROD1 - Monitor well - static. - Wiper trip to 10,000'. Avg. drag 10K from 12028' to 11350'. Hole slick from 11350' to 10000'. Wiped 1 tight spot wI 30K drag @ 11692'. 20:30 - 21 :30 1.001 DRILL P PROD1 - RIH to 10317' below OH sidetrack @ 10220' & survey wI I MWD to confirm in new hole. POH to 10000' & RIH to 10317'. ! Repeat survey & confirm in new hole. 21 :30 - 22:30 1.00 DRILL P PROD1 - RIH to TD @ 12028' - S/O wt 140 - 145K. Hole slick. 22:30 - 00:00 1.50 DRILL P PROD1 - Pump 20 bbllow-vis weighted sweep followed by 20 bbl hi-vis sweep @ 180 GPM, 2050 psi, 40 RPM & reciprocating 70'. 11/8/2004 00:00 - 00:30 0.50 DRILL P PROD1 - Circ out sweeps 180 GPM, 2050 psi, 40 RPM & reciprocating 70'. - Sweeps brought back 10% excess sand @ B/U. 00:30 - 02:30 2.00 DRILL P PROD1 - POH from 12028' to 9280' - hole slick wI no drag. 02:30 - 04:00 1.50 DRILL P PROD1 - Shear open circ sub wi 3200 psi wI circ sub placed at 5 1/2" liner top. - Pump 40 bbl hi-vis sweep & circ surface to surface @ 340 GPM, 2080 psi. Minimal sand on B/U. 04:00 - 08:00 4.00 DRILL P PROD1 - Drop rabbit & POH to 3136'. 08:00 - 10:00 2.00 DRILL P PROD1 - Cut & slip 100' drilling line. - Adjust brakes. - Lubricate rig. 10:00 - 14:00 4.00 DRILL P PROD1 - C/O to 2 7/8" handling equip't. - POH w/2 7/8" DP - LID 66 singles & rack back 8 stands. 14:00 - 15:30 1.50 DRILL P PROD1 - Flushed, B/O & LID BHA. - 4 3/4" PDC bit grade - 2-1-BT-A-X-I-No-TD 15:30 - 17:30 2.00 CASE P RUNPRD - R/U 3 1/2" liner running equip't. - Change out & install new shock hose on # 1 mud pump. 17:30 - 18:00 0.50 CASE P RUNPRD - Test shock hose to 4100 psi. 18:00 - 18:30 0.50 CASE P RUNPRD - PJSM - for running 3 1/2" liner. 18:30 - 00:00 5.50 CASE P RUNPRD - M/U & run 63 of 69 jts 9.2# range 2 31/2" IBT-M liner. - Bakerloc shoe track its - pin end on jts 2,3, & 4. Fill & check floats - floats holding. M/U to oval wI 2100 to 2500 ftllbs Tq. using Best Of Life 2000 thread compound. One free floating centralizer per it. 11/9/2004 00:00 - 00:30 0.50 CASE P RUNPRD M/U & run jts 64 - 69 9.2# 3 1/2" IBT-M range 2 liner. M/U to oval wI 2100 - 2500 ftllbs Tq, using Best Of Life thread compound. Free floating centralizers on it 64,68, & 69. C/O to 2 7/8" handling equipment. 00:30 - 02:00 1.50 CASE P RUNPRD M/U liner hanger I packer & RIH on 8 stands 2 7/8" DP. CIO to 4" handling equipment & M/U 1 stand 4" DP. M/U headpin & hose. Circulate DP & liner vol x 3. Stage up pump & circ from 2 BPM to 6 BPM, 290 psi to 1000 psi. 02:00 - 07:30 5.50 CASE P RUNPRD RIH wI liner on 4" DP from 3123' to 7460' breaking circulation every 20 stands. 07:30 - 09:30 2.00 CASE P RUNPRD CBU at top of window, 4 bpm @ 1000 psi P/U 157k, 8/0 143k 09:30 - 12:00 2.50 CASE P RUNPRD Continue running 3-1/2" liner on 4" DP to 12,028' Printed: 11/22/2004 10:20:28 AM Legal Well Name: . Common Well Name: Event Name: Contractor Name: Rig Name: J-02A j-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 11/9/2004 09:30 - 12:00 2.50 CASE P RUNPRD P/U 178k, S/O 140k 12:00 - 13:30 1.50 CASE P RUNPRD MU cement head and lines. Staged up pumps, 2 bpm - 830 psi, I 3 bpm - 950 psi. Circulated Bottoms Up to Cool and Clean I I Hole. Held PJSM wI Rig Crew, Dowell and Truck Drivers. I Dowell Batched Up 35 bbls of Cement. 13:30 - 13:451 I 0.251 CEMT P RUNPRD Air up and prime up cementers. Switch to Schlumberger, pump I 10 bbls water to fill lines. Test cement lines to 4,000 psi. 13:45 - 14:00 0.25 i CEMT P RUNPRD Pump 10 bbls pre-flush followed by 15 bbls9.5 ppg mud push. i 0.251 CEMT 2.5 bpm @ 900 psi. 14:00 - 14:15 P RUNPRD Pumped 35 bbls (170 sxs) 15.8 ppg Class "G" Latex Cement. I IPR 3 bpm - 900 psi, FPR 3.5 bpm - 425 psi. 14:15 - 14:45 0.50 CEMT P RUNPRD Washed Up Lines, Dropped Drill Pipe Dart and Pumped Out wI 5 bbls Water, 4 bpm 200 psi. Switched to rig pumpx and displaced cement with 40 bbls Perf Pill, 70 bbls mud. IPR 6 bpm - 940 psi, Slowed rate to 2 bpm for the last 20 bbls. Able to reciprocate the liner throughout the cement job. Bumped plug. Total Displacement 115.7 bbls. Pressured up to 3.000 psi to set hanger and release running tool from liner. Stacked 75,000# on hanger to ensure hanger set. Bleed pressure and check floats. CIP @ 14:45 hrs. 14:45 - 15:00 0.25 CASE P RUNPRD Pressure up to 1,000 psi and PU on DP, increased to 1,500 psi, pressure bled off indicating running tool released from liner. 15:00 - 15:30 0.50 CASE P RUNPRD Circulate 50 bbls, 8 bpm @ 1630 psi, to move excess cement up hole. Set down 30k on ZXP packer observed ZXP Packer set, PU rotating at 10 rpm. RIH and stack out 30k on packer to verify it set. PU and CBU to clean excess cement out of hole, 12 bpm @ 3300 psi. 8 bbls cement to surface. 15:30 - 16:30 1.00 CEMT P RUNPRD Break out and RD cement head and lines 16:30 - 17:30 1.00 CASE P RUNPRD Displace well to clean seawater, 12 bpm @ 3500 psi 17:30 - 22:00 4.50 CASE P RUNPRD Monitor well and POH to perforate. 22:00 - 22:30 0.50 CASE P RUNPRD Clean and clear rig floor 22:30 - 23:30 1.00 CASE P RUNPRD Pressure 7" X 5-1/2" X 3-1/2" casing to 3500 psi for 30 minutes. 23:30 - 00:00 0.50 PERFO P OTHCMP RU 2-1/16" handling equipment. 11/10/2004 00:00 - 01 :00 1.00 PERFO P OTHCMP RU to PU and MU 2" perf guns 01 :00 - 01 :30 0.50 PERFO P OTHCMP PJSM with Schlumberger and all rig crews on picking up and running DPC perf guns. 01 :30 - 04:00 2.50 PERFO P OTHCMP MU DPC 2" perf guns, firing head and ported sub, RIH. 04:00 - 06:30 2.50 PERFO P OTHCMP RIH with DPC perf guns picking up 39 jts of 2-1/16" DP from pipe shed and 8 stands of 2-7/8" DP from derrick. 06:30 - 10:30 4.00 PERFO P OTHCMP Continue RIH with 4" DP. Taking weight at 10829'. 10:30 - 12:00 1.50 PERFO N DPRB OTHCMP Attempt to work through obstruction at 10829'. PU slowly and rotate drill string 3 turns, RIH and stack out at 10829'. Work torque down, rotate addition 2 turns and work torque down, still unable to RIH past 10829' 12:00 - 15:00 3.00 PERFO N DPRB OTHCMP POH with unfired perf guns to make clean-out run, standing back 4" DP 15:00 - 17:30 2.50 PERFO N DPRB OTHCMP POH standing back 2-7/8" DP and laying down 2-1/16" DP Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: 11/10/2004 17:30 - 18:00 0.50 PERFOJ N DPRB OTHCMP PJSM with Schlumberger and all rig personnel on breaking out and laying down un-fired perf guns. 18:00 - 19:30 1.50 PERFO N DPRB OTHCMP LD perf guns 19:30 - 20:00 0.50 CLEAN IN DPRB CLEAN Clean and clear rig floor. Load clean-out BHA on rig floor. 20:00 - 20:30 0.50 CLEAN iN DPRB CLEAN PJSM with Baker and all rig personnel on PU and MU clean-out i BHA. I 20:30 - 21 :30 1.00 CLEAN iN DPRB CLEAN PU BHA #11,2.78" clean-out assembly 21 :30 - 00:00 2.50 CLEAN iN DPRB CLEAN RI H with clean-out assembly picking up 71 jts of 2-1/16" DP from pipe shed 11/11/2004 00:00 - 00:30 0.50 CLEAN N DPRB CLEAN MU crossovers and RIH with 2-7/8" DP 00:30 - 01 :00 0.50 CLEAN N DPRB CLEAN CO elevators. MU head pin, fill DP and break circulation. 1.7 bpm @ 730 psi. 01 :00 - 06:30 5.50 CLEAN N DPRB CLEAN Continue RIH with clean-out assy, fill DP and break circulation every 30 stands. 06:30 - 18:30 12.00 CLEAN N DPRB CLEAN Tag up @ 10712'. Clean wellbore from 10712' to 10863'. Unable to maintain differential pressure, suspected motor failure, decision made to trip for new motor and 2-3/4" PDC bit. P/U 155 klbs, SIO 145 klbs 1.7 bpm @ 820 psi 18:30 - 19:30 1.00 CLEAN N DPRB CLEAN Drop ball and open 2-1/16" circ sub. Circulate 100 bls at max rate to clean-out 3-1/2" liner. 3.4 bpm @ 2000 psi 19:30 - 00:00 4.50 CLEAN N DPRB CLEAN POH, standing 4" DP back. 11/12/2004 00:00 - 04:00 4.00 CLEAN N DPRB CLEAN Continue POH standing back 2-7/8" dp and laying down 71 jts of 2-1/16" DP. 04:00 - 05:00 1.00 CLEAN N DPRB CLEAN Pick up and MU new 2-1/8" Extreme motor with HTC PDC bit. 05:00 - 05:30 0.50 CLEAN N DPRB CLEAN Rig service 05:30 - 09:30 4.00 CLEAN N IDPRB CLEAN RIH to clean-out 3-1/2" liner picking up 71 jts 2-1/16" DP from I pipe shed and 8 stands 2-7/8" DP from derrick. 09:30 - 10:00 0.50 CLEAN N IDPRB CLEAN CO elevators and MU head pin.Fill DP and break circulation. 1.5 bpm @ 680 psi 10:00 - 13:30 3.50 CLEAN N DPRB CLEAN Continue RIH with clean out assy on 4" DP. 13:30 - 15:00 1.50 CLEAN N DPRB CLEAN Attempt to break circulation, pressure up to 1000 psi with no returns. Pull 20 stands and attempt to break circulation again, pressured up to 1270 psi then dropped to 500 with returns. Able to circulate at 1.7 bpm with 700 psi. 15:00 - 18:00 3.00 CLEAN N DPRB CLEAN Continue RIH, filling DP and breaking circulation every 20 stands. 18:00 - 00:00 6.00 CLEAN N DPRB CLEAN Clean-out well bore from 10863' to 11304', maintaining differential pressure between 100 to 150 psi. 1.5 bpm @ 820 psi WOB - 1000 Ibs DH RPM = 600 P/U 158 klbs S/O 140 klbs 11/13/2004 00:00 - 09:00 9.00 CLEAN N DPRB CLEAN Clean-out wellbore from 11,304' to 11,928'. Pump Rate 1.7 bpm, 860 psi, WOB - 1,000#, DH RPM 600. Washed and Reamed with Differential Pressure. Maintained Differential Pressure Between 150 to 200 psi. String Weight Up 158,000#, String Weight Down 140,000#. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: j-02A j-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/16/2004 11/17/2004 Spud Date: 9/24/1969 End: 11/13/2004 00:00 - 09:00 9.00 CLEAN N DPRB CLEAN NOTE: Observed Large Volume of Cement Contaminated Perf Pill from Displacement Over Shakers While Washing and Reaming Out Cement. 09:00 - 09:30 0.50 CLEAN N DPRB CLEAN Pumped and Circulated at 11,928 to Clean Out 3-1/2" liner. Pump Rate 1.5 bpm, 820 psi. NOTE: Continued to Observe Cement Contaminated Perf Pill from Displacement Over Shakers While Circulating. Circulated Until Returns Over Shaker Cleaned Up. 09:30 - 11 :00 1 .50 CLEAN N DPRB CLEAN POOH from 11,928' to 9,747' to Clear 3-1/2" Liner wI Bit. 11 :00 - 12:00 1.00 CLEAN N DPRB CLEAN Held PJSM. M I U Circulating Head and Lines. Closed Pipe Rams and Pressured Up 3-1/2" Liner to 3,500 psi, Held f/10 minutes. Bled Down Pressure, Opened Pipe Rams, RID and BID Lines and Circulating Head. 12:00 - 13:00 1.00 CLEAN N DPRB CLEAN RIH from 9,747' to 11,928' Without Problems. 13:00 - 14:30 1.50 CLEAN N DPRB CLEAN Dropped Ball to Open Lower Circulation Sub, Pump Rate 1.7 bpm, 800 psi. Pumped 100 bbls, Did Not Observe Circulation Sub Open. Pressure Increased to 3,000 psi, Lost Returns. Circulating Sub Pinned to Shear at 2,200 psi. String Weight Up Increased to 190,000#. Worked Drill String and Cycled Pump, DPRB I CLEAN Regained Slight Circulation wI 2 bpm 2,500 psi. 14:30 - 17:30 3.00 CLEAN N Pumped Out of the Hole from 11,928' to 11,640', ICP 2 bpm, 2,500 psi, FCP 2 bpm 1,050 psi. Encountered 25,000# Overpull at 11,640', Pump Rate 2 bpm, Pressure Increased to 3,000 psi, Lost Returns. Worked Drill String and Cycled Pump, Regained Circulation, Pump Rate 1.7 bpm, 1,500 psi. Continued to Work Drill String and Staged Up Pump Rate as Pressure Decreased. Pumped Out of the Hole from 11,640' to 9,746'. Pump Rate 5 bpm, 2,000 psi. 17:30 - 20:00 2.50 CLEAN N DPRB CLEAN Placed Lower Circulating Sub at Top of 3-1/2" Liner at 9,770'. Circulated Bottoms Up, Pump Rate 6 bpm, 3,250 psi. Pumped and Circulated Around 20 bbl Sweep, Pump rate 6 bpm, 3,250 psi. NOTE: First Bottoms Up Brought Back Large Amount of Cement Cuttings and Cement Contaminated Perf Pill. 20:00 - 20:30 0.50 CLEAN N DPRB CLEAN Dropped Ball to Open Upper Circulation Sub, Upper Circulation Sub at 7,610'. Pump Rate 3 bpm, 900 psi, Pressure Increased to 1,600 psi, Circulation Sub Sheared Open, Increased Pump Rate to 7.5 bpm, 910 psi. Pumped and Circulated Around 20 bbl Sweep. 20:30 - 23:00 2.50 CLEAN N DPRB CLEAN POOH from 9,746' to 2,940'. 23:00 - 00:00 1.00 CLEAN N DPRB CLEAN C I 0 Handling Equipment, POOH, Racked Back 8 stands of 2-7/8" DP. 11114/2004 00:00 - 03:00 3.00 CLEAN N DPRB CLEAN PJSM, C I 0 Handling Equipment, POOH, Broke Out and LID 71 Joints 2-1/16" DP. 03:00 - 03:30 0.50 CLEAN N DPRB CLEAN Flushed, Broke Out and LID Clean Out BHA. 03:30 - 04:00 0.50 CLEAN N DPRB CLEAN Cleared and Cleaned Rig Floor. 04:00 - 04:30 0.50 PERFO N DPRB OTHCMP Held PJSM wI Schlumberger and Rig Crew on Picking Up and Running DPC Perforating Guns. 04:30 - 05:00 0.50 N DPRB OTHCMP R I U Handling Equipment f/ DPC Perforating Guns. 05:00 - 07:00 2.00 N DPRB OTHCMP M I U and RIH wI DPC Perforating Guns. Total Length of Loaded Guns 825', Total Length of Blanks 454.17'. Total Length of Guns and Blanks 1,279.17'. 07:00 - 08:30 DPRB OTHCMP CIO handling equipment, PIU and RIH with 39 jts 2-1/16" DP. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/14/2004 I' 07:00 - 08:30 08:30 - 13:00 I '13:00 - 13:30 ! 13:30 - 14:00 114:00 - 14:30 i 14:30 - 15:00 15:00 - 16:30 11/15/2004 116:30 - 18:30 118:30 - 19:30 i 19:30 - 23:00 123:00 - 23:30 t 23:30 - 00:00 II' 00:00 - 04:00 04:00 - 04:30 104:30 - 05:30 105:30 - 06:00 I I 06:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:00 j-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 0.50 0.50 0.50 2.00 1.00 4.00 0.50 0.50 4.50 0.50 PERFO 1.00 BOPSU 3.00 BOPSU 0.50 BOPSU 1.00 RUNCO Start: Rig Release: Rig Number: Spud Date: 9/24/1969 End: 9/16/2004 11/17/2004 C/O handling equipment and RIH with 8 stands of 2-7/8" DP. Continue RIH with perf guns on 4" DP. Tag up at 11928'. OTHCMP I P/U 190k Ibs S/O 133k Ibs 'Space out DP to perforate 10658' to 11928'. MU TIW and head pin. PJSM with Schlumberger and rig personnel on firing perf guns. Pressure up to 1000 psi and check for leaks. Continue pressuring up to 3100 psi, held pressure for 4 minutes. Bled pressure, guns fired at 8 minutes 20 seconds with corresponding fluid drop. POH from 11928' to 10498' CBU, 5 bpm @ 1350 psi. 10 bbls fluid lost while circulating. Monitored well fluid, level dropping. Pumped dry job and blew down lines. OTHCMP OTHCMP OTHCMP OTHCMP 1 bbl/hr estimated static loss rate. OTHCMP POH laying down 4 in DP from 10498' to 9032' OTHCMP Service rig, inspect brakes and linkage. Cut and slip 99' of drill line. OTHCMP Continue POH laying down 4 in DP from 9032' to 4711' OTHCMP RIH with 18 stands out of derrick. OTHCMP I Continue POH laying down 4 in DP from 6435 to 6116. I Monitoring hole fill, losses averaging 2.5 bph on trip out. OTHCMP Continue POH laying down 4 in DP from 6116' to 3430' OTHCMP C/O handling equipment and Continue POH laying down 2-7/8" DP from 3430' to 2660' OTHCMP C/O handling equipment and Continue POH laying down 2-1/16" DP from 2660' to 1280' OTHCMP PJSM with Schlumberger and all rig personnel on breaking out and laying down perf guns. OTHCMP C/O handling equipment, break out and LD perf guns. All guns fired. Charge information: 2" PowerJet charges loaded at 6 spf, 60 degree phase with random orientation. Intervals Perforated: 10678' to 10948' 10978' to 11098' 11328' to 11428' 11508' to 11608' 11648' to 11808' 11853' to 11928' OTHCMP Clean and clear rig floor. RUNCMP RU BOPE test equipment. Pull wear bushing. RUNCMP Pressure test BOPE, 3500/250 psi for 5 minutes. Witness of BOP test waived by Chuck Sheave with AOGCC. RUNCMP Rig down BOPE test equipment. RUNCMP RU compensator, tubing tongs and torque turn equipment. RU handling equipment to run 4-1/2",12.6#, 13Cr80, VAM Top completion. RUNCMP PJSM with Baker, Doyon Casing and all rig personnel on picking up and running 4-1/2" completion. Printed: 11/22/2004 10:20:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/15/2004 J-02A J-02A REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 From -To I 17:00 - OO:oot I I I I I I 00:00 - 09:30 I I i 09:30 - 11 :00 I Start: 9/16/2004 Rig Release: 11/17/2004 Rig Number: Spud Date: 9/24/1969 End: 11:00 -12:00 1.00 RUN 4-1/2", 12.6#, 13Cr80, VAM Top completion. Pick up jts with compensator, torque turn each joint, make-up torque 4440 ftlbs 1.50 Midnight depth: 3470' RUNCMP Continue running 4-1/2", 12.6#, 13Cr80, VAM Top completion. Pick up jts with compensator, torque turn each joint, make-up torque 4440 ftlbs RUNCMP Space out and land tubing at 9108.9',3.9' inside 5-1/2" liner top packer tie-back sleeve. RUNCMP RU to circulate seawater. Take 1 bbl Corexit onto vac truck with 150 bbls seawater. RUNCMP PJSM with Veco, MI and all rig personnel on circulating seawater and handling corrosion inhibited seawater. RUNCMP Displace 7" X 4-1/2" IA with 150 bbls corrosion inhibited seawater. RUNCMP Drop rod and ball assembly and allow to fall onto seat. Pressure up tbg to 3500 to set packer. Hold 3500 psi on tbg for 30 minutes to test tbg. Bleed tbg pressure to 1500 psi. Pressure up on 7" X 4-1/2" IA to 3500 psi, hold pressure for 30 minute test. Bleed both tbg and IA pressure to O. RUNCMP Pressure up the 7" X 4-1/2" lA, DCK valve sheared at 2300 psi. Circulate the DCK both ways to ensure it is free of obstructions. 11/16/2004 12:00 - 12:30 12:30 - 13:00 0.50 13:00 - 15:00 2.00 15:00 - 15:30 15:30 - 16:30 RUNCMP 16:30 - 19:00 2.50 BOPSU P RUNCMP 19:00 - 22:00 3.00 WHSUR P RUNCMP 22:00 - 22:30 0.50 WHSUR P RUNCMP 22:30 - 23:00 0.50 WHSUR P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP 11/17/2004 00:00 - 01 :00 1.00 WHSUR P RUNCMP 01 :00 - 02:00 1.00 WHSUR P RUNCMP 02:00 - 04:00 2.00 WHSUR P RUNCMP 04:00 - 05:00 1.00 WHSUR P RUNCMP Reverse circulate 2.1 bpm @ 900 psi and 2.1 bpm @ 630 psi circulating through the tbg. Blow down lines and LD the landing jt. Set TWC valve and test from below to 1000 psi. Clean drip pan and cellar. ND BOPE. NU adapter flange and tree Pressure test tbg hanger, adapter flange and tree to 5000 psi. PJSM, RU DSM lubricator and pull TWC PJSM, RU Little Red, pressure test lines to 1000 psi. Reverse circulate 75 bbls diesel to freeze protect well to 2200'. Continue reverse circulate 75 bbls diesel to freeze protect well to 2200. RD Little Red. Allow well to U-tube. Set BPV, test to 1000 psi from below. Install VR plug in tbg spool outlet Move rig forward to allow room for a VR plug to be installed in the front tbg spool outlet. Secure cellar. RIG RELEASED AT 05:00 Printed: 11/22/2004 10:20:28 AM J-028 Survey Report Schlumberger Report Date: November 30,2004 Client: BP Exploration (Alaska) Field: Prudhoe Bay Unit - WOA Structure I Slot: J-PAD 1 J-02 Well: J-02 Borehole: J-02B UWIIAPI#: 500292002302 Survey Name I Date: J-02B 1 November 7,2004 Tort I AHD I DDII ERD ratio: 343.861· /5950.91 ft 16.436/ 0.660 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32626499, W 148.83939503 Location Grid N/E YIX: N 5970265.490 ftUS, E 643113.790 ftUS Grid Convergence Angle: +1.09287160· Grid Scale Factor: 0.99992327 Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 96.280· Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 63.39 ft relative to MSL Sea Bed I Ground Level Elevation: 37.80 ft relative to MSL Magnetic Declination: 24.941· Total Field Strength: 57615.173 nT Magnetic Dip: 80.847" Declination Date: November 07,2004 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North·> True North: +24.941· Local Coordinates Referenced To: Well Head . Comments Longitude Latitude N 70.32626499 W 148.83939503 N 70.32626499 W 148.83939503 GYD CT CMS N 70.32626421 W 148.83939500 N 70.32626316 W 148.83939580 N 70.32626269 W 148.83939569 406.09 0.40 190.61 342.70 406.09 0.11 1.35 1.26 -1.26 -0.03 0.37 5970264.23 643113.79 N 70.32626154 W 148.83939526 506.09 0.57 189.57 442.69 506.08 0.05 2.20 2.10 -2.10 -0.18 0.17 5970263.39 643113.65 N 70.32625927 W 148.83939646 606.09 0.47 199.75 542.69 606.08 -0.07 3.10 3.00 -2.97 -0.40 0.14 5970262.51 643113.45 N 70.32625687 W 148.83939825 706.09 0.44 181.97 642.69 706.08 -0.14 3.89 3.78 -3.74 -0.55 0.14 5970261.74 643113.31 N 70.32625477 W 148.83939948 806.09 0.30 159.49 742.68 806.07 0.01 4.53 4.40 -4.37 -0.47 0.20 5970261.11 643113.40 N 70.32625305 W 148.83939884 906.09 0.14 310.55 842.68 906.07 0.03 4.76 4.56 -4.54 -0.47 0.43 5970260.95 643113.41 N 70.32625260 W 148.8.5 1006.09 0.14 167.22 942.68 1006.07 -0.03 4.91 4.61 -4.58 -0.54 0.27 5970260.90 643113.34 N 70.32625249 W 148.83 9 1106.09 0.12 15.28 1042.68 1106.07 0.02 5.04 4.62 -4.60 -0.48 0.25 5970260.89 643113.40 N 70.32625244 W 148.83939894 1206.09 0.15 14.87 1142.68 1206.07 0.06 5.27 4.39 -4.37 -0.42 0.03 5970261.12 643113.45 N 70.32625306 W 148.83939845 1306.09 0.16 . 1.16 1242.68 1306.07 0.07 5.54 4.12 -4.10 -0.38 0.04 5970261.38 643113.48 N 70.32625379 W 148.83939815 1406.09 0.15 164.25 1342.68 1406.07 0.10 5.69 4.10 -4.09 -0.35 0.31 5970261.40 643113.52 N 70.32625383 W 148.83939784 1506.09 0.20 53.26 1442.68 1506.07 0.28 5.91 4.11 -4.11 -0.17 0.29 5970261.38 643113.70 N 70.32625377 W 148.83939642 1606.09 0.32 35.00 1542.68 1606.07 0.54 6.36 3.78 -3.78 0.13 0.14 5970261.72 643113.99 N 70.32625468 W 148.83939399 1706.09 0.22 2.73 1642.68 1706.07 0.66 6.82 3.37 -3.36 0.30 0.18 5970262.14 643114.15 N 70.32625583 W 148.83939261 1806.09 0.19 87.88 1742.68 1806.07 0.82 7.12 3.19 -3.16 0.47 0.28 5970262.34 643114.32 N 70.32625637 W 148.83939120 1906.09 0.12 280.68 1842.68 1906.07 0.88 7.26 3.18 -3.13 0.54 0.31 5970262.37 643114.39 N 70.32625644 W 148.83939069 2006.09 1.03 128.46 1942.68 2006.07 1.53 8.10 3.84 -3.67 1.14 1.14 5970261.84 643115.00 N 70.32625496 W 148.83938581 2106.09 5.27 131.84 2042.50 2105.89 6.03 13.59 9.00 -7.30 5.26 4.24 5970258.30 643119.19 N 70.32624506 W 148.83935235 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02B\J-02B Generated 12/7/20046:48 AM Page 1 of? Comments Latitude Longitude N 70.32622855 W 148.83928014 N 70.32621058 W 148.83918229 2406.09 9.90 117.26 2339.66 2403.05 43.22 54.22 48.90 -27.45 40.46 1.29 5970238.81 643154.77 N 70.32618999 W 148.83906694 2456.09 10.44 117.12 2388.87 2452.26 51.4 7 63.05 57.67 -31.49 48.32 1.08 5970234.93 643162.69 N 70.32617897 W 148.83900327 2506.09 11.48 116.76 2437.96 2501.35 60.37 72.55 67.13 -35.79 56.79 2.08 5970230.79 643171.25 N 70.32616721 W 148.83893455 2556.09 11.98 117.18 2486.91 2550.30 69.87 82.72 77.26 -40.40 65.85 1.01 5970226.35 643180.39 N 70.32615461 W 148.83886109 2606.09 12.86 117.38 2535.74 2599.13 79.91 93.47 87.99 -45.33 75.41 1.76 5970221.61 643190.04 N 70.32614114 W 148.83878360 2656.09 13.97 117.75 2584.38 2647.77 90.72 105.07 99.57 -50.70 85.69 2.23 5970216.43 643200.42 N 70.32612648 W 148.83870023 2706.09 14.86 117.78 2632.80 2696.19 102.30 117.52 112.00 -56.50 96.70 1.78 5970210.85 643211.55 N 70.32611063 W 148.83861092 2756.09 15.80 117.72 2681.02 2744.41 114.61 130.74 125.21 -62.66 1 08.40 1.88 5970204.92 643223.36 N 70.32609382 W 148.83851607 2806.09 16.37 118.44 2729.06 2792.45 127.47 144.59 139.05 -69.18 120.62 1.21 5970198.63 643235.70 N 70.32607600 W 148.83_ 2856.09 17.45 119.05 2776.90 2840.29 140.91 159.13 153.59 -76.17 133.37 2.19 5970191.88 643248.58 N 70.32605689 W 148.83 2906.09 18.53 119.09 2824.46 2887.85 155.14 174.58 169.04 -83.68 146.87 2.16 5970184.64 643262.22 N 70.32603639 W 148.83820416 2956.09 19.66 119.50 2871.71 2935.10 170.20 190.93 185.39 -91.68 161.13 2.28 5970176.90 643276.63 N 70.32601452 W 148.83808850 3006.09 20.52 118.99 2918.66 2982.05 186.01 208.11 202.57 -100.07 176.12 1.76 5970168.80 643291.77 N 70.32599160 W 148.83796699 3056.09 21.76 119.09 2965.30 3028.69 202.64 226.14 220.60 -108.82 191.89 2.48 5970160.35 643307.70 N 70.32596769 W 148.83783917 3106.09 23.06 119.36 3011.52 3074.91 220.19 245.20 239.66 -118.13 208.52 2.61 5970151.37 643324.51 N 70.32594226 W 148.83770430 3156.09 24.09 119.58 3057.35 3120.74 238.57 265.20 259.65 -127.97 225.93 2.07 5970141.86 643342.10 N 70.32591538 W 148.83756314 3206.09 25.20 119.86 3102.79 3166.18 257.70 286.05 280.50 -138.31 244.04 2.23 5970131.87 643360.40 N 70.32588714 W 148.83741633 3256.09 26.77 120.38 3147.73 3211.12 277.74 307.95 302.41 -149.30 262.98 3.17 5970121.24 643379.55 N 70.32585710 W 148.83726271 3306.09 28.21 120.88 3192.09 3255.48 298.76 331.03 325.48 -161.06 282.84 2.92 5970109.86 643399.63 N 70.32582497 W 148.83710170 3356.09 29.56 121.33 3235.87 3299.26 320.68 355.18 349.63 -173.54 303.52 2.73 5970097.78 643420.54 N 70.32579087 W 148.83693404 3406.09 30.97 121.35 3279.05 3342.44 343.51 380.38 374.82 -186.65 325.04 2.82 5970085.09 643442.31 N 70.32575506 W 148.83675953 3456.09 32.53 121.57 3321.57 3384.96 367.32 406.69 401.12 -200.38 347.48 3.13 5970071.79 643465.00 N 70.32571755 W 148.83657758 3506.09 33.08 121.36 3363.59 3426.98 391.83 433.78 428.20 -214.52 370.59 1.12 5970058.09 643488.37 N 70.32567891 W 148.83639024 3556.09 33.06 121.36 3405.49 3468.88 416.54 461.07 455.48 -228.72 393.89 0.04 5970044.34 643511.94 N 70.32564012 W 148.83620134 3606.09 32.71 121.73 3447.48 3510.87 441.09 488.21 482.62 -242.92 417.02 0.81 5970030.58 643535.34 N 70.32560132 W 148.83601376 3656.09 32.55 121.55 3489.59 3552.98 465.45 515.17 509.57 -257.07 439.98 0.37 5970016.88 643558.55 N 70.32556268 W 148.8.5 3706.09 31.44 122.00 3531.99 3595.38 489.37 541.66 536.05 -271.01 462.50 2.27 5970003.37 643581.34 N 70.32552457 W 148.8 5 3756.09 30.80 121.15 3574.80 3638.19 512.73 567.51 561.89 -284.55 484.51 1.55 5969990.26 643603.60 N 70.32548760 W 148.83 6 3806.09 29.99 121.21 3617.93 3681.32 535.68 592.80 587.18 -297.64 506.15 1.62 5969977.58 643625.49 N 70.32545181 W 148.83529108 3856.09 30.03 121.19 3661.22 3724.61 558.36 617.81 612.19 -310.60 527.55 0.08 5969965.03 643647.12 N 70.32541642 W 148.83511765 3906.09 30.20 120.78 3704.47 3767.86 581.15 642.90 637.27 -323.51 549.05 0.53 5969952.53 643668.87 N 70.32538113 W 148.83494328 3956.09 30.26 121.39 3747.67 3811.06 604.00 668.07 662.45 -336.51 570.61 0.63 5969939.95 643690.67 N 70.32534562 W 148.83476849 4006.09 30.68 121.19 3790.77 3854.16 626.97 693.43 687.80 -349.68 592.28 0.86 5969927.20 643712.58 N 70.32530964 W 148.83459283 4056.09 30.93 121.13 3833.71 3897.10 650.20 719.03 713.40 -362.93 614.19 0.50 5969914.37 643734.74 N 70.32527344 W 148.83441517 4106.09 31.40 121.44 3876.50 3939.89 673.65 744.91 739.28 -376.36 636.30 0.99 5969901.36 643757.10 N 70.32523672 W 148.83423590 4156.09 31.69 121.55 3919.11 3982.50 697.32 771.07 765.43 -390.03 658.61 0.59 5969888.12 643779.66 N 70.32519939 W 148.83405506 4206.09 31.84 121.44 3961.62 4025.01 721.13 797.39 791.75 -403.78 681.05 0.32 5969874.80 643802.36 N 70.32516181 W 148.83387309 4256.09 32.06 121.65 4004.05 4067.44 745.06 823.85 818.21 -417.62 703.60 0.49 5969861.39 643825.17 N 70.32512399 W 148.83369027 4306.09 32.30 122.04 4046.37 4109.76 769.08 850.47 844.83 -431.67 726.22 0.63 5969847.78 643848.05 N 70.32508560 W 148.83350688 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02B\J-02B Generated 12/7/20046:48 AM Page 2 of 7 Comments Latitude Longitude N 70.32504672 W 148.83332278 4406.09 32.68 121.82 4130.70 4194.09 817.49 904.21 898.55 -460.17 771.78 0.45 5969820.16 643894.15 N 70.32500775 W 148.83313749 4456.09 32.41 118.66 4172.85 4236.24 842.06 931.11 925.44 -473.71 795.01 3.44 5969807.06 643917.63 N 70.32497074 W 148.83294916 4506.09 31.64 116.34 4215.24 4278.63 866.77 957.62 951.91 -485.96 818.52 2.90 5969795.27 643941.37 N 70.32493728 W 148.83275854 4556.09 31.44 116.50 4257.86 4321.25 891.32 983.77 977.99 -497.59 841.95 0.43 5969784.08 643965.01 N 70.32490548 W 148.83256864 4606.09 31.04 115.60 4300.61 4364.00 915.73 1009.70 1003.85 -508.98 865.24 1.23 5969773.14 643988.51 N 70.32487436 W 148.83237977 4656.09 31.17 115.99 4343.42 4406.81 940.07 1035.53 1029.59 -520.22 888.50 0.48 5969762.35 644011.98 N 70.32484364 W 148.83219122 4706.09 32.10 115.84 4385.99 4449.38 964.77 1061.76 1055.74 -531.68 912.09 1.87 5969751.34 644035.78 N 70.32481233 W 148.83199998 4756.09 33.23 115.92 4428.08 4491.47 990.19 1088.74 1082.65 -543.46 936.37 2.26 5969740.03 644060.28 N 70.32478014 W 148.83180314 4806.09 34.16 116.16 4469.68 4533.07 1016.30 1116.48 1110.32 -555.64 961.29 1.88 5969728.33 644085.42 N 70.32474686 W 148.83160109 4856.09 33.95 116.98 4511.10 4574.49 1042.56 1144.48 1138.27 -568.16 986.33 1.01 5969716.28 644110.70 N 70.32471264 W 148.83.7 4906.09 33.80 117.25 4552.62 4616.01 1068.61 1172.35 1166.11 -580.87 1011.14 0.42 5969704.06 644135.74 N 70.32467793 W 148.831 96 4956.09 33.77 117.38 4594.17 4657.56 1094.56 1200.15 1193.88 -593.62 1035.84 0.16 5969691 .78 644160.68 N 70.32464307 W 148.83099668 5006.09 34.19 117.37 4635.64 4699.03 1120.63 1228.10 1221.80 -606.4 7 1060.66 0.84 5969679.40 644185.74 N 70.32460795 W 148.83079550 5056.09 34.29 118.05 4676.97 4740.36 1146.82 1256.23 1249.92 -619.56 1085.56 0.79 5969666.80 644210.88 N 70.32457220 W 148.83059358 5106.09 33.93 117.89 4718.37 4781.76 1172.87 1284.27 1277.94 -632.71 1110.33 0.74 5969654.12 644235.89 N 70.32453627 W 148.83039282 5156.09 33.85 118.72 4759.87 4823.26 1198.72 1312.15 1305.82 -645.93 1134.87 0.94 5969641.38 644260.68 N 70.32450014 W 148.83019382 5206.09 33.62 119.36 4801.45 4864.84 1224.32 1339.92 1333.58 -659.40 1159.15 0.85 5969628.36 644285.21 N 70.32446331 W 148.82999701 5256.09 33.85 118.96 4843.04 4906.43 1249.91 1367.69 1361.35 -672.93 1183.40 0.64 5969615.30 644309.71 N 70.32442634 W 148.82980043 5306.09 34.10 119.68 4884.50 4947.89 1275.62 1395.63 1389.29 -686.62 1207.76 0.95 5969602.09 644334.33 N 70.32438895 W 148.82960293 5356.09 34.50 119.53 4925.80 4989.19 1301.49 1423.80 1417.46 -700.54 1232.26 0.82 5969588.64 644359.09 N 70.32435091 W 148.82940433 5406.09 34.44 119.90 4967.03 5030.42 1327.46 1452.10 1445.76 -714.56 1256.83 0.44 5969575.08 644383.92 N 70.32431258 W 148.82920508 5456.09 34.24 119.45 5008.31 5071.70 1353.34 1480.31 1473.97 -728.53 1281.34 0.65 5969561.59 644408.69 N 70.32427442 W 148.82900642 5506.09 33.81 119.89 5049.75 5113.14 1379.02 1508.28 1501.95 -742.38 1305.65 0.99 5969548.21 644433.26 N 70.32423658 W 148.82880934 5556.09 33.59 120.23 5091.35 5154.74 1404.41 1536.03 1529.69 -756.27 1329.66 0.58 5969534.77 644457.53 N 70.32419860 W 148.82861469 5606.09 33.09 120.41 5133.12 5196.51 1429.50 1563.51 1557.17 -770.14 1353.38 1.02 5969521.36 644481.51 N 70.32416069 W 148.82842239 5656.09 33.04 120.11 5175.02 5238.41 1454.43 1590.79 1584.44 -783.89 1376.94 0.34 5969508.06 644505.33 N 70.32412313 W 148.82823137 5706.09 32.97 120.82 5216.95 5280.34 1479.27 1618.02 1611.68 -797.70 1400.42 0.79 5969494.71 644529.06 N 70.32408539 W 148.8.7 5756.09 32.75 121.24 5258.95 5322.34 1503.91 1645.15 1638.80 -811.68 1423.67 0.63 5969481.17 644552.57 N 70.32404717 W 148.8 1 5806.09 32.74 121.41 5301.01 5364.40 1528.41 1672.20 1665.83 -825.74 1446.77 0.18 5969467.55 644575.93 N 70.32400875 W 148.82 . 3 5856.09 31.66 120.32 5343.32 5406.71 1552.64 1698.84 1692.47 -839.42 1469.64 2.45 5969454.32 644599.05 N 70.32397139 W 148.82747995 5906.09 31.26 121.69 5385.97 5449.36 1576.34 1724.93 1718.56 -852.86 1492.00 1.64 5969441.31 644621.67 N 70.32393466 W 148.82729864 5956.09 31.48 121.60 5428.66 5492.05 1599.86 1750.96 1744.57 -866.51 1514.16 0.45 5969428.08 644644.08 N 70.32389734 W 148.82711901 6006.09 31.85 121.88 5471.22 5534.61 1623.56 1777.21 1770.80 -880.32 1536.48 0.80 5969414.70 644666.66 N 70.32385961 W 148.82693806 6056.09 32.46 120.93 5513.55 5576.94 1647.65 1803.82 1797.40 -894.18 1559.20 1.58 5969401.28 644689.63 N 70.32382172 W 148.82675395 6106.09 32.48 121.80 5555.73 5619.12 1671.96 1830.66 1824.23 -908.15 1582.12 0.93 5969387.75 644712.81 N 70.32378354 W 148.82656815 6156.09 32.25 121.31 5597.96 5661.35 1696.16 1857.43 1850.99 -922.16 1604.92 0.70 5969374.18 644735.88 N 70.32374526 W 148.82638326 6206.09 32.56 121.44 5640.18 5703.57 1720.43 1884.22 1877.77 -936.11 1627.80 0.64 5969360.67 644759.02 N 70.32370713 W 148.82619782 6256.09 32.94 121.98 5682.23 5745.62 1744.86 1911.27 1904.81 -950.33 1650.81 0.96 5969346.89 644782.29 N 70.32366828 W 148.82601129 6306.09 33.23 122.82 5724.12 5787.51 1769.36 1938.56 1932.08 -964.96 1673.85 1.09 5969332.71 644805.61 N 70.32362831 W 148.82582449 6356.09 34.23 123.38 5765.70 5829.09 1794.14 1966.33 1959.80 -980.12 1697.11 2.09 5969317.99 644829.15 N 70.32358687 W 148.82563596 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02B\J-02B Generated 12/7/20046:48 AM Page 3 of 7 Comments Latitude Longitude 6406.09 35.14 123.88 5806.82 5870.21 1819.41 1994.78 1988.20 -995.88 1720.80 1.91 5969302.69 644853.14 N 70.32354380 W 148.82544393 6456.09 35.93 124.82 5847.51 5910.90 1845.05 2023.84 2017.18 -1012.28 1744.79 1.92 5969286.75 644877.43 N 70.32349899 W 148.82524946 6506.09 36.68 124.84 5887.80 5951.19 1871.05 2053.44 2046.68 -1029.18 1769.09 1.50 5969270.31 644902.05 N 70.32345278 W 148.82505249 6556.09 37.51 125.31 5927.68 5991.07 1897.48 2083.60 2076.73 -1046.51 1793.77 1.75 5969253.46 644927.05 N 70.32340542 W 148.82485244 6606.09 37.79 125.36 5967.27 6030.66 1924.18 2114.14 2107.15 -1064.18 1818.69 0.56 5969236.27 644952.30 N 70.32335715 W 148.82465047 6656.09 37.90 125.78 6006.75 6070.14 1950.93 2144.82 2137.70 -1082.02 1843.64 0.56 5969218.91 644977.58 N 70.32330838 W 148.82444822 6706.09 37.58 126.29 6046.29 6109.68 1977.50 2175.42 2168.16 -1100.03 1868.39 0.89 5969201.38 645002.67 N 70.32325918 W 148.82424761 6756.09 37.63 126.39 6085.91 6149.30 2003.91 2205.93 2198.52 -1118.11 1892.96 0.16 5969183.78 645027.58 N 70.32320977 W 148.82404840 6806.09 37.46 126.30 6125.55 6188.94 2030.28 2236.40 2228.83 -1136.16 1917.51 0.36 5969166.19 645052.46 N 70.32316042 W 148.82384947 6856.09 37.44 126.84 6165.24 6228.63 2056.53 2266.80 2259.08 -1154.28 1941.92 0.66 5969148.55 645077.22 N 70.32311092 W 148.82365155 6906.09 36.94 127.37 6205.08 6268.47 2082.49 2297.03 2289.11 -1172.51 1966.03 1.19 5969130.78 645101.67 N 70.32306109 W 148.82_ 6956.09 36.97 127.43 6245.03 6308.42 2108.22 2327.09 2318.98 -1190.77 1989.91 0.09 5969112.98 645125.89 N 70.32301120 W 148.823 62 7006.09 36.49 127.09 6285.10 6348.49 2133.86 2356.99 2348.70 -1208.87 2013.71 1.04 5969095.34 645150.03 N 70.32296172 W 148.82306972 7056.09 36.17 127.68 6325.38 6388.77 2159.22 2386.61 2378.14 -1226.86 2037.24 0.95 5969077.81 645173.90 N 70.32291257 W 148.82287895 7106.09 36.30 128.06 6365.71 6429.10 2184.39 2416.17 2407.48 -1245.00 2060.57 0.52 5969060.11 645197.57 N 70.32286299 W 148.82268984 7156.09 36.10 127.70 6406.06 6469.45 2209.55 2445.70 2436.81 -1263.13 2083.88 0.58 5969042.43 645221.22 N 70.32281344 W 148.82250092 7206.09 35.61 128.49 6446.59 6509.98 2234.43 2474.98 2465.89 -1281.20 2106.93 1.35 5969024.81 645244.60 N 70.32276406 W 148.82231411 7256.09 35.90 128.63 6487.16 6550.55 2259.13 2504.20 2494.88 -1299.41 2129.77 0.60 5969007.04 645267.79 N 70.32271429 W 148.82212894 7306.09 35.23 128.94 6527.84 6591.23 2283.66 2533.28 2523.72 -1317.63 2152.44 1.39 5968989.26 645290.80 N 70.32266451 W 148.82194521 7356.09 34.88 129.32 6568.77 6632.16 2307.78 2562.00 2552.18 -1335.75 2174.72 0.82 5968971.56 645313.42 N 70.32261498 W 148.82176465 7406.09 34.34 130.25 6609.92 6673.31 2331.47 2590.40 2580.29 -1353.92 2196.54 1.51 5968953.81 645335.58 N 70.32256532 W 148.82158776 7456.09 33.50 130.96 6651.41 6714.80 2354.51 2618.30 2607.86 -1372.08 2217.73 1.86 5968936.07 645357.11 N 70.32251570 W 148.82141607 7506.09 33.48 131.38 6693.11 6756.50 2377.14 2645.89 2635.08 -1390.24 2238.50 0.47 5968918.30 645378.22 N 70.32246607 W 148.82124775 7556.09 33.02 132.39 6734.92 6798.31 2399.43 2673.30 2662.08 -1408.54 2258.91 1.44 5968900.40 645398.97 N 70.32241605 W 148.82108233 7606.09 32.91 132.07 6776.87 6840.26 2421.45 2700.51 2688.85 -1426.83 2279.05 0.41 5968882.50 645419.46 N 70.32236608 W 148.82091906 7656.09 32.45 133.20 6818.96 6882.35 2443.20 2727.50 2715.39 -1445.11 2298.91 1.53 5968864.60 645439.67 N 70.32231611 W 148.82075809 7706.09 31.94 134.01 6861.27 6924.66 2464.38 2754.14 2741.51 -1463.48 2318.20 1.34 5968846.60 645459.30 N 70.32226591 W 148.82060175 7756.09 32.33 133.99 6903.61 6967.00 2485.42 2780.74 2767.55 -1481.96 2337.34 0.78 5968828.50 645478.78 N 70.32221542 W 148.8.0 7806.09 33.13 134.08 6945.67 7009.06 2506.79 2807.77 2794.03 -1500.75 2356.77 1.60 5968810.08 645498.57 N 70.32216407 W 148.8 9 7856.09 33.60 135.04 6987.43 7050.82 2528.38 2835.27 2820.93 -1520.04 2376.36 1.41 5968791.16 645518.52 N70.32211134 W148.82 ~2 7906.09 34.39 135.30 7028.88 7092.27 2550.14 2863.23 2848.22 -1539.87 2396.07 1.61 5968771.72 645538.60 N 70.32205716 W 148.81997070 7956.09 35.28 135.98 7069.92 7133.31 2572.22 2891.79 2876.06 -1560.29 2416.04 1.94 5968751.68 645558.96 N 70.32200135 W 148.81980888 8006.09 36.26 137.06 7110.49 7173.88 2594.52 2921.01 2904.47 -1581.50 2436.15 2.33 5968730.86 645579.46 N 70.32194339 W 148.81964593 8056.09 37.17 137.34 7150.57 7213.96 2617.11 2950.90 2933.46 -1603.43 2456.45 1.85 5968709.32 645600.18 N 70.32188346 W 148.81948135 8106.09 38.06 137.80 7190.18 7253.57 2640.04 2981.42 2963.02 -1625.96 2477.04 1.87 5968687.20 645621.20 N 70.32182190 W 148.81931451 8156.09 38.87 138.85 7229.33 7292.72 2663.13 3012.52 2993.06 -1649.19 2497.72 2.08 5968664.37 645642.31 N 70.32175841 W 148.81914695 8206.09 39.33 138.72 7268.13 7331.52 2686.38 3044.06 3023.48 -1672.91 2518.50 0.93 5968641.05 645663.54 N 70.32169359 W 148.81897858 8256.09 39.25 138.60 7306.83 7370.22 2709.77 3075.72 3054.07 -1696.68 2539.41 0.22 5968617.68 645684.90 N 70.32162863 W 148.81880911 8306.09 38.79 139.28 7345.68 7409.07 2732.92 3107.20 3084.46 -1720.42 2560.09 1.26 5968594.35 645706.02 N 70.32156377 W 148.81864155 8356.09 37.67 139.13 7384.95 7448.34 2755.57 3138.14 3114.31 -1743.84 2580.30 2.25 5968571.31 645726.68 N 70.32149976 W 148.81847774 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02B\J-02B Generated 12/7/20046:48 AM Page 4 of 7 Comments Latitude Longitude N 70.32143625 W 148.81831629 N 70.32137273 W 148.81815641 N 70.32130998 W 148.81799878 N 70.32124740 W 148.81784387 N 70.32118489 W 148.81768965 8656.09 36.15 139.71 7624.64 7688.03 2886.31 3318.53 3288.27 -1881.69 2696.66 0.72 5968435.72 645845.64 N 70.32112305 W 148.81753488 8706.09 35.03 140.16 7665.30 7728.69 2907.37 3347.63 3316.39 -1903.96 2715.39 2.30 5968413.81 645864.79 N 70.32106220 W 148.81738310 8756.09 35.25 140.71 7706.18 7769.57 2928.01 3376.41 3344.14 -1926.15 2733.72 0.77 5968391.98 645883.54 N 70.32100157 W 148.81723458 8806.09 34.64 141.59 7747.17 7810.56 2948.31 3405.05 3371.68 -1948.45 2751.69 1.58 5968370.03 645901.92 N 70.32094062 W 148.81708901 8856.09 33.60 141.75 7788.56 7851.95 2968.01 3433.10 3398.60 -1970.45 2769.08 2.09 5968348.37 645919.73 N 70.32088050 W 148.81694807 8906.09 32.99 141.92 7830.35 7893.74 2987.23 3460.54 3424.94 -1992.03 2786.04 1.23 5968327.12 645937.10 N 70.32082153 W 148.81. 8956.09 32.61 141.52 7872.38 7935.77 3006.23 3487.63 3450.96 -2013.29 2802.82 0.87 5968306.18 645954.28 N 70.32076343 W 148.81 9006.09 32.62 142.30 7914.50 7977.89 3025.08 3514.58 3476.85 -2034.50 2819.45 0.84 5968285.29 645971.30 N 70.32070547 W 148.816 00 9056.09 32.01 142.50 7956.75 8020.14 3043.60 3541.31 3502.47 -2055.68 2835.76 1.24 5968264.43 645988.01 N 70.32064760 W 148.81640786 9106.09 31.48 142.65 7999.27 8062.66 3061.78 3567.61 3527.69 -2076.57 2851.74 1.07 5968243.85 646004.39 N 70.32059051 W 148.81627833 9156.09 30.68 143.03 8042.10 8105.49 3079.53 3593.43 3552.41 -2097.14 2867.34 1.65 5968223.58 646020.37 N 70.32053430 W 148.81615200 9206.09 29.95 143.57 8085.26 8148.65 3096.74 3618.66 3576.54 -2117.37 2882.42 1.56 5968203.64 646035.84 N 70.32047900 W 148.81602979 9256.09 28.97 144.52 8128.79 8192.18 3113.27 3643.25 3599.96 -2137.27 2896.86 2.17 5968184.02 646050.66 N 70.32042462 W 148.81591280 9306.09 28.58 145.26 8172.62 8236.01 3129.18 3667.32 3622.80 -2156.96 2910.70 1.06 5968164.60 646064.87 N 70.32037081 W 148.81580065 9356.09 27.16 146.17 8216.82 8280.21 3144.38 3690.69 3644.89 -2176.27 2923.87 2.96 5968145.55 646078.41 N 70.32031805 W 148.81569395 9406.09 26.93 146.97 8261.35 8324.74 3158.91 3713.43 3666.27 -2195.24 2936.40 0.86 5968126.82 646091.29 N 70.32026621 W 148.81559249 9456.09 26.93 147.50 8305.93 8369.32 3173.17 3736.07 3687.49 -2214.29 2948.65 0.48 5968108.02 646103.90 N 70.32021417 W 148.81549320 9506.09 27.33 147.81 8350.43 8413.82 3187.41 3758.87 3708.83 -2233.55 2960.85 0.85 5968088.99 646116.47 N 70.32016153 W 148.81539439 9556.09 27.32 148.14 8394.85 8458.24 3201.63 3781.82 3730.27 -2253.01 2973.02 0.30 5968069.77 646129.01 N 70.32010836 W 148.81529579 9606.09 27.10 148.11 8439.32 8502.71 3215.76 3804.69 3751.63 -2272.42 2985.10 0.44 5968050.59 646141.45 N 70.32005531 W 148.81519799 9656.09 26.85 148.00 8483.88 8547.27 3229.79 3827.37 3772.84 -2291.67 2997.10 0.51 5968031.58 646153.81 N 70.32000272 W 148.81510078 9706.09 27.01 148.23 8528.45 8591.84 3243.78 3850.01 3794.03 -2310.90 3009.06 0.38 5968012.58 646166.13 N 70.31995018 W 148.81500388 9756.09 26.79 148.28 8573.04 8636.43 3257.72 3872.63 3815.20 -2330.13 3020.96 0.44 5967993.58 646178.40 N 70.31989761 W 148.81490747 9806.09 26.71 148.27 8617.69 8681.08 3271.57 3895.14 3836.27 -2349.28 3032.79 0.16 5967974.67 646190.60 N 70.31984530 W 148.81.1 GYD CT CMS 9856.09 26.78 148.32 8662.34 8725.73 3285.42 3917.64 3857.35 -2368.42 3044.62 0.15 5967955.75 646202.78 N 70.31979299 W 148.81 1 Tie-In Survey 9906.09 26.52 148.24 8707.03 8770.42 3299.23 3940.07 3878.37 -2387.50 3056.41 0.52 5967936.91 646214.94 N 70.31974086 W 148.81462030 Top Window 9916.00 26.59 148.29 8715.90 8779.29 3301.96 3944.50 3882.53 -2391.26 3058.74 0.74 5967933.18 646217.34 N 70.31973056 W 148.81460142 Base Window 9928.00 27.76 146.45 8726.57 8789.96 3305.40 3949.98 3887.70 -2395.88 3061.70 12.00 5967928.63 646220.38 N 70.31971795 W 148.81457747 Blind Surveys 9943.15 26.72 148.50 8740.04 8803.43 3309.75 3956.91 3894.24 -2401.72 3065.43 9.24 5967922.85 646224.22 N 70.31970198 W 148.81454726 9964.72 26.43 148.50 8759.33 8822.72 3315.66 3966.56 3903.29 -2409.95 3070.47 1.34 5967914.73 646229.42 N 70.31967950 W 148.81450642 9991.33 28.30 145.04 8782.97 8846.36 3323.45 3978.79 3914.88 -2420.17 3077.18 9.22 5967904.64 646236.32 N 70.31965157 W 148.81445207 10006.33 30.33 143.38 8796.04 8859.43 3328.37 3986.13 3921.94 -2426.13 3081.47 14.58 5967898.76 646240.73 N 70.31963530 W 148.81441725 10024.77 32.76 141.56 8811.76 8875.15 3335.05 3995.78 3931.29 -2433.77 3087.35 14.15 5967891.23 646246.76 N 70.31961440 W 148.81436962 End Blind Survey 10056.64 36.35 138.89 8838.00 8901.39 3348.08 4013.85 3948.97 -2447.65 3098.93 12.22 5967877.58 646258.59 N 70.31957648 W 148.81427584 First MWD + IFR 10087.90 41.54 136.63 8862.31 8925.70 3362.80 4033.49 3968.35 -2462.17 3112.15 17.21 5967863.31 646272.09 N 70.31953679 W 148.81416874 10120.87 50.52 133.53 8885.18 8948.57 3381.30 4057.19 3991.89 -2478.92 3128.92 28.06 5967846.89 646289.17 N 70.31949102 W 148.81403287 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) J-02\J-02\J-02 B\J-02 B Generated 12/7/20046:48 AM Page 5 of 7 Comments Latitude Longitude N 70.31944548 W 148.81387389 N 70.31940167 W 148.81370020 Tie-In Survey N 70.31935200 W 148.81348351 MWD + IFR N 70.31933518 W 148.81340366 10260.17 78.26 120.80 8936.77 9000.16 3492.94 4184.78 4119.03 -2552.06 3233.18 8.80 5967775.76 646394.80 N 70.31929109 W 148.81318801 10290.64 80.54 120.23 8942.38 9005.77 3520.25 4214.73 4148.71 -2567.26 3258.98 7.71 5967761.05 646420.88 N 70.31924952 W 148.81297894 10322.67 84.48 118.58 8946.55 9009.94 3549.45 4246.48 4180.09 -2582.85 3286.64 13.32 5967745.99 646448.83 N 70.31920690 W 148.81275479 10354.45 85.64 115.31 8949.29 9012.68 3579.07 4278.14 4211.14 -2597.19 3314.86 10.88 5967732.19 646477.32 N 70.31916768 W 148.81252609 10388.08 87.67 109.22 8951.25 9014.64 3611.33 4311.71 4243.44 -2609.91 3345.91 19.06 5967720.08 646508.61 N 70.31913292 W 148.81227443 10419.45 87.88 100.95 8952.47 9015.86 3642.28 4343.06 4272.31 -2618.06 3376.15 26.35 5967712.50 646538.99 N 70.31911061 W 148.81202934 10451.24 88.73 95.52 8953.41 9016.80 3674.02 4374.83 4299.97 -2622.61 3407.59 17.28 5967708.55 646570.51 N 70.31909815 W 148.81. 10487.29 90.58 91.21 8953.63 9017.02 3710.02 4410.88 4329.82 -2624.72 3443.57 13.01 5967707.13 646606.52 N 70.31909232 W 148.81 10518.79 92.09 83.37 8952.90 9016.29 3741.09 4442.37 4353.96 -2623.23 3475.00 25.34 5967709.21 646637.91 N 70.31909635 W 148.811 17 10546.39 91.75 78.41 8951.97 9015.36 3767.68 4469.96 4373.11 -2618.87 3502.23 18.00 5967714.10 646665.05 N 70.31910824 W 148.81100746 10578.15 90.48 74.79 8951.35 9014.74 3797.58 4501.71 4393.50 -2611.51 3533.11 12.08 5967722.04 646695.79 N 70.31912830 W 148.81075710 10610.91 89.35 76.71 8951.40 9014.79 3828.25 4534.47 4414.31 -2603.45 3564.86 6.80 5967730.71 646727.37 N 70.31915029 W 148.81049972 10643.89 88.80 77.36 8951.93 9015.32 3859.38 4567.44 4435.97 -2596.05 3596.99 2.58 5967738.72 646759.36 N 70.31917046 W 148.81023922 10674.24 88.77 84.96 8952.58 9015.97 3888.66 4597.79 4457.59 -2591.39 3626.96 25.04 5967743.95 646789.22 N 70.31918315 W 148.80999635 10707.82 91.82 90.73 8952.41 9015.80 3921.85 4631.36 4484.19 -2590.13 3660.49 19.43 5967745.85 646822.73 N 70.31918655 W 148.80972450 10739.95 93.64 97.29 8950.87 9014.26 3953.90 4663.45 4511.64 -2592.37 3692.49 21.17 5967744.22 646854.76 N 70.31918039 W 148.80946516 10771.62 92.74 97.65 8949.11 9012.50 3985.52 4695.08 4539.68 -2596.48 3723.84 3.06 5967740.71 646886.18 N 70.31916911 W 148.80921105 10803.07 92.40 96.71 8947.70 9011.09 4016.93 4726.49 4567.52 -2600.41 3755.01 3.18 5967737.37 646917.42 N 70.31915834 W 148.80895840 10833.85 90.07 91.59 8947.04 9010.43 4047.67 4757.26 4594.04 -2602.63 3785.69 18.27 5967735.74 646948.13 N 70.31915222 W 148.80870974 10868.76 89.18 93.01 8947.27 9010.66 4082.49 4792.17 4623.61 -2604.03 3820.57 4.80 5967735.00 646983.03 N 70.31914835 W 148.80842702 10900.55 88.97 93.75 8947.78 9011.17 4114.24 4823.96 4650.91 -2605.91 3852.30 2.42 5967733.73 647014.79 N 70.31914318 W 148.80816984 10930.97 89.28 90.18 8948.24 9011.63 4144.56 4854.38 4676.70 -2606.95 3882.70 11.78 5967733.27 647045.19 N 70.31914029 W 148.80792348 10963.63 89.62 84.76 8948.56 9011.95 4176.83 4887.03 4703.01 -2605.51 3915.31 16.63 5967735.33 647077.77 N 70.31914418 W 148.80765912 10995.70 89.35 85.07 8948.85 9012.24 4208.27 4919.10 4728.07 -2602.67 3947.25 1.28 5967738.78 647109.65 N 70.31915190 W 148.80740019 11027.16 88.66 91.53 8949.39 9012.78 4239.40 4950.56 4753.83 -2601.73 3978.68 20.65 5967740.31 647141.05 N 70.31915440 W 148.8~.7 11060.30 92.06 88.37 8949.18 9012.57 4272.33 4983.69 4781.58 -2601.70 4011.81 14.01 5967740.97 647174.17 N 70.31915443 W 148.80 3 11092.08 90.82 92.38 8948.39 9011.78 4303.92 5015.46 4808.37 -2601.91 4043.57 13.20 5967741.37 647205.93 N 70.31915382 W 148.80661948 11125.36 90.96 88.61 8947.87 9011.26 4337.02 5048.74 4836.54 -2602.20 4076.84 11.33 5967741.72 647239.20 N 70.31915299 W 148.80634982 11156.34 90.17 92.06 8947.56 9010.95 4367.83 5079.72 4862.77 -2602.38 4107.81 11.42 5967742.13 647270.16 N 70.31915244 W 148.80609877 11188.32 90.21 90.25 8947.46 9010.85 4399.68 5111.70 4890.15 -2603.03 4139.79 5.66 5967742.09 647302.14 N 70.31915064 W 148.80583962 11221.19 90.14 89.56 8947.36 9010.75 4432.35 5144.57 4917.98 -2602.97 4172.65 2.11 5967742.78 647335.00 N 70.31915073 W 148.80557319 11254.01 89.90 89.48 8947.35 9010.74 4464.94 5177.39 4945.71 -2602.70 4205.47 0.77 5967743.68 647367.80 N 70.31915144 W 148.80530718 11283.71 90.65 89.18 8947.20 9010.59 4494.42 5207.08 4970.80 -2602.35 4235.17 2.72 5967744.59 647397.49 N 70.31915234 W 148.80506646 11316.66 91.51 85.86 8946.58 9009.97 4526.98 5240.03 4998.13 -2600.92 4268.08 10.41 5967746.64 647430.36 N 70.31915618 W 148.80479971 11347.55 91.51 85.40 8945.77 9009.16 4557.32 5270.91 5023.23 -2598.57 4298.87 1.49 5967749.58 647461.10 N 70.31916256 W 148.80455013 11380.57 91.85 84.52 8944.80 9008.19 4589.69 5303.91 5049.90 -2595.67 4331.75 2.86 5967753.11 647493.91 N 70.31917043 W 148.80428362 11413.05 91.65 83.72 8943.81 9007.20 4621.42 5336.38 5075.93 -2592.35 4364.04 2.54 5967757.05 647526.13 N 70.31917947 W 148.80402185 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) J-02\J-02\J-02 B\J-02 B Generated 12/7/20046:48 AM Page 6 of 7 Comments Latitude Longitude N 70.31918994 W 148.80376258 N 70.31919822 W 148.80350920 N 70.31920658 W 148.80326137 11538.96 90.17 87.12 8941.19 9004.58 4744.44 5462.26 5177.51 -2579.43 4489.23 15.99 5967772.35 647651.04 N 70.31921454 W 148.80300708 11571.44 90.65 87.25 8940.96 9004.35 4776.52 5494.74 5204.87 -2577.84 4521.67 1.53 5967774.56 647683.44 N 70.31921884 W 148.80274412 11603.21 90.86 85.80 8940.54 9003.93 4807.82 5526.50 5231.50 -2575.91 4553.37 4.61 5967777.09 647715.10 N 70.31922405 W 148.80248710 11635.29 90.48 85.09 8940.16 9003.55 4839.33 5558.58 5258.10 -2573.37 4585.35 2.51 5967780.24 647747.02 N 70.31923096 W 148.80222790 11667.27 88.94 89.47 8940.33 9003.72 4870.90 5590.56 5285.24 -2571.85 4617.28 14.52 5967782.37 647778.92 N 70.31923505 W 148.80196905 11698.53 88.49 92.13 8941.03 9004.42 4902.01 5621.81 5312.77 -2572.28 4648.53 8.63 5967782.53 647810.17 N 70.31923381 W 148.80171578 11730.31 88.70 85.65 8941.81 9005.20 4933.50 5653.58 5340.27 -2571.67 4680.28 20.40 5967783.75 647841.89 N 70.31923543 W 148.80145845 11761.56 88.25 89.34 8942.64 9006.03 4964.37 5684.82 5366.98 -2570.30 4711.48 11.89 5967785.71 647873.06 N 70.31923911 W 148.80.1 11793.93 87.84 89.25 8943.74 9007.13 4996.48 5717.17 5395.22 -2569.91 4743.83 1.30 5967786.73 647905.40 N 70.31924014 W 148.80 1 11825.82 87.29 88.71 8945.10 9008.49 5028.08 5749.03 5422.98 -2569.34 4775.69 2.42 5967787.90 647937.23 N 70.31924163 W 148.800 09 11858.51 87.33 83.44 8946.63 9010.02 5060.21 5781.69 5450.63 -2567.10 4808.25 16.10 5967790.76 647969.75 N70.31924768 W148.80042111 11890.20 86.61 88.65 8948.31 9011.70 5091.34 5813.33 5477.46 -2564.92 4839.81 16.57 5967793.54 648001.26 N 70.31925359 W 148.80016529 11922.50 87.16 87.46 8950.06 9013.45 5123.26 5845.59 5505.45 -2563.83 4872.04 4.05 5967795.25 648033.46 N 70.31925652 W 148.79990402 Last MWD + IFR 11961.75 86.64 87.36 8952.19 9015.58 5161.98 5884.78 5539.31 -2562.06 4911.20 1.35 5967797.77 648072.57 N 70.31926129 W 148.79958665 TO ( Projected) 12028.00 86.64 87.36 8956.07 9019.46 5227.32 5950.91 5596.58 -2559.01 4977.26 0.00 5967802.07 648138.56 N 70.31926950 W 148.79905113 Survey Type: Definitive Survey NOTES: GYD CT CMS - ( Gyrodata - cont. casing mIs -- Gyrodata multishot surveys with continuous toll (RGS-CT) in casing. OD 13-3/8" or less.) MWD + IFR . ( In-field referenced MWD with time-varying field applied. Model is applicable whether or not Short Collar type correction is applied. Assumes a BHA sag correction Is applied to enhance inclination accuracy. ) Legal Description: Surface: 4199 FSL 1245 FEL S9 T11 N R13E UM BHL: 1639 FSL 1554 FEL S10 T11N R13E UM Northing tY) rftUSl 5970265.49 5967802.07 Eastina tX) rftUSl 643113.79 648138.56 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02 B\J-02 B Generated 12/7/20046:48 AM Page 7 of 7 J-02BPB1 Survey Report Schlumberger Report Date: 3-Nov-04 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration (Alaska) Vertical Section Azimuth: 96.280° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: J-PAD 1 J-02 TVD Reference Datum: Rotary Table Well: J-02 TVD Reference Elevation: 63.39 ft relative to MSL Borehole: J-02BPB1 Sea Bed I Ground Level Elevation: 37.80 ft relative to MSL UWl/API#: 500292002370 Magnetic Declination: 24.947° Survey Name I Date: J-02BPB11 November 3,2004 Total Field Strength: 57614.690 nT Tort I AHD I DDII ERD ratio: 261.410°/4770.40 ft/6.1751 0.528 Magnetic Dip: 80.847° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 02, 2004 . Location Lat/Long: N 70.32626499, W 148.83939503 Magnetic Declination Model: BGGM 2004 Location Grid NÆ Y!X: N 5970265.490 ftUS, E 643113.790 ftUS North Reference: True North Grid Convergence Angle: +1.09287160° Total Corr Mag North·> True North: +24.947" Grid Scale Factor: 0.99992327 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub·Sea TVD TVD Closure NS EW DLS Latitude Longitude Depth ft 0.00 N 70.32626499 W 148.83939503 6.09 N 70.32626499 W 148.83939503 GYD CT CMS 106.09 N 70.32626421 W 148.83939500 206.09 N 70.32626316 W 148.83939580 306.09 N 70.32626269 W 148.83939569 406.09 0.40 190.61 342.70 406.09 0.11 1.35 1.26 -1.26 -0.03 0.37 5970264.23 643113.79 N 70.32626154 W 148.83939526 506.09 0.57 189.57 442.69 506.08 0.05 2.20 2.10 -2.10 -0.18 0.17 5970263.39 643113.65 N 70.32625927 W 148.83939646 606.09 0.47 199.75 542.69 606.08 -0.07 3.10 3.00 -2.97 -0.40 0.14 5970262.51 643113.45 N 70.32625687 W 148.83939825 706.09 0.44 181.97 642.69 706.08 -0.14 3.89 3.78 -3.74 -0.55 0.14 5970261.74 643113.31 N 70.32625477 W 148.83939948 806.09 0.30 159.49 742.68 806.07 0.01 4.53 4.40 -4.37 -0.47 0.20 5970261.11 643113.40 N 70.32625305 W 148.83939884 906.09 0.14 310.55 842.68 906.07 0.03 4.76 4.56 -4.54 -0.47 0.43 5970260.95 643113.41 N 70.32625260 W 148.8.5 1006.09 0.14 167.22 942.68 1006.07 -0.03 4.91 4.61 -4.58 -0.54 0.27 5970260.90 643113.34 N 70.32625249 W 148.8 9 1106.09 0.12 15.28 1042.68 1106.07 0.02 5.04 4.62 -4.60 -0.48 0.25 5970260.89 643113.40 N 70.32625244 W 148.83939894 1206.09 0.15 14.87 1142.68 1206.07 0.06 5.27 4.39 -4.37 -0.42 0.03 5970261.12 643113.45 N 70.32625306 W 148.83939845 1306.09 0.16 1.16 1242.68 1306.07 0.07 5.54 4.12 -4.10 -0.38 0.04 5970261.38 643113.48 N 70.32625379 W 148.83939815 1406.09 0.15 164.25 1342.68 1406.07 0.10 5.69 4.10 -4.09 -0.35 0.31 5970261.40 643113.52 N 70.32625383 W 148.83939784 1506.09 0.20 53.26 1442.68 1506.07 0.28 5.91 4.11 -4.11 -0.17 0.29 5970261.38 643113.70 N 70.32625377 W 148.83939642 1606.09 0.32 35.00 1542.68 1606.07 0.54 6.36 3.78 -3.78 0.13 0.14 5970261.72 643113.99 N 70.32625468 W 148.83939399 1706.09 0.22 2.73 1642.68 1706.07 0.66 6.82 3.37 -3.36 0.30 0.18 5970262.14 643114.15 N 70.32625583 W 148.83939261 1806.09 0.19 87.88 1742.68 1806.07 0.82 7.12 3.19 -3.16 0.47 0.28 5970262.34 643114.32 N 70.32625637 W 148.83939120 1906.09 0.12 280.68 1842.68 1906.07 0.88 7.26 3.18 -3.13 0.54 0.31 5970262.37 643114.39 N 70.32625644 W 148.83939069 2006.09 1.03 128.46 1942.68 2006.07 1.53 8.10 3.84 -3.67 1.14 1.14 5970261.84 643115.00 N 70.32625496 W 148.83938581 2106.09 5.27 131.84 2042.50 2105.89 6.03 13.59 9.00 -7.30 5.26 4.24 5970258.30 643119.19 N 70.32624506 W 148.83935235 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) J-02\J-02\J-02BPB 1 \J-02BPB 1 Generated 12/7/20046:49 AM Page 1 of 6 Comments Latitude Longitude N 70.32622855 W 148.83928014 N 70.32621058 W 148.83918229 2406.09 9.90 117.26 2339.66 2403.05 43.22 54.22 48.90 -27.45 40.46 1.29 5970238.81 643154.77 N 70.32618999 W 148.83906694 2456.09 10.44 117.12 2388.87 2452.26 51.47 63.05 57.67 -31.49 48.32 1.08 5970234.93 643162.69 N 70.32617897 W 148.83900327 2506.09 11.48 116.76 2437.96 2501.35 60.37 72.55 67.13 -35.79 56.79 2.08 5970230.79 643171.25 N 70.32616721 W 148.83893455 2556.09 11.98 117.18 2486.91 2550.30 69.87 82.72 77.26 -40.40 65.85 1.01 5970226.35 643180.39 N 70.32615461 W 148.83886109 2606.09 12.86 117.38 2535.74 2599.13 79.91 93.4 7 87.99 -45.33 75.41 1.76 5970221.61 643190.04 N 70.32614114 W 148.83878360 2656.09 13.97 117.75 2584.38 2647.77 90.72 105.07 99.57 -50.70 85.69 2.23 5970216.43 643200.42 N 70.32612648 W 148.83870023 2706.09 14.86 117.78 2632.80 2696.19 102.30 117.52 112.00 -56.50 96.70 1.78 5970210.85 643211.55 N 70.32611063 W 148.83861092 2756.09 15.80 117.72 2681.02 2744.41 114.61 130.74 125.21 -62.66 1 08.40 1.88 5970204.92 643223.36 N 70.32609382 W 148.83851607 2806.09 16.37 118.44 2729.06 2792.45 127.47 144.59 139.05 -69.18 120.62 1.21 5970198.63 643235.70 N 70.32607600 W 148.83. 2856.09 17.45 119.05 2776.90 2840.29 140.91 159.13 153.59 -76.17 133.37 2.19 5970191.88 643248.58 N 70.32605689 W 148.83 2906.09 18.53 119.09 2824.46 2887.85 155.14 174.58 169.04 -83.68 146.87 2.16 5970184.64 643262.22 N 70.32603639 W 148.83820416 2956.09 19.66 119.50 2871.71 2935.10 170.20 190.93 185.39 -91.68 161.13 2.28 5970176.90 643276.63 N 70.32601452 W 148.83808850 3006.09 20.52 118.99 2918.66 2982.05 186.01 208.11 202.57 -100.07 176.12 1.76 5970168.80 643291.77 N 70.32599160 W 148.83796699 3056.09 21.76 119.09 2965.30 3028.69 202.64 226.14 220.60 -108.82 191.89 2.48 5970160.35 643307.70 N 70.32596769 W 148.83783917 3106.09 23.06 119.36 3011.52 3074.91 220.19 245.20 239.66 -118.13 208.52 2.61 5970151.37 643324.51 N 70.32594226 W 148.83770430 3156.09 24.09 119.58 3057.35 3120.74 238.57 265.20 259.65 -127.97 225.93 2.07 5970141.86 643342.10 N 70.32591538 W 148.83756314 3206.09 25.20 119.86 3102.79 3166.18 257.70 286.05 280.50 -138.31 244.04 2.23 5970131.87 643360.40 N 70.32588714 W 148.83741633 3256.09 26.77 120.38 3147.73 3211.12 277.74 307.95 302.41 -149.30 262.98 3.17 5970121.24 643379.55 N 70.32585710 W 148.83726271 3306.09 28.21 120.88 3192.09 3255.48 298.76 331.03 325.48 -161.06 282.84 2.92 5970109.86 643399.63 N 70.32582497 W 148.83710170 3356.09 29.56 121.33 3235.87 3299.26 320.68 355.18 349.63 -173.54 303.52 2.73 5970097.78 643420.54 N 70.32579087 W 148.83693404 3406.09 30.97 121.35 3279.05 3342.44 343.51 380.38 374.82 -186.65 325.04 2.82 5970085.09 643442.31 N 70.32575506 W 148.83675953 3456.09 32.53 121.57 3321.57 3384.96 367.32 406.69 401.12 -200.38 347.48 3.13 5970071.79 643465.00 N 70.32571755 W 148.83657758 3506.09 33.08 121.36 3363.59 3426.98 391.83 433.78 428.20 -214.52 370.59 1.12 5970058.09 643488.37 N 70.32567891 W 148.83639024 3556.09 33.06 121.36 3405.49 3468.88 416.54 461.07 455.48 -228.72 393.89 0.04 5970044.34 643511.94 N 70.32564012 W 148.83620134 3606.09 32.71 121.73 3447.48 3510.87 441.09 488.21 482.62 -242.92 417.02 0.81 5970030.58 643535.34 N 70.32560132 W 148.83601376 3656.09 32.55 121.55 3489.59 3552.98 465.45 515.17 509.57 -257.07 439.98 0.37 5970016.88 643558.55 N 70.32556268 W 148.8.5 3706.09 31.44 122.00 3531.99 3595.38 489.37 541.66 536.05 -271.01 462.50 2.27 5970003.37 643581.34 N 70.32552457 W 148.8 5 3756.09 30.80 121.15 3574.80 3638.19 512.73 567.51 561.89 -284.55 484.51 1.55 5969990.26 643603.60 N 70.32548760 W 148.83 56 3806.09 29.99 121.21 3617.93 3681.32 535.68 592.80 587.18 -297.64 506.15 1.62 5969977.58 643625.49 N 70.32545181 W 148.83529108 3856.09 30.03 121.19 3661.22 3724.61 558.36 617.81 612.19 -310.60 527.55 0.08 5969965.03 643647.12 N 70.32541642 W 148.83511765 3906.09 30.20 120.78 3704.47 3767.86 581.15 642.90 637.27 -323.51 549.05 0.53 5969952.53 643668.87 N 70.32538113 W 148.83494328 3956.09 30.26 121.39 3747.67 3811.06 604.00 668.07 662.45 -336.51 570.61 0.63 5969939.95 643690.67 N 70.32534562 W 148.83476849 4006.09 30.68 121.19 3790.77 3854.16 626.97 693.43 687.80 -349.68 592.28 0.86 5969927.20 643712.58 N 70.32530964 W 148.83459283 4056.09 30.93 121.13 3833.71 3897.10 650.20 719.03 713.40 -362.93 614.19 0.50 5969914.37 643734.74 N 70.32527344 W 148.83441517 4106.09 31.40 121.44 3876.50 3939.89 673.65 744.91 739.28 -376.36 636.30 0.99 5969901.36 643757.10 N 70.32523672 W 148.83423590 4156.09 31.69 121.55 3919.11 3982.50 697.32 771.07 765.43 -390.03 658.61 0.59 5969888.12 643779.66 N 70.32519939 W 148.83405506 4206.09 31.84 121.44 3961.62 4025.01 721.13 797.39 791.75 -403.78 681.05 0.32 5969874.80 643802.36 N 70.32516181 W 148.83387309 4256.09 32.06 121.65 4004.05 4067.44 745.06 823.85 818.21 -417.62 703.60 0.49 5969861.39 643825.17 N 70.32512399 W 148.83369027 4306.09 32.30 122.04 4046.37 4109.76 769.08 850.47 844.83 -431.67 726.22 0.63 5969847.78 643848.05 N 70.32508560 W 148.83350688 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02 BPB 1 \J-02 BPB 1 Generated 12/7/20046:49 AM Page 2 of 6 · Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure 1ft I (deal Idea I Iftl Iftl 1ft I Iftl Iftl Iftl 1ft) (dea/100 ft I (ftUS) (ftUSI 4356.09 32.52 122.11 4088.58 4151.97 793.21 877.27 871.62 -445.91 748.93 0.45 5969833.98 643871.03 N 70.32504672 W 148.83332278 4406.09 32.68 121.82 4130.70 4194.09 817.49 904.21 898.55 -460.17 771.78 0.45 5969820.16 643894.15 N 70.32500775 W 148.83313749 4456.09 32.41 118.66 4172.85 4236.24 842.06 931.11 925.44 -473.71 795.01 3.44 5969807.06 643917.63 N 70.32497074 W 148.83294916 4506.09 31.64 116.34 4215.24 4278.63 866.77 957.62 951.91 -485.96 818.52 2.90 5969795.27 643941.37 N 70.32493728 W 148.83275854 4556.09 31.44 116.50 4257.86 4321.25 891.32 983.77 977.99 -497.59 841.95 0.43 5969784.08 643965.01 N 70.32490548 W 148.83256864 4606.09 31.04 115.60 4300.61 4364.00 915.73 1009.70 1003.85 -508.98 865.24 1.23 5969773.14 643988.51 N 70.32487436 W 148.83237977 4656.09 31.17 115.99 4343.42 4406.81 940.07 1035.53 1029.59 -520.22 888.50 0.48 5969762.35 644011.98 N 70.32484364 W 148.83219122 4706.09 32.10 115.84 4385.99 4449.38 964.77 1061.76 1055.74 -531.68 912.09 1.87 5969751.34 644035.78 N 70.32481233 W 148.83199998 4756.09 33.23 115.92 4428.08 4491.4 7 990.19 1088.74 1082.65 -543.46 936.37 2.26 5969740.03 644060.28 N 70.32478014 W 148.83180314 4806.09 34.16 116.16 4469.68 4533.07 1016.30 1116.48 1110.32 -555.64 961.29 1.88 5969728.33 644085.42 N 70.32474686 W 148.83160109 4856.09 33.95 116.98 4511.10 4574.49 1042.56 1144.48 1138.27 -568.16 986.33 1.01 5969716.28 644110.70 N 70.32471264 W 148.83117 4906.09 33.80 117.25 4552.62 4616.01 1068.61 1172.35 1166.11 -580.87 1011.14 0.42 5969704.06 644135.74 N 70.32467793 W 148.831 96 4956.09 33.77 117.38 4594.17 4657.56 1094.56 1200.15 1193.88 -593.62 1035.84 0.16 5969691.78 644160.68 N 70.32464307 W 148.83099668 5006.09 34.19 117.37 4635.64 4699.03 1120.63 1228.10 1221.80 -606.47 1060.66 0.84 5969679.40 644185.74 N 70.32460795 W 148.83079550 5056.09 34.29 118.05 4676.97 4740.36 1146.82 1256.23 1249.92 -619.56 1085.56 0.79 5969666.80 644210.88 N 70.32457220 W 148.83059358 5106.09 33.93 117.89 4718.37 4781.76 1172.87 1284.27 1277.94 -632.71 1110.33 0.74 5969654.12 644235.89 N 70.32453627 W 148.83039282 5156.09 33.85 118.72 4759.87 4823.26 1198.72 1312.15 1305.82 -645.93 1134.87 0.94 5969641.38 644260.68 N 70.32450014 W 148.83019382 5206.09 33.62 119.36 4801 .45 4864.84 1224.32 1339.92 1333.58 -659.40 1159.15 0.85 5969628.36 644285.21 N 70.32446331 W 148.82999701 5256.09 33.85 118.96 4843.04 4906.43 1249.91 1367.69 1361.35 -672.93 1183.40 0.64 5969615.30 644309.71 N 70.32442634 W 148.82980043 5306.09 34.10 119.68 4884.50 4947.89 1275.62 1395.63 1389.29 -686.62 1207.76 0.95 5969602.09 644334.33 N 70.32438895 W 148.82960293 5356.09 34.50 119.53 4925.80 4989.19 1301.49 1423.80 1417.46 -700.54 1232.26 0.82 5969588.64 644359.09 N 70.32435091 W 148.82940433 5406.09 34.44 119.90 4967.03 5030.42 1327.46 1452.10 1445.76 -714.56 1256.83 0.44 5969575.08 644383.92 N 70.32431258 W 148.82920508 5456.09 34.24 119.45 5008.31 5071.70 1353.34 1480.31 1473.97 -728.53 1281.34 0.65 5969561.59 644408.69 N 70.32427442 W 148.82900642 5506.09 33.81 119.89 5049.75 5113.14 1379.02 1508.28 1501.95 -742.38 1305.65 0.99 5969548.21 644433.26 N 70.32423658 W 148.82880934 5556.09 33.59 120.23 5091.35 5154.74 1404.41 1536.03 1529.69 -756.27 1329.66 0.58 5969534.77 644457.53 N 70.32419860 W 148.82861469 5606.09 33.09 120.41 5133.12 5196.51 1429.50 1563.51 1557.17 -770.14 1353.38 1.02 5969521.36 644481.51 N 70.32416069 W 148.82842239 5656.09 33.04 120.11 5175.02 5238.41 1454.43 1590.79 1584.44 -783.89 1376.94 0.34 5969508.06 644505.33 N 70.32412313 W 148.82823137 5706.09 32.97 120.82 5216.95 5280.34 1479.27 1618.02 1611.68 -797.70 1400.42 0.79 5969494.71 644529.06 N 70.32408539 W 148.8.7 5756.09 32.75 121.24 5258.95 5322.34 1503.91 1645.15 1638.80 -811.68 1423.67 0.63 5969481.17 644552.57 N 70.32404717 W 148.8 1 5806.09 32.74 121.41 5301.01 5364.40 1528.41 1672.20 1665.83 -825.74 1446.77 0.18 5969467.55 644575.93 N 70.32400875 W 148.82 33 5856.09 31.66 120.32 5343.32 5406.71 1552.64 1698.84 1692.47 -839.42 1469.64 2.45 5969454.32 644599.05 N 70.32397139 W 148.82747995 5906.09 31.26 121.69 5385.97 5449.36 1576.34 1724.93 1718.56 -852.86 1492.00 1.64 5969441.31 644621.67 N 70.32393466 W 148.82729864 5956.09 31.48 121.60 5428.66 5492.05 1599.86 1750.96 1744.57 -866.51 1514.16 0.45 5969428.08 644644.08 N 70.32389734 W 148.82711901 6006.09 31.85 121.88 5471.22 5534.61 1623.56 1777.21 1770.80 -880.32 1536.48 0.80 5969414.70 644666.66 N 70.32385961 W 148.82693806 6056.09 32.46 120.93 5513.55 5576.94 1647.65 1803.82 1797.40 -894.18 1559.20 1.58 5969401.28 644689.63 N 70.32382172 W 148.82675395 6106.09 32.48 121.80 5555.73 5619.12 1671.96 1830.66 1824.23 -908.15 1582.12 0.93 5969387.75 644712.81 N 70.32378354 W 148.82656815 6156.09 32.25 121.31 5597.96 5661.35 1696.16 1857.43 1850.99 -922.16 1604.92 0.70 5969374.18 644735.88 N 70.32374526 W 148.82638326 6206.09 32.56 121.44 5640.18 5703.57 1720.43 1884.22 1877.77 -936.11 1627.80 0.64 5969360.67 644759.02 N 70.32370713 W 148.82619782 6256.09 32.94 121.98 5682.23 5745.62 1744.86 1911.27 1904.81 -950.33 1650.81 0.96 5969346.89 644782.29 N 70.32366828 W 148.82601129 .6306.09 33.23 122.82 5724.12 5787.51 1769.36 1938.56 1932.08 -964.96 1673.85 1.09 5969332.71 644805.61 N 70.32362831 W 148.82582449 6356.09 34.23 123.38 5765.70 5829.09 1794.14 1966.33 1959.80 -980.12 1697.11 2.09 5969317.99 644829.15 N 70.32358687 W 148.82563596 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02BPB 1 \J-02BPB 1 Generated 12/7/2004 6:49 AM Page 3 of 6 · Comments Latitude Longitude 6406.09 35.14 123.88 5806.82 5870.21 1819.41 1994.78 1988.20 -995.88 1720.80 1.91 5969302.69 644853.14 N 70.32354380 W 148.82544393 6456.09 35.93 124.82 5847.51 5910.90 1845.05 2023.84 2017.18 -1012.28 1744.79 1.92 5969286.75 644877.43 N 70.32349899 W 148.82524946 6506.09 36.68 124.84 5887.80 5951.19 1871.05 2053.44 2046.68 -1029.18 1769.09 1.50 5969270.31 644902.05 N 70.32345278 W 148.82505249 6556.09 37.51 125.31 5927.68 5991.07 1897.48 2083.60 2076.73 -1046.51 1793.77 1.75 5969253.46 644927.05 N 70.32340542 W 148.82485244 6606.09 37.79 125.36 5967.27 6030.66 1924.18 2114.14 2107.15 -1064.18 1818.69 0.56 5969236.27 644952.30 N 70.32335715 W 148.82465047 6656.09 37.90 125.78 6006.75 6070.14 1950.93 2144.82 2137.70 -1082.02 1843.64 0.56 5969218.91 644977.58 N 70.32330838 W 148.82444822 6706.09 37.58 126.29 6046.29 6109.68 1977.50 2175.42 2168.16 -1100.03 1868.39 0.89 5969201.38 645002.67 N 70.32325918 W 148.82424761 6756.09 37.63 126.39 6085.91 6149.30 2003.91 2205.93 2198.52 -1118.11 1892.96 0.16 5969183.78 645027.58 N 70.32320977 W 148.82404840 6806.09 37.46 126.30 6125.55 6188.94 2030.28 2236.40 2228.83 -1136.16 1917.51 0.36 5969166.19 645052.46 N 70.32316042 W 148.82384947 6856.09 37.44 126.84 6165.24 6228.63 2056.53 2266.80 2259.08 -1154.28 1941.92 0.66 5969148.55 645077.22 N 70.32311092 W 148.82365155 6906.09 36.94 127.37 6205.08 6268.4 7 2082.49 2297.03 2289.11 -1172.51 1966.03 1.19 5969130.78 645101.67 N 70.32306109 W 148.82.8 6956.09 36.97 127.43 6245.03 6308.42 2108.22 2327.09 2318.98 -1190.77 1989.91 0.09 5969112.98 645125.89 N 70.32301120 W 148.8232 62 7006.09 36.49 127.09 6285.10 6348.49 2133.86 2356.99 2348.70 -1208.87 2013.71 1.04 5969095.34 645150.03 N 70.32296172 W 148.82306972 7056.09 36.17 127.68 6325.38 6388.77 2159.22 2386.61 2378.14 -1226.86 2037.24 0.95 5969077.81 645173.90 N 70.32291257 W 148.82287895 7106.09 36.30 128.06 6365.71 6429.10 2184.39 2416.17 2407.48 -1245.00 2060.57 0.52 5969060.11 645197.57 N 70.32286299 W 148.82268984 7156.09 36.10 127.70 6406.06 6469.45 2209.55 2445.70 2436.81 -1263.13 2083.88 0.58 5969042.43 645221.22 N 70.32281344 W 148.82250092 7206.09 35.61 128.49 6446.59 6509.98 2234.43 2474.98 2465.89 -1281.20 2106.93 1.35 5969024.81 645244.60 N 70.32276406 W 148.82231411 7256.09 35.90 128.63 6487.16 6550.55 2259.13 2504.20 2494.88 -1299.41 2129.77 0.60 5969007.04 645267.79 N 70.32271429 W 148.82212894 7306.09 35.23 128.94 6527.84 6591.23 2283.66 2533.28 2523.72 -1317.63 2152.44 1.39 5968989.26 645290.80 N 70.32266451 W 148.82194521 7356.09 34.88 129.32 6568.77 6632.16 2307.78 2562.00 2552.18 -1335.75 2174.72 0.82 5968971.56 645313.42 N 70.32261498 W 148.82176465 7406.09 34.34 130.25 6609.92 6673.31 2331.47 2590.40 2580.29 -1353.92 2196.54 1.51 5968953.81 645335.58 N 70.32256532 W 148.82158776 7456.09 33.50 130.96 6651.41 6714.80 2354.51 2618.30 2607.86 -1372.08 2217.73 1.86 5968936.07 645357.11 N 70.32251570 W 148.82141607 7506.09 33.48 131.38 6693.11 6756.50 2377.14 2645.89 2635.08 -1390.24 2238.50 0.47 5968918.30 645378.22 N 70.32246607 W 148.82124775 7556.09 33.02 132.39 6734.92 6798.31 2399.43 2673.30 2662.08 -1408.54 2258.91 1.44 5968900.40 645398.97 N 70.32241605 W 148.82108233 7606.09 32.91 132.07 6776.87 6840.26 2421.45 2700.51 2688.85 -1426.83 2279.05 0.41 5968882.50 645419.46 N 70.32236608 W 148.82091906 7656.09 32.45 133.20 6818.96 6882.35 2443.20 2727.50 2715.39 -1445.11 2298.91 1.53 5968864.60 645439.67 N 70.32231611 W 148.82075809 7706.09 31.94 134.01 6861.27 6924.66 2464.38 2754.14 2741.51 -1463.48 2318.20 1.34 5968846.60 645459.30 N 70.32226591 W 148.82060175 7756.09 32.33 133.99 6903.61 6967.00 2485.42 2780.74 2767.55 -1481.96 2337.34 0.78 5968828.50 645478.78 N 70.32221542 W 148.8"0 7806.09 33.13 134.08 6945.67 7009.06 2506.79 2807.77 2794.03 -1500.75 2356.77 1.60 5968810.08 645498.57 N 70.32216407 W 148.8 9 7856.09 33.60 135.04 6987.43 7050.82 2528.38 2835.27 2820.93 -1520.04 2376.36 1.41 5968791.16 645518.52 N 70.32211134 W 148.82 42 7906.09 34.39 135.30 7028.88 7092.27 2550.14 2863.23 2848.22 -1539.87 2396.07 1.61 5968771.72 645538.60 N 70.32205716 W 148.81997070 7956.09 35.28 135.98 7069.92 7133.31 2572.22 2891.79 2876.06 -1560.29 2416.04 1.94 5968751.68 645558.96 N 70.32200135 W 148.81980888 8006.09 36.26 137.06 7110.49 7173.88 2594.52 2921.01 2904.47 -1581.50 2436.15 2.33 5968730.86 645579.46 N 70.32194339 W 148.81964593 8056.09 37.17 137.34 7150.57 7213.96 2617.11 2950.90 2933.46 -1603.43 2456.45 1.85 5968709.32 645600.18 N 70.32188346 W 148.81948135 8106.09 38.06 137.80 7190.18 7253.57 2640.04 2981.42 2963.02 -1625.96 2477.04 1.87 5968687.20 645621.20 N 70.32182190 W 148.81931451 8156.09 38.87 138.85 7229.33 7292.72 2663.13 3012.52 2993.06 -1649.19 2497.72 2.08 5968664.37 645642.31 N 70.32175841 W 148.81914695 8206.09 39.33 138.72 7268.13 7331.52 2686.38 3044.06 3023.48 -1672.91 2518.50 0.93 5968641.05 645663.54 N 70.32169359 W 148.81897858 8256.09 39.25 138.60 7306.83 7370.22 2709.77 3075.72 3054.07 -1696.68 2539.41 0.22 5968617.68 645684.90 N 70.32162863 W 148.81880911 8306.09 38.79 139.28 7345.68 7409.07 2732.92 3107.20 3084.46 -172D.42 2560.09 1.26 5968594.35 645706.02 N 70.32156377 W 148.81864155 8356.09 37.67 139.13 7384.95 7448.34 2755.57 3138.14 3114.31 -1743.84 2580.30 2.25 5968571.31 645726.68 N 70.32149976 W 148.81847774 SurveyEd/tor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) J-02\J-02\J-02BPB 1 \J-02 B PB 1 Generated 12/7/20046:49 AM Page 4 of 6 Comments Latitude Longitude N 70.32143625 W 148.81831629 N 70.32137273 W 148.81815641 N 70.32130998 W 148.81799878 N 70.32124740 W 148.81784387 N 70.32118489 W 148.81768965 8656.09 36.15 139.71 7624.64 7688.03 2886.31 3318.53 3288.27 -1881.69 2696.66 0.72 5968435.72 645845.64 N 70.32112305 W 148.81753488 8706.09 35.03 140.16 7665.30 7728.69 2907.37 3347.63 3316.39 -1903.96 2715.39 2.30 5968413.81 645864.79 N 70.32106220 W 148.81738310 8756.09 35.25 140.71 7706.18 7769.57 2928.01 3376.41 3344.14 -1926.15 2733.72 0.77 5968391.98 645883.54 N 70.32100157 W 148.81723458 8806.09 34.64 141.59 7747.17 7810.56 2948.31 3405.05 3371.68 -1948.45 2751.69 1.58 5968370.03 645901.92 N 70.32094062 W 148.81708901 8856.09 33.60 141.75 7788.56 7851.95 2968.01 3433.10 3398.60 -1970.45 2769.08 2.09 5968348.37 645919.73 N 70.32088050 W 148.81694807 8906.09 32.99 141.92 7830.35 7893.74 2987.23 3460.54 3424.94 -1992.03 2786.04 1.23 5968327.12 645937.10 N 70.32082153 W 148.81_ 8956.09 32.61 141.52 7872.38 7935.77 3006.23 3487.63 3450.96 -2013.29 2802.82 0.87 5968306.18 645954.28 N 70.32076343 W 148.81 9006.09 32.62 142.30 7914.50 7977.89 3025.08 3514.58 3476.85 -2034.50 2819.45 0.84 5968285.29 645971.30 N 70.32070547 W 148.816 00 9056.09 32.01 142.50 7956.75 8020.14 3043.60 3541.31 3502.47 -2055.68 2835.76 1.24 5968264.43 645988.01 N 70.32064760 W 148.81640786 9106.09 31.48 142.65 7999.27 8062.66 3061.78 3567.61 3527.69 -2076.57 2851.74 1.07 5968243.85 646004.39 N 70.32059051 W 148.81627833 9156.09 30.68 143.03 8042.10 8105.49 3079.53 3593.43 3552.41 -2097.14 2867.34 1.65 5968223.58 646020.37 N 70.32053430 W 148.81615200 9206.09 29.95 143.57 8085.26 8148.65 3096.74 3618.66 3576.54 -2117.37 2882.42 1.56 5968203.64 646035.84 N 70.32047900 W 148.81602979 9256.09 28.97 144.52 8128.79 8192.18 3113.27 3643.25 3599.96 -2137.27 2896.86 2.17 5968184.02 646050.66 N 70.32042462 W 148.81591280 9306.09 28.58 145.26 8172.62 8236.01 3129.18 3667.32 3622.80 -2156.96 2910.70 1.06 5968164.60 646064.87 N 70.32037081 W 148.81580065 9356.09 27.16 146.17 8216.82 8280.21 3144.38 3690.69 3644.89 -2176.27 2923.87 2.96 5968145.55 646078.41 N 70.32031805 W 148.81569395 9406.09 26.93 146.97 8261.35 8324.74 3158.91 3713.43 3666.27 -2195.24 2936.40 0.86 5968126.82 646091.29 N 70.32026621 W 148.81559249 9456.09 26.93 147.50 8305.93 8369.32 3173.17 3736.07 3687.49 -2214.29 2948.65 0.48 5968108.02 646103.90 N 70.32021417 W 148.81549320 9506.09 27.33 147.81 8350.43 8413.82 3187.41 3758.87 3708.83 -2233.55 2960.85 0.85 5968088.99 646116.47 N 70.32016153 W 148.81539439 9556.09 27.32 148.14 8394.85 8458.24 3201.63 3781.82 3730.27 -2253.01 2973.02 0.30 5968069.77 646129.01 N 70.32010836 W 148.81529579 9606.09 27.10 148.11 8439.32 8502.71 3215.76 3804.69 3751.63 -2272.42 2985.10 0.44 5968050.59 646141.45 N 70.32005531 W 148.81519799 9656.09 26.85 148.00 8483.88 8547.27 3229.79 3827.37 3772.84 -2291.67 2997.10 0.51 5968031.58 646153.81 N 70.32000272 W 148.81510078 9706.09 27.01 148.23 8528.45 8591.84 3243.78 3850.01 3794.03 -2310.90 3009.06 0.38 5968012.58 646166.13 N 70.31995018 W 148.81500388 9756.09 26.79 148.28 8573.04 8636.43 3257.72 3872.63 3815.20 -2330.13 3020.96 0.44 5967993.58 646178.40 N 70.31989761 W 148.81490747 9806.09 26.71 148.27 8617.69 8681.08 3271.57 3895.14 3836.27 -2349.28 3032.79 0.16 5967974.67 646190.60 N 70.31984530 W 148.8.1 GYD CT eMS 9856.09 26.78 148.32 8662.34 8725.73 3285.42 3917.64 3857.35 -2368.42 3044.62 0.15 5967955.75 646202.78 N 70.31979299 W 148.8 1 Tie-In Survey 9906.09 26.52 148.24 8707.03 8770.42 3299.23 3940.07 3878.37 -2387.50 3056.41 0.52 5967936.91 646214.94 N 70.31974086 W 148.81462030 Top Window 9916.00 26.59 148.29 8715.90 8779.29 3301.96 3944.50 3882.53 -2391.26 3058.74 0.74 5967933.18 646217.34 N 70.31973056 W 148.81460142 Base Window 9928.00 27.76 146.45 8726.57 8789.96 3305.40 3949.98 3887.70 -2395.88 3061.70 12.00 5967928.63 646220.38 N 70.31971795 W 148.81457747 Blind Surveys 9943.15 26.72 148.50 8740.04 8803.43 3309.75 3956.91 3894.24 -2401.72 3065.43 9.24 5967922.85 646224.22 N 70.31970198 W 148.81454726 9964.72 26.43 148.50 8759.33 8822.72 3315.66 3966.56 3903.29 -2409.95 3070.47 1.34 5967914.73 646229.42 N 70.31967950 W 148.81450642 9991.33 28.30 145.04 8782.97 8846.36 3323.45 3978.79 3914.88 -2420.17 3077.18 9.22 5967904.64 646236.32 N 70.31965157 W 148.81445207 10006.33 30.33 143.38 8796.04 8859.43 3328.37 3986.13 3921.94 -2426.13 3081.47 14.58 5967898.76 646240.73 N 70.31963530 W 148.81441725 10024.77 32.76 141.56 8811.76 8875.15 3335.05 3995.78 3931.29 -2433.77 3087.35 14.15 5967891.23 646246.76 N 70.31961440 W 148.81436962 End Blind Survey 10056.64 36.35 138.89 8838.00 8901.39 3348.08 4013.85 3948.97 -2447.65 3098.93 12.22 5967877.58 646258.59 N 70.31957648 W 148.81427584 First MWD + IFR 10087.90 41.54 136.63 8862.31 8925.70 3362.80 4033.49 3968.35 -2462.17 3112.15 17.21 5967863.31 646272.09 N 70.31953679 W 148.81416874 10120.87 50.52 133.53 8885.18 8948.57 3381.30 4057.19 3991.89 -2478.92 3128.92 28.06 5967846.89 646289.17 N 70.31949102 W 148.81403287 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) J-02\J-02\J-02BPB 1 \J-02BPB1 Generated 12/7/2004 6:49 AM Page 5 of 6 " ~ Comments Latitude Longitude N 70.31944548 W 148.81387389 N 70.31940167 W 148.81370020 N 70.31935200 W 148.81348352 N 70.31931847 W 148.81329744 10259.55 80.41 107.84 8933.58 8996.97 3494.54 4184.76 4118.13 -2547.99 3235.23 39.55 5967779.87 646396.77 N 70.31930220 W 148.81317134 10292.11 78.33 92.15 8939.62 9003.01 3526.36 4216.76 4146.26 -2553.54 3266.64 47.78 5967774.92 646428.28 N 70.31928700 W 148.81291680 10323.30 76.59 88.49 8946.39 9009.78 3556.64 4247.20 4170.39 -2553.71 3297.08 12.74 5967775.32 646458.71 N 70.31928649 W 148.81267007 10355.47 80.99 87.05 8952.65 9016.04 3587.84 4278.75 4194.61 -2552.48 3328.60 14.36 5967777.15 646490.20 N 70.31928982 W 148.81241455 10388.73 85.57 86.70 8956.54 9019.93 3620.42 4311.77 4219.74 -2550.68 3361.58 13.81 5967779.58 646523.13 N 70.31929470 W 148.81214727 10419.71 87.84 79.84 8958.32 9021.71 3650.53 4342.70 4242.05 -2547.06 3392.27 23.29 5967783.79 646553.75 N 70.31930456 W 148.81189845 10451.78 87.88 81.12 8959.52 9022.91 3681.37 4374.75 4264.21 -2541.76 3423.88 3.99 5967789.69 646585.25 N 70.31931900 W 148.81.5 10483.22 84.85 79.83 8961.51 9024.90 3711.55 4406.12 4286.01 -2536.57 3454.82 10.47 5967795.47 646616.08 N 70.31933314 W 148.81 4 10515.47 84.43 82.19 8964.52 9027.91 3742.53 4438.23 4308.67 -2531.55 3486.53 7.40 5967801.09 646647.69 N 70.31934681 W 148.8111 438 10547.87 84.85 89.74 8967.55 9030.94 3774.24 4470.49 4333.40 -2529.28 3518.68 23.24 5967803.97 646679.79 N 70.31935296 W 148.81087373 10579.38 89.42 99.59 8969.13 9032.52 3805.65 4501.95 4360.36 -2531.84 3550.00 34.42 5967802.01 646711.15 N 70.31934593 W 148.81061988 10611.94 94.15 103.07 8968.12 9031.51 3838.05 4534.48 4390.06 -2538.23 3581.90 18.03 5967796.23 646743.16 N 70.31932843 W 148.81036137 10643.95 94.25 101.78 8965.77 9029.16 3869.79 4566.41 4419.48 -2545.10 3613.07 4.03 5967789.96 646774.46 N 70.31930962 W 148.81010869 10676.15 91.88 96.54 8964.05 9027.44 3901.89 4598.56 4448.39 -2550.22 3644.80 17.84 5967785.45 646806.28 N 70.31929561 W 148.80985152 10707.18 89.52 96.98 8963.67 9027.06 3932.92 4629.58 4475.75 -2553.87 3675.61 7.74 5967782.39 646837.15 N 70.31928559 W 148.80960180 10740.24 90.31 95.92 8963.72 9027.11 3965.98 4662.64 4504.88 -2557.58 3708.46 4.00 5967779.30 646870.06 N 70.31927540 W 148.80933554 Last MWD + IFR 10772.74 90.17 99.30 8963.58 9026.97 3998.46 4695.14 4533.86 -2561.88 3740.67 10.41 5967775.61 646902.35 N 70.31926360 W 148.80907449 TD ( Projected) 10848.00 90.17 99.30 8963.36 9026.75 4073.62 4770.40 4602.12 -2574.05 3814.94 0.00 5967764.87 646976.83 N 70.31923027 W 148.80847253 Leoal DescriDtion: Survey Type: Definitive Survey NOTES: GYD CT CMS - ( Gyrodata - cont. casing mIs -- Gyrodata multishot surveys with continuous toll (RGS-CT) In casing. OD 13-3/8" or less.) MWD + IFR - ( In-field referenced MWD with time-varying field applied. Model is applicable whether or not Short Collar type correction is applied. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Surface: 4199 FSL 1245 FEL S9 T11 N R13E UM BHL: 1624 FSL 2716 FEL S10 T11N R13E UM Northina fYI rftUS1 5970265.49 5967764.87 Eastino (XI rftUS1 643113.79 646976.83 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) J-02\J-02\J-02BPB 1 \J-02BPB 1 Generated 1217/20046:49 AM Page 6 of 6 ?'" 7" Tieback LNR, 10 = 6.276" 7" DVCOLLAR 13-3/8" CSG, 68#, K-55, iD 12.415" - 4589' Top of 5-1/2" LNR - 9105' 9-5/8" x 7" 8KR Tieback LNR PKR Shoe - 9296' Top of 3-1/2" LNR - 9771' Top of Whipstock -9916' Tubing space out joints Insert LNDG Collar P8TD -9970' 5-1/2 LNR. 17#, L-80 9980' Kevlar Nylon Cent Arm 6-11/91 3 UR Arms 5-12-91 -10217' Est. - 3254' Est TOC - 5955' 4-1/2" T8G, 10 = 3.958" HES 4-112" X Nipple 10 = 3.813" 8KR 7" x 4-1/2" PKR @ 9036' HES 4-112" X Nipple 10 = 3.813" HES 4-1/2" XN Nipple 10 = 3.725" @ 4-1/2" WLEG @ 9093' 2974 7 5176 22 6781 26 7924 28 L-80, KBG2 WI DCK SHEAR KBG2 WI DUMMY K8G2 W/ DUMMY KBG2 WI DUMMY 2" 2" 2" 2" 2" 2" 6 1 - 10948' 6 10978' - 11098' 6 11328' - 11428' 6 11508' - 11608' 6 11648' - 11808' 6 11853' -11928' o o o o o o 11/15/2004 BP ..' ~ SCRLUMBERGER Survey report Client..... ..............: BP Exploration (Alaska) Inc. Field....................: Prudhoe Bay Well.....................: J-02B API number....... ..... ...: 50-029-20023-02 Engineer.................: M. Perdomo COUNTY:... ...... .........: North Slope Borough STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum... .......: MEAN SEA LEVEL Depth reference..........: Driller's Depth GL above permanent.......: 38.04 ft KB above permanent.......: N/A Top Drive DF above permanent... ....: 63.39 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.32626499 ft Departure (+E/W-) ........: W 148.83939503 ft Azimuth from rotary table to target: 96.28 degrees [(c)2004 IDEAL ID8 1C_02J Spud date................: Last survey date.. .......: Total accepted surveys...: MD of first survey.......: MD of last survey........: 27-0ct-04 09-Nov-04 70 9906.09 ft 12028.00 ft ----- Geomagnetic data ---------------------- Magnetic model. ..........: BGGM version 2004 Magnetic date............: 29-0ct-2004 Magnetic field strength..: 1152.31 RCNT Magnetic dec (+E/W-).....: 24.95 degrees Magnetic dip... ..........: 80.85 degrees ----- MWD survey Reference Reference G..............: Reference R..............: Reference Dip............: Tolerance of G...........: Tolerance of R........... : Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152 .31 RCNT 80.85 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.95 degrees Grid conve~gence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.95 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 . . ÂO t{ - J f <-( SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9906.09 26.52 148.24 0.00 8707.03 3299.23 -2387.50 3056.41 3878.38 128.00 0.00 TIP None 2 9916.00 26.59 148.29 9.91 8715.89 3301.96 -2391.27 3058.74 3882.53 128.02 0.74 BP ZERO None 3 9928.00 27.76 146.45 12.00 8726.57 3305.40 -2395.88 3061.70 3887.70 128.04 12.00 BP BLIND None 4 9943.15 26.72 148.50 15.15 8740.04 3309.75 -2401.73 3065.43 3894.24 128.08 9.24 BP INC TREND - 5 9964.72 26.43 148.50 21.57 8759.33 3315.66 -2409.95 3070.47 3903.29 128.13 1. 34 BP INC TREND 6 9991.33 28.30 145.04 26.61 8782.96 3323.45 -2420.18 3077.18 3914.88 128.18 9.22 BP INC TREND . - 7 10006.33 30.33 143.38 15.00 8796.04 3328.37 -2426.13 3081.47 3921.94 128.21 14.58 BP INC TREND - 8 10024.77 32.76 141.56 18.44 8811.76 3335.05 -2433.78 3087.35 3931.29 128.25 14 .15 BP INC TREND - - 9 10056.64 36.35 138.89 31. 87 8838.00 3348.08 -2447.65 3098.93 3948.97 128.30 12.22 BP INC TREND - 10 10087.90 41.54 13 6.63 31.26 8862.31 3362.80 -2462.18 3112.15 3968.35 128.35 17.21 MWD IFR None 11 10120.87 50.52 133.53 32.97 8885.18 3381. 30 -2478.92 3128.92 3991.89 128.39 28.06 MWD IFR None - 12 10152.42 59.10 127.46 31.55 8903.35 3402.63 -2495.58 3148.54 4017.61 128.40 31.39 MWD IFR None - 13 10182.38 67.72 126.17 29.96 8916.75 3425.69 -2511.61 3169.97 4044.37 128.39 29.03 MWD IFR None - 14 10216.28 77.80 122.32 33.90 8926.79 3454.26 -2529.78 3196.71 4076.61 128.36 31.64 MWD IFR None - 15 10228.22 75.57 121.64 11.94 8929.54 3464.72 -2535.93 3206.57 4088.16 128.34 19.48 MWD IFR None 16 10260.17 78.26 120.80 31. 95 8936.77 3492.94 -2552.06 3233.18 4119.04 128.29 8.80 MWD IFR None - 17 10290.64 80.54 120.23 30.47 8942.38 3520.25 -2567.27 3258.98 4148.71 128.23 7.71 MWD IFR None - 18 10322.67 84.48 118.58 32.03 8946.55 3549.45 -2582.85 3286.64 4180.09 128.16 13.32 MWD IFR None - 19 10354.45 85.64 115.31 31.78 8949.29 3579.07 -2597.20 3314.86 4211. 15 128.08 10.88 MWD IFR None - 20 10388.08 87.67 109.22 33.63 8951.25 3611.33 -2609.91 3345.91 4243.44 127.96 19.06 MWD IFR None 21 10419.45 87.88 100.95 31.37 8952.47 3642.28 -2618.06 3376.15 4272.31 127.79 26.35 MWD IFR None . - 22 10451.24 88.73 95.52 31.79 8953.41 3674.02 -2622.61 3407.59 4299.97 127.58 17.28 MWD IFR None - 23 10487.29 90.58 91.21 36.05 8953.63 3710.02 -2624.73 3443.57 4329.82 127.32 13.01 MWD IFR None - 24 10518.79 92.09 83.37 31.50 8952.90 3741.09 -2623.24 3475.00 4353.96 127.05 25.34 MWD IFR None - 25 10546.39 91. 75 78.41 27.60 8951.97 3767.68 -2618.87 3502.23 4373.11 126.79 18.00 MWD IFR None 26 10578.15 90.48 74.79 31.76 8951.35 3797.58 -2611.51 3533.11 4393.50 126.47 12.08 MWD IFR None - 27 10610.91 89.35 76.71 32.76 8951.40 3828.25 -2603.45 3564.86 4414.32 126.14 6.80 MWD IFR None - 28 10643.89 88.80 77.36 32.98 8951.93 3859.39 -2596.05 3597.00 4435.97 125.82 2.58 MWD IFR None - 29 10674.24 88.77 84.96 30.35 8952.58 3888.66 -2591.39 3626.96 4457.59 125.55 25.04 MWD IFR None - 30 10707.82 91.82 90.73 33.58 8952.41 3921.86 -2590.13 3660.49 4484.19 125.28 19.43 MWD IFR None [(c)2004 IDEAL ID8_1C_02J _ 4 SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 10739.95 93.64 97.29 32.13 8950.87 3953.91 -2592.37 3692.49 4511.64 125_07 21.17 MWD IFR None - 32 10771.62 92.74 97.65 31. 67 8949.11 3985.52 -2596.48 3723.84 4539.68 124.89 3.06 MWD IFR None - 33 10803.07 92.40 96.71 31. 45 8947.70 4016.93 -2600.41 3755.01 4567.52 124.70 3.18 MWD IFR None - 34 10833.85 90.07 91.59 30.78 8947.04 4047.67 -2602.64 3785.69 4594.04 124.51 18.27 MWD IFR None - 35 10868.76 89.18 93.01 34.91 8947.26 4082.50 -2604.04 3820.57 4623.61 124.28 4.80 MWD IFR None 36 10900.55 88.97 93.75 31.79 8947.78 4114.24 -2605.91 3852.30 4650.92 124.08 2.42 MWD IFR None . - 37 10930.97 89.28 90.18 30.42 8948.24 4144.57 -2606.95 3882.70 4676.70 123.88 11.78 MWD IFR None - 38 10963.63 89.62 84.76 32.66 8948.56 4176.83 -2605.51 3915.31 4703.02 123.64 16.63 MWD IFR None - 39 10995.70 89.35 85.07 32.07 8948.84 4208.27 -2602.67 3947.26 4728.08 123.40 1. 28 MWD IFR None - 40 11027.16 88.66 91.53 31.46 8949.39 4239.40 -2601.74 3978.68 4753.83 123.18 20.65 MWD IFR None 41 11060.30 92.06 88.37 33.14 8949.18 4272.33 -2601.71 4011.81 4781.58 122.96 14.01 MWD IFR None - 42 11092.08 90.82 92.38 31.78 8948.38 4303.92 -2601.92 4043.57 4808.37 122.76 13 .20 MWD IFR None - 43 11125.36 90.96 88.61 33.28 8947.87 4337.02 -2602.20 4076.84 4836.54 122.55 11.33 MWD IFR None - 44 11156.34 90.17 92.06 30.98 8947.56 4367.83 -2602.38 4107.81 4862.77 122.36 11. 42 MWD IFR None - 45 11188.32 90.21 90.25 31.98 8947.46 4399.68 -2603.03 4139.79 4890.15 122.16 5.66 MWD IFR None 46 11221.19 90.14 89.56 32.87 8947.35 4432.35 -2602.97 4172.66 4917.98 121.96 2.11 MWD IFR None - 47 11254.01 89.90 89.48 32.82 8947.34 4464.94 -2602.70 4205.47 4945.71 121. 75 0.77 MWD IFR None - 48 11283.71 90.65 89.18 29.70 8947.20 4494.42 -2602.35 4235.17 4970.81 121. 57 2.72 MWD IFR None - 49 11316.66 91.51 85.86 32.95 8946.58 4526.98 -2600.93 4268.08 4998.13 121.36 10.41 MWD IFR None - 50 11347.55 91. 51 85.40 30.89 8945.76 4557.32 -2598.57 4298.87 5023.23 121.15 1. 49 MWD IFR None 51 11380.57 91.85 84.52 33.02 8944.80 4589.69 -2595.67 4331.75 5049.91 120.93 2.86 MWD IFR None . - 52 11413.05 91.65 83_72 32.48 8943.80 4621.42 -2592.35 4364.04 5075.94 120.71 2.54 MWD IFR None - 53 11445.28 91.75 82.55 32.23 8942.85 4652.79 -2588.50 4396.03 5101.51 120.49 3.64 MWD IFR None - 54 11476.70 90.82 86.30 31. 42 8942.14 4683.53 -2585.45 4427.28 5126.93 120.28 12.29 MWD IFR None - 55 11507.44 91.27 82.20 30.74 8941.58 4713.58 -2582.37 4457.86 5151.81 120.08 13 .42 MWD IFR None 56 11538.96 90.17 87.12 31.52 8941.19 4744.45 -2579.44 4489.23 5177.51 119.88 15.99 MWD IFR None - 57 11571.44 90.65 87.25 32.48 8940.95 4776.52 -2577.84 4521.67 5204.88 119.69 1.53 MWD IFR None - 58 11603.21 90.86 85.80 31.77 8940.54 4807.82 -2575.92 4553.38 5231.50 119.50 4.61 MWD IFR None - 59 11635.29 90.48 85.09 32.08 8940.16 4839.33 -2573.37 4585.35 5258.11 119.30 2.51 MWD IFR None - 60 11667.27 88.94 89.47 31.98 8940.32 4870.91 -2571.85 4617.29 5285.24 119.12 14.52 MWD IFR None [(c)2004 IDEAL ID8_1C_02J - SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 11698.53 88.49 92.13 31.26 8941.02 4902.01 -2572.29 4648.53 5312.77 118.96 8.63 MWD IFR None - 62 11730.31 88.70 85.65 31.78 8941.80 4933.50 -2571.67 4680.28 5340.27 118.79 20.40 MWD IFR None - 63 11761.56 88.25 89.34 31.25 8942.64 4964.37 -2570.31 4711.48 5366.99 118.61 11.89 MWD IFR None - 64 11793.93 87.84 89.25 32.37 8943.74 4996.48 -2569.91 4743.83 5395.22 118.45 1. 30 MWD IFR None - 65 11825.82 87.29 88.71 31.89 8945.09 5028.08 -2569.34 4775.69 5422.98 118.28 2.42 MWD IFR None 66 11858.51 87.33 83.44 32.69 8946.63 5060.21 -2567.11 4808.25 5450.63 118.10 16.10 MWD IFR None . - 67 11890.20 86.61 88.65 31.69 8948.31 5091.34 -2564.93 4839.81 5477.47 117.92 16.57 MWD IFR None - 68 11922.50 87.16 87.46 32.30 8950.06 5123.26 -2563.83 4872.05 5505.46 117.75 4.05 MWD IFR None - 69 11961.75 86.64 87.36 39.25 8952.18 5161. 98 -2562.06 4911.20 5539.32 11 7.55 1. 35 MWD IFR None - 70 12028.00 86.64 87.36 66.25 9019.46 5227.32 -2559.01 4977.26 5596.58 117.21 0.00 Projection to TD [(c)2004 IDEAL ID8 1C_02J . - !! SCRLUMBERGER Survey report Client.............. .....: BP Exploration (Alaska) Inc. Field............. .......: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: J-02BPBl API number.. ........... ..: 50-029-20023-70 Engineer... .......... ....: M. Perdomo COUNTY:.. ........... .....: North Slope Borough STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..... .....: MEAN SEA LEVEL Depth reference.... ......: Driller's Depth GL above permanent. ......: 38.04 ft KB above permanent.......: Top Drive N/A DF above permanent.......: 63.39 ft ----- Vertical section origin---------------- Latitude (+N/S-)... ......: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-). ........: N 70.32626499 ft Departure (+E/W-) ........: W 148.83939503 ft Azimuth from rotary table to target: 96.28 degrees [(c)2004 IDEAL ID8 lC 02] Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: 27-0ct-04 04-Nov-04 33 9906.09 ft 10848.00 ft . ----- Geomagnetic data ---------------------- Magnetic model....... ....: BGGM version 2004 Magnetic date............: 03-Nov-2004 Magnetic field strength..: 1152.32 RCNT Magnetic dec (+E/W-) .....: 24.95 degrees Magnetic dip.............: 80.85 degrees ----- MWD survey Reference Reference G..............: Reference R..............: Reference Dip............: Tolerance of G...........: Tolerance of R. ..... .....: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152.32 RCNT 80.85 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 24.95 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 24.95 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 JvD~- L~ ~ SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9906.09 26.52 148.24 0.00 8770.42 3299.35 -2387.65 3056.51 3878.55 128.00 0.00 TIP None 2 9916.00 26.59 148.29 9.91 8779.28 3302.07 -2391.42 3058.84 3882.70 128.02 0.74 BP ZERO None 3 9928.00 27.76 146.45 12.00 8789.96 3305.52 -2396.03 3061.80 3887.87 128.05 12.00 BP BLIND None - 4 9943.15 26.72 148.50 15.15 8803.43 3309.86 -2401. 88 3065.53 3894.41 128.08 9.24 BP INC TREND - - 5 9964.72 26.43 148.50 21. 57 8822.72 3315.78 -2410.10 3070.57 3903.46 128.13 1. 34 BP INC TREND 6 9991.33 28.30 145.04 26.61 8846.35 3323.56 -2420.33 3077.28 3915.05 128.19 9.22 BP INC TREND . - - 7 10006.33 30.33 143.38 15.00 8859.43 3328.49 -2426.28 3081.57 3922.11 128.22 14.58 BP INC TREND - - 8 10024.77 32.76 141.56 18.44 8875.15 3335.17 -2433.93 3087.45 3931.46 128.25 14.15 BP INC TREND - - 9 10056.64 36.35 138.89 31. 87 8901.39 3348.19 -2447.80 3099.03 3949.14 128.30 12.22 BP INC TREND - - 10 10087.90 41.54 136.63 31. 26 8925.70 3362.92 -2462.33 3112.25 3968.52 128.35 17.21 MWD IFR None 11 10120.87 50.52 133.53 32.97 8948.57 3381.42 -2479.07 3129.02 3992.06 128.39 28.06 MWD IFR None - 12 10152.42 59.10 127.46 31. 55 8966.74 3402.75 -2495.73 3148.64 4017.79 128.40 31. 39 MWD IFR None - 13 10182.38 67.72 126.17 29.96 8980.14 3425.80 -2511.76 3170.07 4044.54 128.39 29.03 MWD IFR None - 14 10216.28 77.80 122.32 33.90 8990.18 3454.37 -2529.93 3196.81 4076.78 128.36 31. 64 MWD IFR None - 15 10242.71 83.16 113.97 26.43 8994.56 3478.54 -2542.20 3219.77 4102.40 128.29 37.17 MWD IFR None 16 10259.55 80.41 107.84 16.84 8996.96 3494.65 -2548.14 3235.33 4118.30 128.22 39.55 MWD IFR None - 17 10292.11 78.33 92.15 32.56 9003.01 3526.48 -2553.69 3266.74 4146.44 128.02 47.78 MWD IFR None - 18 10323.30 76.59 88.49 31.19 9009.78 3556.75 -2553.87 3297.18 4170.57 127.76 12.74 MWD IFR None - 19 10355.47 80.99 87.05 32.17 9016.03 3587.95 -2552.64 3328.70 4194.78 127.48 14.36 MWD IFR None - 20 10388.73 85.57 86.70 33.26 9019.92 3620.53 -2550.84 3361. 68 4219.91 127.19 13.81 MWD IFR None 21 10419.71 87.84 79.84 30.98 9021.71 3650.65 -2547.21 3392.37 4242.22 126.90 23.29 MWD IFR None . - 22 10451.78 87.88 81. 12 32.07 9022.90 3681. 48 -2541.91 3423.98 4264.38 126.59 3.99 MWD IFR None - 23 10483.22 84.85 79.83 31.44 9024.90 3711.67 -2536.72 3454.92 4286.19 126.29 10.47 MWD IFR None - 24 10515.47 84.43 82.19 32.25 9027.91 3742.64 -2531.70 3486.63 4308.84 125.98 7.40 MWD IFR None - 25 10547.87 84.85 89.74 32.40 9030.94 3774.36 -2529.44 3518.78 4333.58 125.71 23.24 MWD IFR None - 26 10579.38 89.42 99.59 31. 51 9032.52 3805.77 -2532.00 3550.10 4360.53 125.50 34.42 MWD IFR None - 27 10611. 94 94.15 103.07 32.56 9031.50 3838.17 -2538.39 3582.00 4390.23 125.32 18.03 MWD IFR None - 28 10643.95 94.25 101.78 32.01 9029.16 3869.91 -2545.25 3613.17 4419.65 125.16 4.03 MWD IFR None - 29 10676.15 91.88 96.54 32.20 9027.44 3902.01 -2550.37 3644.91 4448.56 124.98 17.84 MWD IFR None - 30 10707.18 89.52 96.98 31. 03 9027.06 3933.03 -2554.02 3675.71 4475.92 124.79 7.74 MWD IFR None [(c)2004 IDEAL ID8_1C_02] . SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 10740.24 90.31 95.92 33.06 9027.11 3966.09 -2557.74 3708.56 4505.05 124.59 4.00 MWD IFR None - 32 10772.74 90.17 99.30 32.50 9026.97 3998.58 -2562.04 3740.77 4534.03 124.41 10.41 MWD IFR None 33 10848.00 90.17 99.30 75.26 9026.75 4073.74 -2574.20 3815.04 4602.29 124.01 0.00 Projection to TO [(c)2004 IDEAL 108 1C 02J . . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No J-02B Date Dispatched: 27-0ct-04 Installation/Rig Doyon 16 Dispatched By: J.Bosse Data No Of Prints No of Floppies Surveys 2 1 Received By: ./1 / , LI. Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-11 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address:johnsojh@bp.com . , '- J (ÿ JJ~\ , !~ Nw )JM~I LWD Log Delivery V1.1, 10-02-03 Schlumberger Private J. OLf-!ty r- (/ I-i ~L . . Schlumberger Drilling & Measurements MWD/LWD Log Product Deliverv Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No J-02B PB1 Date Dispatched: 27-0ct-04 Installation/Rig Doyon 16 Dispatched By: J.Bosse Data No Of Prints No of Floppies Surveys 2 Received By: ./1/ ~J~^ J rJJll ~I ! y AJ~v ~vt Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Genter (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private tÀóL{ -( ~ y F:L(C . ,. ~TI TIŒ ffi)~ . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay J-02B BP Exploration (Alaska) Inc. Permit No: 204-184 Surface Location: 1080' SNL, 1245' WEL, SEC. 09, TIIN, R13E, UM Bottomhole Location: 3663' SNL, 3727' EWL, SEC. 10, TIIN, RI3E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-36 (pager). BY ORDER OE THE COMMISSION DATED thisj¡[ day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~4j'\- 'II zI ¡toot . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION~OMMISSION CEIVE.D. PERMIT TO DRILL RE 20 MC 25.005 ~¡:p 1 ~ 7n04 1a. Type of work o Drill III Redrill rb. Current Well Class o Exploratory II Development Oil 0 Multiple Zqne. ORe-Entry o Stratigraphic Test o Service ÕA9~~ewr¡rneJtt r.~i ~~~W9mmrsSIOn 2. Operator Name: 5. Bond: 1m Blanket o Single Well 11. Well Na~11~~~b~ BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11975 TVD 9007 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028281 1080' SNL, 1245' WEL, SEC. 09, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3621' SNL, 2149' EWL, SEC. 10, T11N, R13E, UM September 26, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3663' SNL, 3721' EWL, SEC. 10, T11N, R13E, UM 2560 18,300' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: X-643114 y- 5970265 Zone- ASP4 (Height above GL): 57.3' feet J-17B is 600' away at 9906' 16. Deviated Wells: Kickoff Depth: 9890 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 92.5 dearees Downhole: 3140 Surface: 2260 1 !i. Casing Program: Specifications $ettingDèpth Y' Size Tóp< . . Bottom (c.t. VI """""'Q/ . Hole Casina Weiaht Grade CouplinQ LenQth MD TVD MD TVD (includinQ staQe data) 7" 5-1/2" 17# L-80 Hvdrill 1071' 9146' 8096' 10211' 9049' 291 sx Class 'G' (Scab Liner) ./ 4-3/4" 3-1/2" 9.2# L-80 IBT-M 2235' 9740' 8621' 11975' 9001' 170 sx Class 'G' " 19. PRESENT WELL CONDlTIONSUMMAR'Y (To be . completecf for RecJril.IANP8~e!1tI)'Opêratio!1$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 10420 9232 9187 10355 9173 10217 ~;,¡.,i"" . "'Atítífli i~i;Zêi i.. if i .iif. .i..iii. if MD. ii ..'.'.if)(Q..;... Strudural 70' 30" 175 sx Fondu / Flv Ash 70' 70' Conductor 931' 20" 2000 sx Fondu I Fly Ash 931' 931' ~. ~- 4589' 13-3/8" 3150 sx Class 'G' 4589' 4348' Intermediate Procluction 10410' 10-3/4" x 9-518" 1370 sx Class 'G', 725 sx Class 'G' 10410' 9223' Liner Tieback Liner 9296' 7" 17 sx Class 'G', 118 sx Arcticset 9296' 8226 Perforation Depth MD (ft): 10180' - 10200' IPerfOration Depth TVD (ft): 9015' - 9033' 20. Attachments 1m Filing Fee, $100 o BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name Bill Isaacson Title Senior Drilling Engineer 1 ~.lL L L-- Cf!I(,,¡ Prepared By Name/Number: Signature Phone 564-5521 Date d'1 Terrie Hubble, 564-4628 .·fi ."....,............... i.·..·.. iif.t.'. ¡.i!;it ; ..i·i.}f·f.t.; ....fi; if iiii·.·...... ·ii·····...i.··. it.i Permit To Drill I API Number: I Permit Approval. .~ I ~ee cover letter for Number: 2. os.-' - /Ifle/ 50- 029-20023-02-00 Date: Q/,;2/ tl d lather requirements Conditions of Approval: Samples Required DYes M'No Mud Log Required DYes ~No Hydrogen Sulfide Measures ~Yes 0 No Directional Survey Required }}!Yes D No Other:T€ S + Eo P E -l-o 's ~CD yJS / ~~..f" t.o, S I ",OVe du vì ~l cy2€r t\.t",~'Yl 1. a."p P Iv if e d iliA~401. ' UKIG¡I\~AL APPROVED BY Date 9/u /ðl{V ADDroved . A /' THE COMMISSION Form 10-401 Rev~d 06~4 -- (Subm/t In Duplicate . . Planned Well Summary Well J-02B Sidetrack 1 horizontal Zone 1 B I AFE Number: I PBD 4P2288 I I API Number: I 50-029-20023-02 Surface Offsets TRS Location 1080' FNL 11,245' FEL 11 N, 13 E, 09 ,-/ Target Offsets TRS Location 3627' FNL 13131' FEL 11 N, 13 E, 10 Target Offsets TRS Location 3685'FNL/2443'FEL 11 N, 13E, 10 Bottom Offsets TRS Location 3,663' FNL 11553' FEL 11 N, 13E,10 / Planned KOP: Planned S ud: I Planned TD: I Planned TVD: 9,890' md 09/26/04 11,975' md 9,007' / I Rig: I Nabors 2ES I / I BFE: 128.8' I RTE: 157.3' Proximity Issues: Directional Proaram WP06 Exit oint: 9,890' md 18,698' sstvd -390 at 8,200' in the original well bore, -92.50 at -11,700' in the planned 4-3/4" roduction horizontal. There are three wells that need to be risk based to pass BP anti-collision criteria. J-15B and J-17B are risked based to 1:500 and J-17BPB1 is risked to 1 :200. All other wells ass ma'or risk criteria. Standard MWD+IIFR+MS Well J-17B, with center-to-center distance of -600' at 9,906' md KOP. 18,300' to the nearest PBU ro e line. Maximum Hole Inclination: Logging ProGram Required Sensors 1 Service Real time MWD Dir/GRlRes throu hout the interval. Two sam Ie catchers will J-02B Sidetrack Version 1.0 Page 1 . Cased Hole: o en Hole: . be re uired at com an man call out. RST lanned POST ri None lanned Mud Program Funnel Vis 50 - 60 H 9.0-9.5 Casing I Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size / / md I tvd md I tvd 7" 5-1/2" Scab liner 17.0# l-80 Hvrdrill 521 1,071' 9,146' /8,096' 10,217'/9,049' 4-3/4" 3-1/2" 9.2# l-80 IBT-M 2235' 9,740' /8,621' 11,975'/9 007' Tubing 4-1/2" 12.6# 13Cr-80 VAM TOP 9,146' Surface 9,146' /8,096' Slurry Design Basis: Fluids Sequence / Volume: Slurry Design Basis: Fluids Sequence I Volume: J-02B Sidetrack Version 1.0 Cementing Program / cf/sk. Page 2 . . Casina I Formation Intearity Testina Test Test Point Landin collar to surface 20' be ond middle of window Test Type 30 min recorded FIT Test pressure 3,500 si surface 10 EMW Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an / annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. ..-- DisDosal Annular In ection: Cuttings Handling: Fluid Handling: No annular in'ection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at D5-04. An metal cuttin s should be sent to the North 510 e Borou h. All drilling and completion fluids and other Class II wastes are to be hauled to D5-04 for in·ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Proanosis Formation MD TVDss Comments Kickoff 9890 8698 25N 9973 -8770 3140 psi @ 8800 22N 10063 8840 PGOC 10139 -8890 21N 10156 -8900 TZ1B 10269 -8950 MHO/HOT 10389 -8970 J-02B Sidetrack Version 1.0 Page 3 . . TD Criteria TD Criteria: The plan is to drill to the planned to TD of 11975' md. The well bore will not be extended as all the polygons are hard lines. The possibility of stopping early is very small and would require a minimum of 600' of perforable sands. Fault Proanosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 Zone 1 B 10,350' 8,967' -10' West +1- 100' Fault #2 Zone 1 B 11 ,150' 8,946' < 10' West +1- 100' NOTE: Fault #1 is considered low risk for lost circulation and hole stability problems. Fault #2 is also considered a low risk and is not visible on seismic, but is inferred based on nearby fault patterns. Overall the risk of faults and fracture associated lost circulation is low in the target area. Qperations SUmmary Pre-Ria ODerations: 1. Bleed OOA, OA, IA and tubing pressures to zero. Test the 7" and Tubing pack-offs. Function all LDS. repair or replace as necessary. 2. MIT the OA to 2000 psi. CMIT IA and Tubing to 3500 psi for 30 minutes. 3. RU Slick-line. Drift the tubing with gauge rig I junk basket to the 4-1/2" x 3-1/2" crossover at 9186', POOH. Pull XX plug from the X profile at 9187', POOH. 4. RU E-line. RIH with Gamma Ray I CCL tool and tag top offish - 10217', log from fish up to X nipple at 9187' to tie into jewelry log. This log will be used to optimize the KOP (avoid cutting a collar and verify TCGL). Perform tubing punch in 2-7/8" pup joint of tubing just below the x nipple located at 9253'. This places the holes about 9256'. This hole will alleviate some of the possible gas trapped behind the tail pipe during milling operations with the rig. 5. RU Slick-line. Set a plug in the x nipple at 9253' Oust above the previous tubing punch}. This plug will act as a barrier for Nabors 2ES while rigging up. It will also act as a bottom to aid circulating out the gas and freeze protection job. 6. RU E-line. RIH and perform tubing punch (above packer), POOH. RIH and perform string shot at - 9165', POOH. RIH and chemical cut the 4-1/2" tubing in the middle of joint #1 - 9165' Oust below sliding sleeve and just above the 4-1/2" x 3-1/2" crossover}. 7. Circulate the well to seawater. Freeze protect the IA and tubing with diesel to - 2200'. 8. Bleed all pressures to zero. Set BPV. Secure well. 9. Remove the well house. If necessary, level the pad. Ria ODerations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to Sea Water. 3. Monitor OA. IA and T for pressure. Verify well is dead. 4. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 5. Pull 4-1/2" tubing from pre-rig cut at - 9165'. (Have a spear on location as a contingency). 6. PU overshot assy. RIH picking up 4" DP. Washover tubing stub and rotate latch assy free, POOH. NOTE: If SBR rotates free a second trip to retrieve the latch assy. will be required. 7. PU packer mill and PRT assy. RIH, engage PRT and mill until packer releases as per Baker representative, POOH with packer and 2-7/8" tailpipe assy. J-02B Sidetrack Version 1.0 Page 4 . . 1 8. PU 6-1/8" mill assembly on OP. RIH to drift the 7" 26# liner and verify PBTO inside the 9-5/8" casing. Note: If loses are present a LCM pill will need to be pumped and squeezed, while on bottom, to heip guarantee a good cement job between the 5-1/2" and 9-5/8" casing. 9. Run and cement a 5-1/2" 17# liner from the previously found PBTO, inside 9-5/8" casing, up 150' into the 7" tie-back to 9146'. Space out 5-1/2" liner so the collars are at similar depths as that of the 9-5/8" collars to limit possibility of cutter either one during the window milling job. Space out insert landing collar to limit spacing pups needed for the bottom of the whipstock. Set hanger / liner top packer as per Baker recommended procedure and displace cement with sea water, POOH to - 8500' (or maximum hanging weight on 7" RTTS). 10. PU and MU HES 7" RTTS. RIH and set RTTS below the wellhead and change out 7" packoff. POOH and lay down liner running tools. 11. PU 5-1/2" milling assy. RIH and tag landing collar, pressure test wellbore to 3500 psi for 30 minutes. POOH. ¡ lts 10" 4 (.') i MW tV Ij ",-I, 12. RIH with 5-1/2" whipstock and milling assy. to tHe top of landing collar. Add extra tubing pup joints to . the bottom of the whipstock so window is milled just below the base of Zone 3, but avoids casing / collars in both the 5-1/2" and 9-5/8" casings - 9890'. Orient and set whipstock, swap over to 8.5 ppg mud before milling the window. 13. Mill a window through both the 5-1/2" and 9-5/8" casings at -9890' plus 20' from mid window. Perform FIT to 10.0. POOH for drilling BHA. 14. MU the 4-3/4" drilling assembly with OIR/GR/RES and RIH. Kick off and drill 4-3/4" production interval /" as per directional plan to an estimated TO of 11975'. 15. Run and cement a 3-1/2", 9.2#, L-80 liner throughout the 4-3/4" wellbore and 150' back into the 5-1/2" liner to 9,740' MO. Set liner top packer and displace well to clean seawater above the liner top. ,/ 16. RIH with OPC perf guns, Perf intervals to be determined from LWO logs. Plan to perforate overbalance. POOH, LO OP and perf guns / 17. Run 4-1/2", 12.6#, 13Cr-80 completion tying into the 5-1/2" scab liner top. 18. Set packer, test and record the tubing to 3500 psi and annulus to 3500 psi for 30 minutes each. 19. Set and test TWC to 1000 psi. 20. NO BOPE. NU and test the tree to 5000 psi. Pull TWC. ' 21. Freeze protect the well to -2200'. Set BPV and secure the well. 22. ROMO. Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. MIRU E-line. Run RST log. 4. MIRU slickline. Install gas lift valves. Job 1: Move In I Rig Up I Test BOPE Planned Phase Time 30 hours Planned Phase Cost $78,302 Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. .:. "Hydrogen Sulfide" SOP. .:. "ADW Rig Move" RP. Issues and Potential Hazards ~ BOP test interval during this phase is 7 days. J-02B Sidetrack Version 1.0 Page 5 . . ~ No wells will require shut-in for the rig move onto J-02A. However, JX-02A is about 70' to the North. JX-02A is the closest surface neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ The J-02A well bore will be secured with the following barriers, (A plug in the 2-7/8" tail pipe. kill weight fluid and annular valves). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ J·Pad i!!JJPlg~signated as an HzS site. Standard Operating Procedures for HzS precautions should be followed at all times. Recent HzS data from the pad is as follows: #1 Closest SHL with H2S Readin #2 Closest SHL with H2S Readin #1 Closest BHL with H2S Readin #2 Closest BHL with H2S Readin Max Recorded H2S Readin on the Pad Well Name JX-02A J-03 J-15B J-14A J-26 Date 8/18/2000 12/18/2003 7/11/2002 9/20/00 ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ~ Note that the J-02 was not sidetracked, but deepened from the Put River formation to the Ivishak and renamed to J-02A. Job 2: De-complete Well Planned Phase Time 134 hours Planned Phase Cost $489,480 Reference RP .:. "De-completions" RP .:. "Baker 5-1/2" x 7" HMC hyrdraulic set LNR hanger with ZXP packer" procedure Issues and Potential Hazards ~ BOP test interval during this phase is 7 days. ~ The J-02A well bore will be secured with 2 barriers, (A plug in the 2-7/8" tail pipe and kill weight fluid). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ Monitor the well to ensure the fluid column remains static prior to pulling the completion. ~ Note and record required PU weight to pull tubing at cut point (-9,165'). ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ This wellhead is mixture of Cameron and McEvoy equipment. The pre-rig inspection drawing has been included in this program. The tubing hanger is most likely a 12" X 4.5" CS Hydril top and bottom. The tubing tally states 4-1/2" CS Hydril threads, but the drawing states 4-1/2" Buttress threads. Have both threads and a spear on location as a contingency. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. ~ There is a 4-1/2" K valve nipple with a W' encapsulated control line at 2028'. There are an unknown number of steel bands securing the control line. The well plan called for 110 steel bands, but the well record does not list the actual number ran. ~ The BOT 3H packer will be milled and removed from the well bore along with the 2-7/8" tail pipe. The perforations were not P & A'd with cement in order to avoid any possibility of complicating the packer milling and pulling. J-02B Sidetrack Version 1.0 Page 6 . . » The 5-1/2" scab liner cement job is critical to the success of the 2 string milling job to exit the current well bore. The losses to the perforations will need to be stopped prior to the cement job. » The 5-1/2" collars will need to be spaced out to line up with the 9-5/8" collars logged during the pre-rig operations. This will help avoid milling a collar in either string while exiting the parent well bore. An extra 1 0' and 20' pup joint have been made to aid this space out. During this space out the 4 centrilizer collars will need to be placed in the joints above and below (surrounding) the KOP. Job 3: Run Whiø Stock Planned Phase Time 60 hours Planned Phase Cost $297,993 Reference RP .:. "Whipstock Sidetrack" RP. .:. "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards » BOP test interval during this phase is 7 days until the window i~ milled into formation. Once the window is milled the 14 day test cycle starts and continues until the rig moves off the well. » A 5-1/2 whip stock will be run and set in the previously installed 5-1/2" scab liner. » According to the cement bond log, there should be cement behind the 9 5/8" casing at the sidetrack point. » There is the possibility of a centralizer on the 9-5/8" casing at window milling depth. 9-5/8" casing running notes state centralizers will be run on the bottom 25 joints (-1000'). The Baker centralizers were run at 20' & 60' above the shoe using Weatherford stop rings latched over the collars at the top of joints 3 to 25. » The attempt will be to cut the window below Zone 3 near the top of Zone 2. Chert, pyrite, and conglomerates maybe present while milling the window. » The window will be milled through 2 strings of casing and is planned to be done in 2 runs. The first BHA will be a standard whipstock setting / milling BHA. The second BHA will consist of a mud motor, watermelon mill and diamond speed mill to finish the milling of the window. » Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. » Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Job 7: Drill 4-3/4" Production Hole Interval Planned Phase Time 160 hours Planned Phase Cost $812,762 Reference RP .:. "Leak-off and Formation Integrity Tests" SOP J-02B Sidetrack Version 1.0 Page 7 . . .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Managemenf' RP Issues and Potential Hazards þ> The parent J-02A wellbore does not have a history of losses. The J-02B wellbore crosses two possible faults, but they are both considered to have a low probability of losses or hole stability problems associated with them. The J-02B sidetrack area is a complex area, but the proposed wellpath maximizes standoff from mapped faults tips and damaged zones. þ> Differential sticking is a concern. The 8.5ppg mud will be -740 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). þ> Tie the MWD Gamma Ray log back into parent well bore log in the wellsite geologist possession. A 200' MAD pass above the window is usually sufficient. Job 9: Run 3-1/2" Production Liner Planned Phase Time 30 hours Planned Phase Cost $197,137 Reference RP .:. "Modified Conventional Liner Cementing" RP .:. Schlumberger Cement Program. Issues and Potential Hazards þ> The completion design is to run a 3-1/2", 9.2#, L-80 IBT-M solid liner throughout the productiC"1\,,) interval. þ> Differential sticking is possible. The 8.5 ppg Flo-Pro will be -750 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. þ> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. þ> Sufficient 3-1/2" liner will be run to extend -150' back up into the 5-1/2" liner. Phase 10: DPC Peñorate Planned Phase Time 35 hours Planned Phase Cost $219,183 Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards þ> The well will be DPC perforated, -700psi overbalanced, after running the 3-1/2 liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. J-02B Sidetrack Version 1.0 Page 8 . . ~ Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Job 12: Run 4 Yz" 13Cr-80 Completion Planned Phase Time 25 hours Planned Phase Cost $493.365 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Casing and Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well to 2200'. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. ~ The completion, as designed, will be to run a 4-1/2",12.6#, 13Cr-80, VAM TOP production tubing string, stinging into the 5-1/2" scab liner tieback sleeve. Take all the normal precautions while running the Vam TOP 13Cr-80 tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Tubing should arrive on location with the proper thread dope. Confirm type of thread compound prior to RIH. Job 13: ND/NU/Release Rig Planned Phase Time 12 hours Planned Phase Cost $42,821 Reference RP .:. "ADW Rig Move" RP. .:. "Freeze Protecting an Inner Annulus" RP. Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto J-02A. However, JX-02A is about 70' to the North. JX-02A is the closest surface neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. J-02B Sidetrack Version 1.0 Page 9 TREE = 6" erN . J-02A ~ NOTES: 7" SCAB LNR CEMENTED & SET ON WELLHEAD = McEVOY GENCY SLIPS DURING RWO. **WELL WAS ACTUA TOR = OTIS KB. ELEV - 57.33' Current RENAMED J-02A WHEN IT WAS DEEPENED FROM THE BF. ELEV = 20.0'0 PUT RIVER FORMATION TO THE IVISHAK. ** KOP= 2400' Ì"f Max Angle = 39 @ 8200' I~ 861' H 13-3/8" FOC I Datum MD = 10004' 20" eSG, 94#, I~ Datum lVD = 8800'SS N-40, 8 rd - 931 ~ ..... N 918' H 13-3/8" CASING PATCH I N 2003' H 10-3/4" X 9-518" XO I . t.. I 2028' 4-1/2" OTIS SSSV NIP, 10 = 3.813" I . r-.....~ 2042' H 9-5/8" FOe I Est. TOe - 3254~ 2053' H 9-5/8" CASING PATCH I - I 7" DV COLLAR I 4019' 1--- : : I 13-3/8" CSG, 68#, K-55, 10= 12.415" I 4589' µ yES!. TOe - 5955' I 7" TIEBACK LNR, 26#, L-80, 10 = 6.276" 9122' 4-1/2" BKR L SLIDING SLV, 10 = 3.812" I I I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9185' --- 1- - I 9186' 4-1/2" X 3-1/2" XO, 10 = 2.992" I i" 9187' 3-1/2" BOT SBR WI 2.313" X-PROFILE I 9211' 7" X 3-1/2" BOT3-H PKR I Minimum ID = 2.313" @ 9187' IIII 2-7/8" OTIS X NIPPLE PROFILE I I 9253' 1-12-7/8" OTIS X NIP, 10 = 2.313" I 9296' 1-19-5/8" X 7" BKR TIEBACK LNR PKR SHOE I 12-7/8" TBG, 6.5#, L-80, .00579 bpf, 10 = 2.441" I 9349' J 9350' 1-12-7/8" WLEG, 10 = 2.441" I 1 9339' - ELMO TT LOG NOT A V AILABLE I ÆRFORA TION SUMMARY II REF LOG: BHCS ON 10/28/69 ANGLE AT TOP ÆRF: 27 @ 10007' Note: Refer to Production DB for historical perf data II SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 10007 - 10022 S 06/18/91 2-1/8" 4 10037 - 10046 S 06/18/91 [ ] 2-118" 4 10067 - 10082 S 06/18/91 2-1/8" 4 10094-10114 S 06/18/91 II 2-1/8" 4 10128 - 10165 S 06/18/91 2-1/8" 8 10175 - 10180 S 06/18/91 2-1/8" 4 10180 - 10200 0 06/26/91 2-118" 8 10200 - 10212 S 06/18/91 1 10217' HKEVLARNYLONCENTARM 6-11/91 I I 10217' -3URARMS 5-12-911 I PBTD I 10355' I I 9-5/8" CSG, 47#, N-80, 10 = 8.681" , 10410' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE SA Y UNrr 11/06/69 ORIGINAL COM PLETION WELL: J-02A 07/06/82 LAST RWO ÆRMrr No: 1690970 04/05/02 RNlCHlTP CORRECTIONS API No: 50-029-20023-01 11/13/02 lW/tlh WELL NAME CORRECTION SEC 9, T11 N, R13E, 1080' NSL & 1245' WEL 07/15/03 CMOITLP MAX ANGLE CORRECTION 05/07/04 ??/KAK WELL NAME CLARIFICA TION BP Exploration (Alaska) Pre-Rig ~ NOTES: 7" SCAB LNR CEMENTED & SET ON _GENCY SLIPS DURING RWO. **WELL WAS RENAMED J-02A WHEN IT WAS DEEPENED FROM THE T RIVER FORMATION TO THE IVISHAK. ** TREE::: 6" CrN . WELLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 57.33' BF. ELEV - 20.0'0 KOP = 2400' . Max Angle = 39 @ 8200' 20" CSG, 94#, ~ DatumMD= 10004' N-40,8rd-931' ~ Datum lVD = 8800' SS '" Minimum IC = 2.313" @ 9187'1 ~ 2-7/8" OTIS X NIPPLE PROFILE Est. TOC - 3254~ _ I 7" DV COLLAR I 4019' ~ '- ~ J-02A ~ 861' 1-113-3/8" FCC I Ñ 918' 1-113-3/8" CASING PATCH I 2003' 1-110-3/4" X 9-5/8" XO I . ~ r 2028' 4-1/2" OTIS SSSV NIP, ID = 3.813" I ....... "r 2042' H 9-5/8" Foe I I 2053' H 9-5/8" CASING PATCH I : I 13-318" CSG, 68#, K-55, ID = 12.415" I 4589' ~ yES!. TOG - 5955' ~ r 9122' 4-1/2" BKR L SLIDING SLV, ID = 3.812" I Wi I 7" TIEBACK LNR, 26#, L-80, ID = 6.276" ~ Cut 4-1/2" Tubing -9165'__ , 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9185' I--- ~ iji.. I I ~¡t I I ~ I 9186' 4-1/2" X 3-1/2" XO, ID = 2.992" I 9187' 3-1/2" BOT SBR WI 2.313" X-PROFILE I I 9211' 7" X 3-1/2" BOT 3-H A<:R I r 9253' 1-12-7/8" OTIS X NIP, ID = 2.313" I 9296' 1-19-5/8" X 7" BKR TIEBACK LNR A<:R SHOE I r 9350' 1-12-7/8" WLEG, ID = 2.441" I I 9339' H ELMD TT LOG NOT A V AILABLE I . If- 12-718" TBG, 6.5#, L-80, .00579 bpf, ID = 2.441" I 9349' I J ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/28/69 ANGLE AT TOP ÆRF: 27 @ 10007' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 10007 - 10022 S I 06/18/91 2-1/8" 4 10037 - 10046 S 06/18/91 2-1/8" 4 10067 - 10082 S 06/18/91 2-1/8" 4 10094 -10114 S 06/18/91 2-118" 4 10128 - 10165 S 06/18/91 2-118" 8 10175 - 10180 S 06/18/91 2-1/8" 4 10180 - 10200 0 06/26/91 2-1/8" 8 10200 - 10212 S 06/18/91 I I I I I 10217' HKEVLARNYLONCENTARM 6-11/91 I I 10217' H3 URARMS 5-12-91 I I PBTD I 10355' I ·Y I 9-518" CSG, 47#, N-80, ID = 8.681" I 10410' ~ DATE 11/06/69 07/06/82 04/05/02 11/13/02 07/15/03 05/07104 REV BY COMMENTS ORIGINAL COMPLETION LAST RWO RN/CH/TP CORRECTIONS lW/tlh WELL NAME CORRECTION CMOI1LP MAX ANGLE CORRECTION ??/KAK WELL NAME CLARIFICATION DATE REV BY COMMENTS PRUDHOE BAY UNrr W8...L: J-02A ÆRMrr No: 1690970 API No: 50-029-20023-01 SEe 9, T11N, R13E. 1080' NSL & 1245' WEL BP Exploration (Alaska) TREE = WELLHEAD = AGTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 20" CSG, 94#, N-40, 8 rd - 931' 6"CrN McEVOY OTIS 57.33' 20.0'0 2400' 39 @ 8200' 10004 ' 8800' SS .-028 5-1/2" Liner / P&A Perf's A-rv NOTES: 7" SCAB LNR CEMENTED & SET ON aGENCY SLIPS DURING RWO. **WELL WAS RENAMED J-02A WHEN IT WAS DEEPENED FROM THE PUT RIVER FORMATION TO THE IVISHAK. ** 7" Tieback LNR, 26#, L-80, 10 = 6.276" Top of 5-1/2" LNR - 9146' - 13-3/8" Foe I -i 13-3/8" CASING PATCH I -110-314" X 9-5/8" XO I 14-1/2" OTIS SSSV NIP, ID = 3.813" I 9-518" Foe I 9-5/8" CASING PATCH I Est. TOC - 3254' -- Est. TOC - 5955' Insert LOG Collar PBTO -9970' DATE 11/06/69 07/06/82 04/05/02 11/13/02 07/15/03 05/07/04 5-1/2 LNR, 17#, L-80 -10217' I PBTD I REV BY COMMENTS ORIGINAL COM PLETION LAST RWO RNIC CORRECTIONS lW/tlh WELL NAME CORRECTION CMOITLP MAX ANGLE CORRECTION ??/KAK WELL NAME CLARIFICATION DATE 9296' -19-5/8" X 7" BKR TIEBACK LNR PKR SHOE I ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/28/69 ANGLEATTOPÆRF: 27@ 10007' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 10007 - 10022 S 06/18/91 2-1/8" 4 10037 - 10046 S 06/18/91 2-1/8" 4 10067 - 10082 S 06/18/91 2-1/8" 4 10094 -10114 S 06/18/91 2-1/8" 4 10128 - 10165 S 06/18/91 2-1/8" 8 10175 - 10180 S 06/18/91 2-1/8" 4 10180 - 10200 0 06/26/91 2-1/8" 8 10200 - 10212 S 06/18/91 10217' H KEVLAR NYLON CENT ARM 6-11191 10217' 1-13 URARMS 5-12-91 I - I 9-5/8" CSG, 47#, N-80, ID = 8.681" H 10410' REV BY COMMENTS PRUDHOE BAY UNrr WELL: J-02A ÆRMrr No: 1690970 API No: 50-029-20023-01 SEC 9, T11 N, R13E, 1080' NSL & 1245' WEL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = .-028 AErv NOTES: 7" SCAB LNR CEMENTED & SET ON WlRGENCY SLIPS DURING RWO. **WELL WAS RENAMED J-02A WHEN IT WAS DEEPENED FROM THE PUT RIVER FORMATION TO THE IVISHAK. ** Proposed Completion 5-1/2 LNR, 17#, L-80 -10217' 2042' 2053' -i 13-3/8" Foe I -i 13-3/8" CASING PATCH I - 10-314" X 9-5/8" XO I 9-5/8" Foe I 9-5/8" CASING PATCH I 20" CSG, 94#, _____ N-40, 8 rd - 931 ' 7" Tieback LNR, 26#, L-80, 10 = 6.276" 7" DV COLLAR I 4019' 13-3/8" CSG, 68#, K-55, 10 12.415" - 4589' 2200' - HES 4-1/2" X Nipple 10 = 3.813" ~ Est. TOC - 3254' Est. TOC - 5955' 4-1/2" TBG, 12.6#, 13Cr-80, 10 = 3.958" Top of 5-1/2" LNR - 9146' 9-5/8" x 7" BKR Tieback LNR PKR Shoe - 9296' HES 4-1/2" X Nipple 10 = 3.813" BKR 7" x 4-1/2" PKR HES 4-1/2" X Nipple 10 = 3.813" HES 4-1/2" XN Nipple 10 = 3.725" 4-1/2" WLEG Top of 3-1/2" LNR - 9740' Top of Whipstock -9890' Tubing space out joints Insert LNOG Collar PBTO -9970' 3-1/2" Solid LNR, 9.2#, L-80, 11975' / Kevlar Nylon Cent Arm 6-11/91 3 UR Arms 5-12-91 -10217' I PBTD I 9-5/8" CSG, 47#. N-80. ID = 8.681" H 10410' I DA TE REV BY COMMENTS 11/06/69 ORIGINAL COMPLETION 07/06/82 LAST RWO 04/05/02 RN'CH/TP CORRECTIONS 11/13/02 lW/Uh WELL NAME CORRECTION 07/15/03 CMOITLP MAX ANGLE CORRECTION 05/07104 ??/KAK WELL NAME CLARIFICA TION DA TE REV BY COMMENTS 08/25/04 kw a Proposed Completion & add calc. em! from previous 7" tieback liner PRUDHOE BAY UNrr WELL: J-02B ÆRMrr No: API No: 50-029-20023-xx BP Exploration (Alaska) SURVEY PROGRA.M Created By: Troy Jakabosky Date; 8/3.J/2004 Checked: Date;~ Reviewed: Date:~ - - - - -- WELL D£T AILS Nm'W 51'" j..{j2 2003.94 IJ2 - - - ..... -- ID +Ej·W Northing E - - - ..... -- See MD [ne Azi TVD DLeg TFa"" Targ"t ¡ 2 3 4 5 J"()2B TI rev b 7 J·02B T2 rev 8 9 J"()2B T3 rev - CASING DETAILS FORMA nON TOP DETAILS No. TVD Name Size No. TVDPath MDPath Formation 9007.30 ! 974.00 I. 2 3 4 5 6 c; ~ :::1 fì iì' '" "ii " ! " 2 ... Created By: Troy Jaka.bosky Date: 8/J 112004 - WELL DETARS N""" Name TVD +N/~S +EI~W Northing Basting Sha¡>c TVD MD Name Size 9007.30 I ! 974.00 3 3.500 No. TVDPaIh MDPath COMPANY DETAIL'" 573ù SECTION DETAILS TVD +NI-S DLe¡; TFace VSec Target J-02B TI rev J-02B 1'2 J-02B T3 Azi [ne MD See ! 2 3 4 5 6 7 S 9 fil ¡j c c ¡:;, '+ :g ~. ;E § '" . . BP BP Planning Report Company: Field: Site: WeD: WeDpath: BP AmoCO Prudhoe Bay PB J Pad J-02 Plan J-02B Date: 8/3112004 Time: 11:05:21 Page: 1 Co-ordinate(NE) Reference: Well: J-02. True North Vertieal (TVD) Reference: 3 : 02 9124/196900:00 57.3 Seetion (VS) Reference: Well (0.ooN,0.ooE.117.40Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Plan: J-02B wp06 Date Composed: Version: Tied-to: 7/13/2004 40 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5968224.22 ft 641155.79 ft Latitude: 70 19 Longitude: 148 51 North Reference: Grid Convergence: 14.845 N 20.C:J2 W True 1.08 deg J-02 J-02 Well Position: Slot Name: 02 Well: +N/-S 2003.94 ft +E/-W 1996.17 ft Position Uncertainty: 0.00 ft Northing: Easting : 5970265.19 ft 643113.77 ft Latitude: Longitude: 70 19 34.551 N 148 50 21.823 W Casing Points MD TVD DIameter Hole Size Name ft ft in In 11974.00 9007.30 3.500 4.750 3 1/2" Formations MD TVD Formations UtlloIogy ft ft 9973.10 8827.30 25N 0.00 0.00 10063.10 8897.30 22N 0.00 0.00 10138.86 8947.30 PGOC 0.00 0.00 10155.98 8957.30 21N 0.00 0.00 10268.83 9007.30 TZ1B 0.00 0.00 10388.79 9027.30 MHO/HOT 0.00 0.00 Targets Name Descriptiqu TVD +Nl-S +EI-W Dip. DIr. ft ft ft ft J-02B T2 rev 3 9006.00 -2603.83 4087.63 5967740.00 647250.00 70 19 8.932 N 148 48 22.545 W J-02B Geo Poly 9006.30 -2417.29 3065.92 5967907.00 646225.00 70 19 10.771 N 148 4852.356 W -Polygon 1 9006.30 -2417.29 3065.92 5967907.00 646225.00 70 19 10.771 N 148 48 52.356 W -Polygon 2 9006.30 -2591.03 3154.63 5967735.00 646317.00 70 19 9.062 N 148 48 49.770 W -Polygon 3 9006.30 -2688.81 3980.98 5967653.00 647145.00 70 19 8.096 N 148 48 25.658 W -Polygon 4 9006.30 -2658.08 4257.64 5967689.00 647421.00 70 19 8.397 N 148 48 17.585 W -Polygon 5 9006.30 -2653.81 5029.92 5967708.00 648193.00 70 19 8.435 N 148 47 55.050 W -Polygon 6 9006.30 -2533.66 4971.20 5967827.00 648132.00 70 19 9.617 N 148 47 56.761 W -Polygon 7 9006.30 -2515.72 4240.35 5967831.00 647401.00 70 19 9.797 N 148 48 18.087 W J-02B T3 rev 1 9007.30 -2580.81 4978.30 5967780.00 648140.00 70 19 9.153N 148 47 56.555 W J-02B Faull 1 9007.30 -2019.56 4081.77 5968324.00 647233.00 70 19 14.678 N 148 48 22.707 W -Polygon 1 9007.30 -2019.56 4081.77 5968324.00 647233.00 70 19 14.678 N 148 48 22.707 W -Polygon 2 9007.30 -2346.71 4137.55 5967998.00 647295.00 70 1911.460 N 148 48 21.084 W J-02B Faull 4 9007.30 -2986.65 4492.43 5967365.00 647662.00 70 19 5.164 N 148 48 10.739 W -Polygon 1 9007.30 -2986.65 4492.43 5967365.00 647662.00 70 19 5.164 N 148 48 10.739 W -Polygon 2 9007.30 -2872.70 4601.63 5967481.00 647769.00 70 19 6.284 N 148 48 7.551 W -Polygon 3 9007.30 -2781.78 4921.45 5967578.00 648087.00 70 19 7.177 N 148 47 58.217 W . . BP BP Planning Report çQmp~ny: 8P Amoco Date: 813112004 Tùne:l1 :05:21 ~.gé: Z Field: Prudhoe Bay Ç_rdinate(NE) Réference: Well: J..()2, TrueNôrth Site: P8J Pad Vertical (TVD) Referçnce: 3 :02 9124/196E}iOO:OQ()7';~ WeD: J-Q2 SectitJn (VS) Referçnce: Well (O,OON,(),00E.117.4QAzI) Wellpath: Plan J-028 Survey ÇaJculation MetJa(Jd; Minimum Curvature Db: öracle Targets Map Map <'- .."'titude .......> ..<-...:..LIJ..gi....~ ..~ Name DescriptiQn TVD +N/-S +EI-W NQI·tldng Eastjng .neg . Min ......$ec neg.~n.$ec Dip. Dir. ft ft ft ft ft -Polygon 4 9007.30 -2768.11 5253.80 5967598.00 648419.00 70 19 7.309 N 148 47 48.519 W -Polygon 5 9007.30 -2781.78 4921.45 5967578.00 648087.00 70 19 7.177 N 148 4758.217 W -Polygon 6 9007.30 -2872.70 4601.63 5967481.00 647769.00 70 19 6.284 N 148 48 7.551 W J-028 Fault 6 9007.30 -2618.60 3394.17 5967712.00 646557.00 70 19 8.790 N 148 48 42.781 W -Polygon 1 9007.30 -2618.60 3394.17 5967712.00 646557.00 70 19 8.790 N 148 48 42.781 W -Polygon 2 9007.30 -2085.91 3260.29 5968242.00 646413.00 70 19 14.029 N 148 48 46.680 W J-028 Fault 7 9007.30 -2783.03 3151.97 5967543.00 646318.00 70 19 7.174 N 148 48 49.850 W -Polygon 1 9007.30 -2783.03 3151.97 5967543.00 646318.00 70 19 7.174 N 148 48 49.850 W -Polygon 2 9007.30 -2564.65 3135.13 5967761.00 646297.00 70 19 9.321 N 148 48 50.339 W -Polygon 3 9007.30 -2362.63 3031.96 5967961.00 646190.00 70 1911.309 N 148 48 53.347 W -Polygon 4 9007.30 -2149.72 2987.00 5968173.00 646141.00 70 19 13.403 N 148 48 54.656 W -Polygon 5 9007.30 -2362.63 3031.96 5967961.00 646190.00 70 19 11.309 N 148 48 53.347 W -Polygon 6 9007.30 -2564.65 3135.13 5967761.00 646297.00 70 19 9.321 N 148 48 50.339 W J-02B Fault 5 9007.30 -2824.55 4227.46 5967522.00 647394.00 70 19 6.760 N 148 48 18.469 W -Polygon 1 9007.30 -2824.55 4227.46 5967522.00 647394.00 70 19 6.760 N 148 48 18.469 W -Polygon 2 9007.30 -2857.81 4030.77 5967485.00 647198.00 70 19 6.434 N 148 48 24.208 W -Polygon 3 9007.30 -3311.35 3581.00 5967023.00 646757.00 70 19 1.976 N 148 48 37.338 W -Polygon 4 9007.30 -2857.81 4030.77 5967485.00 647198.00 70 19 6.434 N 148 48 24.208 W J-02B Fault 3 9007.30 -2293.35 4800.74 5968064,00 647957.00 70 1911.981 N 148 48 1.7::S1 W -Polygon 1 9007.30 -2293.35 4800.74 5968064.00 647957.00 70 1911.981 N 148 48 1.731 W -Polygon 2 9007.30 -2343.13 4945.82 5968017.00 648103.00 70 19 11.491 N 148 47 57.498 W -Polygon 3 9007.30 -2577.80 5135.40 5967786.00 648297.00 70 19 9.181 N 148 47 51.971 W -Polygon 4 9007.30 -2796.04 5197.25 5967569.00 648363.00 70 19 7.035 N 148 4750.170 W -Polygon 5 9007.30 -2577.80 5135.40 5967786.00 648297.00 70 19 9,181 N 148 47 51.971 W -Polygon 6 9007.30 -2343.13 4945.82 5968017.00 648103.00 70 1911.491 N 148 47 57.498 W J-02B Fault 2 9007.30 -2418.75 4348.23 5967930.00 647507.00 70 19 10.750 N 148 48 14.938 W -Polygon 1 9007.30 -2418.75 4348.23 5967930.00 647507.00 70 19 10.750 N 148 48 14.938 W -Polygon 2 9007.30 -2425.82 4509.13 5967926.00 647668.00 70 19 10.680 N 148 48 10.242 W -Polygon 3 9007.30 -2302.09 4839.58 5968056.00 647996.00 70 19 11.895 N 148 48 0.597 W -Polygon 4 9007.30 -2425.82 4509.13 5967926.00 647668.00 70 19 10.680 N 148 48 10.242 W J-028 T1 rev 1 9027.30 -2545.69 3399.56 5967785.00 646561.00 70 19 9.507 N 148 48 42.622 W Plan SediQn InfQrmatiQD MD locI ADm TVD +N/-S +EI-W DLS BuDd Turn DO Tårget ft deg deg ft ft ft degl100ft degl100ft degl100ft deg 9890.00 26.57 148,25 8755.37 -2383.65 3054.07 0.00 0.00 0.00 0.00 9910.00 28.01 144.06 8773.14 -2391.26 3059,18 12.00 7.20 -20.94 -55.00 10138.71 53.33 110.00 8947.21 -2468.24 3180.25 14.40 11.07 -14.89 -55.73 10141.01 53.33 110.00 8948.59 -2468.88 3181.98 0.00 0.00 0.00 0.00 10388.79 89.00 109.00 9027.30 -2545.69 3399.56 14.40 14.40 -0.40 -1.71 J-02B T1 rev 1 10698.09 92.54 90.78 9023,10 -2598.59 3702.90 6.00 1.15 -5.89 -78.96 11083.24 92.54 90.78 9006.00 -2603.83 4087.63 0.00 0.00 0.00 0.00 J-02B T2 rev 3 11174.55 89.77 88.40 9004.15 -2603.17 4178.90 4.00 -3.03 -2.61 -139.28 11974.26 89.77 88.40 9007.30 -2580.81 4978.30 0.00 0.00 0.00 0.00 J-02B T3 rev 1 . . BP BP Planning Report Company: BPAmoco Date: 813112004 Tiine:11:0.5:21 .e.ge: 3 Field: Prudhoe Bay Co-ordiJIate(NE) Reference: Well: J-02, Tr1.IeNgrtp Site: PB J Pad Vertical (TVD) Reference: 3 :. 0~9/24/!96900:0057.~. WeD: J-02 Seeticln(VS) Reference.: wen (0.QON,0.OQç¡1g,~oAzi) WeDpath: Plan J-02B Survey Caleulatiou Method: Minimum Curvature Db: Of'acle Survey MD lucl Azim TVD Sys TVP NIS EIW DLS M.apN MapE ft deg deg ft ft ft ft deg/10Qft ft ft 9890.00 26.57 148.25 8755.37 8698.07 -2383.65 3054.07 0.00 5967940.41 646212.51 Start Dir 12/10 9900.00 27.28 146.11 8764.28 8706.98 -2387.45 3056.53 12.00 5967936.65 646215.04 MWD+IFR+MS 9910.00 28.01 144.06 8773.14 8715.84 -2391.26 3059.18 12.00 5967932.90 646217.77 Start Dir 14.41 9925.00 29.28 140.41 8786.31 8729.01 -2396.94 3063.59 14.40 5967927.30 646222.28 MWD+IFR+MS 9950.00 31.59 134.95 8807.87 8750.57 -2406.28 3072.12 14.40 5967918.13 646230.99 MWD+IFR+MS 9973.10 33.90 130.53 8827.30 8770.00 -2414.74 3081.30 14.40 5967909.84 646240.33 25N 9975.00 34.10 130.19 8828.87 8771.57 -2415.43 3082.11 14.40 5967909.17 646241.15 MWD+IFR+MS 10000.00 36.77 126.03 8849.24 8791.94 -2424.35 3093.52 14.40 5967900.46 646252.72 MWD+IFR+MS 10025.00 39.57 122.36 8868.90 8811.60 -2433.02 3106.30 14.40 5967892.04 646265.67 MWD+IFR+MS 10050.00 42.47 119.12 8887.76 8830.46 -2441.39 3120.40 14.40 5967883.94 646279.93 MWD+IFR+MS 10063.10 44.03 117.56 8897.30 8840.00 -2445.65 3128.30 14.40 5967879.84 646287.91 22N 10075.00 45.46 116.21 8905.75 8848.45 -2449.44 3135.78 14.40 5967876.19 646295.45 MWD+IFR+MS 10100.00 48.51 113.60 8922.81 8865.51 -2457.12 3152.35 14.40 5967868.82 646312.17 MWD+IFR+MS 10125.00 51.61 111.22 8938.86 8881.56 -2464.42 31'70.07 14.40 5967861.87 646330.02 MWD+IFR+MS 10138.71 53.33 110.00 8947.21 8889.91 -2468.24 3180.25 14.38 5967858.24 646340.27 End Dir : 1013 10138.86 53.33 110.00 8947.30 8890.00 -2468.28 3180.36 0.00 5967858.20 646340.38 PGOC 10141.01 53.33 110.00 8948.59 8891.29 -2468.88 3181.98 0.00 5967857.64 646342.01 Start Dir 14.41 10150.00 54.62 109.95 8953.87 8896.57 -2471.36 3188.81 14.40 5967855.29 646348.89 MWD+IFR+MS 10155.98 55.48 109.92 8957.30 8900.00 -2473.03 3193.42 14.40 5967853.70 646353.53 21N 10175.00 58.22 109.83 8967.70 8910.40 -2478.44 3208.40 14.40 5967848.58 646368.60 MWD+IFR+MS 10200.00 61.82 109.71 8980.19 8922.89 -2485.77 3228.77 14.40 5967841.65 646389.11 MWD+IFR+MS 10225.00 65.42 109.60 8991.30 8934.00 -2493.30 3249.86 14.40 5967834.52 646410.34 MWD+IFR+MS 10250.00 69.02 109.50 9000.97 8943.67 -2501.01 3271.58 14.40 5967827.22 646432.20 MWD+IFR+MS 10265.68 71.28 109.44 9006.30 8949.00 -2505.93 3285.48 14.40 5967822.57 646446.20 J-02B Geo Poly 10268.83 71.73 109.43 9007.30 8950.00 -2506.92 3288.30 14.40 5967821.63 646449.03 J-02B Fault 1 10275.00 72.62 109.41 9009.19 8951.89 -2508.88 3293.84 14.40 5967819.78 646454.60 MWD+IFR+MS 10300.00 76.22 109.31 9015.90 8958.60 -2516.86 3316.55 14.40 5967812.24 646477.47 MWD+IFR+MS 10325.00 79.81 109.22 9021.09 8963.79 -2524.93 3339.63 14.40 5967804.61 646500.69 MWD+IFR+MS 10350.00 83.41 109.13 9024.74 8967.44 -2533.05 3362.99 14.40 5967796.94 646524.20 MWD+IFR+MS 10375.00 87.01 109.05 9026.82 8969.52 -2541.20 3386.53 14.40 5967789.24 646547.89 MWD+IFR+MS 10388.79 89.00 109.00 9027.30 8970.00 -2545.69 3399.56 14.42 5967785.00 646561.00 J-02B T1 rev 1 10400.00 89.13 108.34 9027.48 8970.18 -2549.28 3410.18 6.00 5967781.6'; 646571.68 MWD+IFR+MS 10425.00 89.42 106.87 9027.80 8970.50 -2556.84 3434.00 6.00 5967774.51 646595.65 MWD+IFR+MS 10450.00 89.70 105.40 9027.99 8970.69 -2563.78 3458.02 6.00 5967768.02 646619.79 MWD+IFR+MS 10475.00 89.99 103.92 9028.06 8970.76 -2570.11 3482.20 6.00 5967762.16 646644.09 MWD+IFR+MS 10500.00 90.28 102.45 9028.00 8970.70 -2575.81 3506.54 6.00 5967756.92 646668.53 MWD+IFR+MS 10525.00 90.57 100.98 9027.81 8970.51 -2580.89 3531.02 6.00 5967752.31 646693.10 MWD+IFR+MS 10550.00 90.86 99.51 9027.50 8970.20 -2585.33 3555.62 6.00 5967748.34 64671'7.78 MWD+IFR+MS 10575.00 91.14 98.03 9027.06 8969.76 -2589.14 3580.32 6.00 5967745.00 646742.54 MWD+IFR+MS 10600.00 91.43 96.56 9026.50 8969.20 -2592.32 3605.11 6.00 5967742.30 646767.39 MWD+IFR+MS 10625.00 91.72 95.09 9025.82 8968.52 -2594.86 3629.97 6.00 5967740.24 646792.29 MWD+IFR+MS 10650.00 92.00 93.62 9025.00 8967.70 -2596.75 3654.89 6.00 5967738.82 64681'7.24 MWD+IFR+MS 10675.00 92.28 92.14 9024.07 8966.77 -2598.01 3679.84 6.00 5967738.04 646842.20 MWD+IFR+MS 10698.09 92.54 90.78 9023.10 8965.80 -2598.59 3702.90 6.00 5967737.89 646865.27 End Dir : 1069 10700.00 92.54 90.78 9023.01 8965.71 -2598.62 3704.81 0.00 5967737.90 646867.18 MWD+IFR+MS 10725.00 92.54 90.78 9021.90 8964.60 -2598.96 3729.78 0.00 5967738.04 646892.15 MWD+IFR+MS 10750.00 92.54 90.78 9020.79 8963.49 -2599.30 3754.75 0.00 5967738.17 646917.12 MWD+IFR+MS 10775.00 92.54 90.78 9019.68 8962.38 -2599.64 3779.73 0.00 5967738.31 646942.10 MWD+IFR+MS 10800.00 92.54 90.78 9018.57 8961.27 -2599.98 3804.70 0.00 5967738.45 646967.07 MWD+IFR+MS 10825.00 92.54 90.78 9017.46 8960.16 -2600.32 3829.67 0.00 5967738.58 646992.04 MWD+IFR+MS 10850.00 92.54 90.78 9016.35 8959.05 -2600.66 3854.65 0.00 5967738.72 647017.02 MWD+IFR+MS 10875.00 92.54 90.78 9015.24 8957.94 -2601.00 3879.62 0.00 5967738.86 647041.99 MWD+IFR+MS 10900.00 92.54 90.78 9014.13 8956.83 -2601.34 3904.59 0.00 5967738.99 647066.96 MWD+IFR+MS . . BP BP Planning Report Comp.ny: BP AmOco Date: 8/3112004 Time: 11:05:21 Påge: 4 Field: Prudhoe Bay Co-ordinate(NE)Refe~nçe: WE!U:J-Q2''rruE! N.ortI'I Site; PB J Pad Vertieal (TVD) Refe~nçe: 3 ;02 9124f1969i~;~i~7.3 WeD: J-02 Section (VS) ~fe~nçe: Well(0.Q()N.0.OOe.117.40~) WeDpath: Plan· J-02B Sûrvey CaJeulationMethod: Mil1imum.Cuf\llitt1,lre Db: Oråêle Survey MD Incl Azim TVD Sys TVD N/S EIW DLS M.pN M~f; ft deg deg ft ft ft ft degl100ft ft 10925.00 92.54 90.78 9013.02 8955.72 -2601.68 3929.56 0.00 5967739.13 647091.94 MWD+IFR+MS 10950.00 92.54 90.78 9011.91 8954.61 -2602.02 3954.54 0.00 5967739.27 647116.91 MWD+IFR+MS 10975.00 92.54 90.78 9010.80 8953.50 -2602.36 3979.51 0.00 5967739.40 647141.88 MWD+IFR+MS 11000.00 92.54 90.78 9009.69 8952.39 -2602.70 4004.48 0.00 5967739.54 647166.86 MWD+IFR+MS 11025.00 92.54 90.78 9008.59 8951.29 -2603.04 4029.46 0.00 5967739.68 647191.83 MWD+IFR+;JlS 11050.00 92.54 90.78 9007.48 8950.18 -2603.38 4054.43 0.00 5967739.81 647216.80 MWD+IFR+MS 11075.00 92.54 90.78 9006.37 8949.07 -2603.71 4079.40 0.00 5967739.95 647241.77 MWD+IFR+MS 11083.24 92.54 90.78 9006.00 8948.70 -2603.83 4087.63 0.00 5967740.00 647250.00 J-02B T2 rev 3 11100.00 92.04 90.34 9005.33 8948.03 -2603.99 4104.38 4.00 5967740.15 647266.75 MWD+IFR+MS 11125.00 91.28 89.69 9004.61 8947.31 -2604.00 4129.37 4.00 5967740.62 647291.73 MWD+IFR+MS 11150.00 90.52 89.04 9004.22 8946.92 -2603.72 4154.36 4.00 5967741.38 647316.72 MWD+IFR+MS 11174.55 89.77 88.40 9004.15 8946.85 -2603.17 4178.91 4.00 5967742.39 647341.24 End Dir : 1117 11175.00 89.77 88.40 9004.15 8946.85 -2603.16 4179.36 0.00 5967742.41 647341.69 MWD+IFR+MS 11200.00 89.77 88.40 9004.25 8946.95 -2602.46 4204.35 0.00 5967743.59 647366.66 MWD+IFR+MS 11225.00 89.77 88.40 9004.35 8947.05 -2601.76 4229.34 0.00 5967744.77 647391.63 MWD+IFR+MS 11250.00 89.77 88.40 9004.45 8947.15 -2601.06 4254.33 0.00 5967745.94 647416.60 MWD+IFR+MS 11275.00 89.77 88.40 9004.55 8947.25 -2600.36 4279.32 0.00 5967747.12 647441.57 MWD+IFR+MS 11300.00 89.77 88.40 9004.65 8947.35 -2599.66 4304.31 0.00 5967748.29 647466.54 MWD+IFR+MS 11325.00 89.77 88.40 9004.74 8947.44 -2598.96 4329.30 0.00 5967749.47 647491.51 MWD+IFR+MS 11350.00 89.77 88.40 9004.84 8947.54 -2598.26 4354.29 0.00 5967750.64 647516.48 MWD+IFR+MS 11375.00 89.77 88.40 9004.94 8947.64 -2597.57 4379.28 0.00 5967751.82 647541.45 MWD+IFR+MS 11400.00 89.77 88.40 9005.04 8947.74 -2596.87 4404.27 0.00 5967752.99 647566.42 MWD+IFR+MS 11425.00 89.77 88.40 9005.14 8947.84 -2596.17 4429.26 0.00 5967754.17 647591.39 MWD+IFR+MS 11450.00 89.77 88.40 9005.24 8947.94 -2595.47 4454.25 0.00 5967755.35 647616.37 MWD+IFR+MS 11475.00 89.77 88.40 9005.33 8948.03 -2594.77 4479.24 0.00 5967756.52 647641.34 MWD+IFR+MS 11500.00 89.77 88.40 9005.43 8948.13 -2594.07 4504.23 0.00 5967757.70 647666.31 MWD+IFR+MS 11525.00 89.77 88.40 9005.53 8948.23 -2593.37 4529.22 0.00 5967758.87 647691.28 MWD+IFR+MS 11550.00 89.77 88.40 9005.63 8948.33 -2592.67 4554.21 0.00 5967760.05 647716.25 MWD+IFR+MS 11575.00 89.77 88.40 9005.73 8948.43 -2591.97 4579.20 0.00 5967761.22 647741.22 MWD+IFR+MS 11600.00 89.77 88.40 9005.83 8948.53 -2591.27 4604.19 0.00 5967762.40 647766.19 MWD+IFR+MS 11625.00 89.77 88.40 9005.93 8948.63 -2590.57 4629.18 0.00 5967763.57 647791.16 MWD+IFR+MS 11650.00 89.77 88.40 9006.02 8948.72 -2589.88 4654.17 0.00 5967764.75 647816.13 MWD+IFR+MS 11675.00 89.77 88.40 9006.12 8948.82 -2589.18 4679.16 0.00 5967765.92 647841.10 MWD+IFR+MS 11700.00 89.77 88.40 9006.22 8948.92 -2588.48 4704.15 0.00 5967767.10 647866.07 MWD+IFR+MS 11725.00 89.77 88.40 9006.32 8949.02 -2587.78 4729.14 0.00 5967768.28 647891.04 MWD+IFR+MS 11750.00 89.77 88.40 9006.42 8949.12 -2587.08 4754.13 0.00 5967769.45 647916.01 MWD+IFR+MS 11775.00 89.77 88.40 9006.52 8949.22 -2586.38 4779.12 0.00 5967770.63 647940.98 MWD+IFR+MS 11800.00 89.77 88.40 9006.61 8949.31 -2585.68 4804.11 0.00 5967771.80 647965.95 MWD+IFR+MS 11825.00 89.77 88.40 9006.71 8949.41 -2584.98 4829.10 0.00 5967772.98 647990.92 MWD+IFR+MS 11850.00 89.77 88.40 9006.81 8949.51 -2584.28 4854.09 0.00 5967774.15 648015.89 MWD+IFR+MS 11875.00 89.77 88.40 9006.91 8949.61 -2583.58 4879.08 0.00 5967775.33 648040.86 MWD+IFR+MS 11900.00 89.77 88.40 9007.01 8949.71 -2582.88 4904.07 0.00 5967776.50 648065.83 MWD+IFR+MS 11925.00 89.77 88.40 9007.11 8949.81 -2582.19 4929.06 0.00 5967777.68 648090.80 MWD+IFR+MS 11950.00 89.77 88.40 9007.20 8949.90 -2581.49 4954.05 0.00 5967778.85 648115.77 MWD+IFR+MS 11974.00 89.77 88.40 9007.30 8950.00 -2580.82 4978.04 0.00 5967779.98 648139.74 31/2" 11974.26 89.77 88.40 9007.30 8950.00 -2580.81 4978.30 0.00 5967780.00 648140.00 J-02B T3 rev 1 . . BP-GDB Anticollision Report Comp.ny: BP Amoco Field: Prudhoe Bay Refe..en~ Site: PB JPad RefeJ"tn~ Well: J"()2 Reference WeUp.tiI: Plan J-02B GLOBAL SCAN APPLIED: All wellp.ths within 200'+ 100/1000 ofrefe..ence - The..e ....H!HilfMè"ells In th"~1 Plan & PLANNED PROGRAM Inte..pol.tion Method: MD Interval: 25.00 ft E....o.. Model: ISCWSA Ellipse Depth Range: 9890.00 to 11974.26 ft Sean Method: Trav Cylinder North Maximum Radius: 1394.58 ft ElTo.. Suñace: Ellipse + Casing Date: 9/1512004 Co-ol'dinate(NE) Reference: Vet1ieal (TVD) Reference: Survey P..og..am fo.. Definitive Wellp.tb Date: 7/16/2004 Validated: No Planned From To Survey ft ft 34.30 9890.00 9890.00 11974.26 Version: 17 Toolcode Tool Name J-02 GyroData (100.00-10150.00) (3) Planned: J-02B wp06 V41 GYD-CT-CMS MWD Gyrodata cont.casing mIs MWD - Standard Casing Points MD TVD Dlltmeter Hole Size Name ft ft in In 11974.00 9007.30 3.500 4.750 3 1/2" Summary <: Offset Wellpath ,. Referenee Offset Site Well Wellpath MD MD ft ft PB J Pad J-02 J"()2A V5 9899.99 9900.00 0.11 No Reference Casings PB J Pad J-02 Plan J-02B L 1 VO Plan: 10400.00 10400.00 0.00 No Reference Casings PB J Pad J-02 Plan J"()2B L2 V1 Plan: 10400.00 10400.00 0.00 No Reference Casings PB J Pad J-14 J-14A V2 10125.00 11774.00 829.44 674.23 155.21 Pass: Major Risk PB J Pad J-15 J-15 V3 10600.00 10975.00 1343.84 812.63 531.21 Pass: Major Risl PB J Pad J-15 J-15A V1 10600.00 10975.00 1343.84 812.63 531.21 Pass: Major Risk PB J Pad J-15 J-15B V2 11970.26 12850.00 677.96 0.00 677.96 Pass: Minor 1/500 PB J Pad J-16 J-16A V2 Out of range PB J Pad J-17 J-17 V1 11082.39 11040.00 1102.62 862.65 239.97 Pass: Major Risk PB J Pad J-17 J-17B V6 9906.57 11375.00 599.78 0.00 599.78 Pass: Minor 1/500 PB J Pad J-17 J-17BPB1 V1 9892.64 11275.00 671.91 0.00 671.91 Pass: Minor 1/200 PB J Pad J-20 J-20 V1 Out of range PB J Pad J-20 J-20A V3 Out of range PB J Pad J-20 J-20B V2 Out of range PB a Pad o.06A a-06A V4 Out of range PB a Pad 0.06 a-06 V1 Out of range Site: PB J Pad Well: J-02 Rule Assigned: NOERRORS Wellpath: J-02A V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Majo..Axis ~tI'No-Go AJIo~~ MD TVD MD TVD Ref Offset TFO+AZI TFO-HS. C::B$iqIIISHstan~ Area, Deviation WlQ'IIing ft ft ft ft ft ft deg deg in ft ft ft 9899.99 8764.28 9900.00 8764.31 26.72 26.73 281.87 135.76 0.11 FAIL 9924.92 8786.24 9925.00 8786.67 26.84 26.93 271.64 131.21 1.33 No Reference Casings 9949.61 8807.53 9950.00 8809.00 26.94 27.10 268.47 133.44 4.07 No Reference Casings 9973.87 8827.93 9975.00 8831.32 26.98 27.22 267.00 136.61 8.35 No Reference Casings 9997.53 8847.26 10000.00 8853.67 26.99 27.30 266.14 139.72 14.12 No Reference Casings 10020.44 8865.37 10025.00 8876.04 26.96 27.33 265.49 142.49 21.36 No Reference Casings 10042.47 8882.17 10050.00 8898.47 26.89 27.33 264.94 144.89 30.02 No Reference Casings 10063.54 8897.62 10075.00 8920.93 26.79 27.30 264.40 146.90 40.00 No Reference Casings 10083.60 8911.73 10100.00 8943.42 26.68 27.24 263.86 148.58 51.20 No Reference Casings 10102.62 8924.54 10125.00 8965.94 26.55 27.15 263.33 149.99 63.52 No Reference Casings 10120.59 8936.10 10150.00 8988.49 26.41 27.06 262.81 151.18 76.87 No Reference Casings 10137.50 8946.49 10175.00 9011.04 26.26 27.24 262.25 152.14 91.21 No Reference Casings 10154.13 8956.25 10200.00 9033.57 26.22 28.08 262.18 152.25 106.37 No Reference Casings 10169.47 8964.75 10225.00 9056.08 26.20 28.06 262.28 152.43 122.27 No Reference Casings 10183.94 8972.32 10250.00 9078.60 26.17 28.05 262.48 152.70 138.81 No Reference Casings 10197.58 8979.04 10275.00 9101.12 26.16 28.03 262.74 153.01 155.93 No Reference Casings 10210.43 8984.99 10300.00 9123.64 26.14 28.02 263.02 153.35 173.60 No Reference Casings b~~~æ First Nationa Bank Alaska ~W~_ TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 "Mastercard Check" Anchorage, AK 99501 MEMO-:r:-O;1ß I: ~ 25 20001;OI:iiii .1...11; 227111.551;"- 0 ~I.'" 89-611252 144 DATE 09, /to -()Lf ~OD. Lb ~~-ÐOttARS . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~4 i0'028 PTD# .2oý'-/?<7 'X' Development Service CHECK WßA T APPLIÈS ADD-ONS (OPTIONS) MULTI LATERAL (1f API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE'" Tbe permit is for a new wellbore segment of existing wen . Permit No, API No. . Production. should continue to be reponed as a function 'of tbe original API number, stated above. BOLE In accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot bole must be dearly differentiated ID botb name (name on permit plus PH) " and API num ber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE .' Tbe permit is approved subject ·to full compliance witb 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of I! conservation order approving a spa cing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacing .eJception tbat may occur. All dry ditcb sampJe sets submitted to tbe Commission must be in no greater ,tban 30' sampJe intenraJs from beJow tbe permafrost or from wbere sampJes are first caugbt and 10' sampJe inte:r:vaJs tbrougb target zones. . . o Well bore seg Annular Disposal - 640150 Well Name: PRUDHOE BAY UNIT J-02ª- _Program DEV INC Initial ClassfType DEV I j~ GeoArea 890 Unit Jî65º-_ On/Off Shore On - - - Administration Pß(I1')it fee attaçhe.d · Yßs - - ~ - - - - 2 leasßnumberappropriate. · Yßs 3 .U.nique weftn.arnß.and OL!mb.er . .- - - - - . ........ Yßs - -. - - - - - - - - - - - - - - - ~ - ~ - - 4 Well Jocatßd in.a. define.dppol. .. Yßs 5 WeJfJocated proper .distance. from driJling uni1.b.ounc:lar:y Yßs 6 Well Jocatßd proper .distance. from otber wells. . . . _ . Yßs - - - - - - 7 S.uffiçient .açreage.ayailable ¡ndrilliog unjL · Yßs 8 Jf.dßviated, js. weJlbore plaUncJu.ded . Yßs 9 .Qperator only aftected party. . . . . . . Yßs - ~ - - 10 .Operator bas.apprppriate.bond in.force . . . . . . _ _ . . - - - -. ...... .. .Yß$ -. . - - - - - - - - - - - - - - - - ~ - - - 11 Pßrmit can be iSSL!ed witbout co.nservation order. . . · Yßs - - - - - Appr Date 12 Pßrmi1. can be issL!ed witbout ad.ministratilleappr9vaJ . . · Yß$ RPC 9/21/2004 13 Can permit be approved before 15-day wait Yes 14 WellJoca1.ed within area and.strata .authorized by.lnjectipn Ordßr # (PulIO# in. comrnents). (For. NA 15 AJI wells.within.1l4.mile.area.of reyiew identified (F9rservicew.ell only). _ . _ . . . _ . . . . . . . .NA . -- - - - - - - - - - - - - - - - - - - -- 16 Pre-produced injector; dur.ationof pre-produdipnless. than. 3 months (Forservtce well only) . . .NA - - - - - - 17 ACMP F:indingof Con.si.stency h.as bee.n issued_ for. tbis pr.ojeç1. NA Engineering 18 .C.ondu.ctor string.prQvided . . . - - - - .NA 19 .Surface casing prQtects alLknown USQWs . . NA 20 .CMT vol adequate to çircul.ate oncond.uctor. & SUJf. C$g . - - - - NA - - - - - - - - - - 21 .CMT v.oladequate.to tie-tnJong .string to.surf ~g . . .NA 22 .CMTwill coyer.alll<oownproducìiye borizon.s. . · Yes 23 .Casing designs ad.equa.te for C,T, B.&.Rermafro$t . . · Yes 24 Adequatetan.kage.oJ re.serve pit. Yes Nab.ors2ES. . . 25 Jfa. re-drilt bas. a 1.00403 for abandon.ment beeo apPJoved . . . · Yes 9/13120.04. - - - - - 26 Adequate .wellbore separatio.n -Proposed. . . . . . . . . . . . . . . . . . . ..... Yes .. - - - - - . - - - - - - - - - - - - - -- 27 Jfdivecter required, does iemeet reguJations. . . .NA Sidetrack.. . . . . Appr Date 28 Drilling fluid. program s~hematic. & eQ.uip Jistadequate. . · Yes Max MW.8~5. ppg, . . . . . . WGA 9/21/2004 29 .BOPEs.dothey meetreguJa.tioo . . . . . . · Yes - - - - - - - - - - - 30 .BOPEpress raiing appropriate; .test to .(puJ psig tn .comments) · yes Test 1.03500. psi. .MSr:> 2260 psi.. 31 .Chokemanifold cQrnpJies w/API Rr:>-53. (May 84). · Yes - - - - - - -- 32 Wort will occu~ withputoperatjon .sbutdown . . · Yes 33 .Is presence. of H2S gas. RrQb.able. . · . No NQtan H2S pad. 34 Mecba.nicaLcoodjtion of wens within ,A.Oß. yerifiecl (For s.ervice wßIJ only) NA Geology 35 Pe(l1')it can be issued w/o. hydrogen. s.ulfide meas.ure$. . . · No. 36 .D.ata.preseoted on. pote.ntìal pveJPre$.sure .zone$. . . · .NA Appr Date 37 .SßLsmic.analysjs of $lJaJlow gasz9nes . . NA RPC 9/21/2004 38 .SßÇlbed .conditioo sL!rvey(if oft-shore) . . . . . . .NA - - - - - 39 . CQntact namelphonefor.weekly prpgressreports [exploratpr:y .only] NA - - Geologic Date: Engineering Date Date Commissioner Commissioner ÐJs ~ J <<1-J~ ~0Y