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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG FEB 11 2019 la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 20AAC 25.105 20AAC 25.110 1b. Well Class: _ ,f,�, er'' — Developme `i1P1 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero I��'Ifl^T Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Aband.. 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 1/13/2019 196-087 318-368 3, Address: T Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 5/28/1996 50-029-20241-01-00 4a. Location of Well (Governmental Section): 8, Date TO Reached: 16, Well Name and Number: 6!7/1996 PBU J -07A 9 Ref Elevations KB 75.80 17. Field/Pool(s): Surface. 848' FNL, BOP FEL, Sec. 09, T11 N. R13E, UM Top of Productive Interval: 4022' FSL, 1110' FEL, Sec. 04, T11N, R13E, UM GL 38.40 BF 38.46 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18, Property Designation: Total Depth: 13T FSL, 1137' FEL, Sec. 33, T12N, R13E, UM 11148'18964' ADL 028281 & 028278 41b. 4b. Location of Well (Stale Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 643550 y- 5970505 Zone - ASP 4 12235'18944' 85-24 12, SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/rVD: TPI: x- 643140 y- 5975369 Zone - ASP 4 Total Depth: x- 643083 y- 5976763 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 Wndow DD Submit electronic and printed information per 20 AAC 25.050 N/A (k MSL) 8745'17261' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD, LWD, OR RES. NEU, DIR, CNL, 4Phase 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 20" x 30" 41' 121' 41' 121' 36" 213 cu ft PF 13-3/8" 72# N -W 41' 2683' 41' 2683' 17-1/2" 3861 cu If PF II, 279 cu It PF II 9-5/8" 47# N-80 40' 8745' 40' 7261' 12-1/4" 1525 cu ft Howcol-ile, 250 cu ft Class -G', 135 cu ft PF'C', 629 cu ft AS I 7" 26# L-80 38' 11069' 38' 8964' 8-1/2" 506 cu ft Gass'G', 186 Bbls Glass 'G' 4-1/2" 12.6# L -w 10937' 12235' 8936' 8944' 6" 196 cu It Class'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (MD/TV Size and Number, Date Perfd): 4-1/2" 12.6# 13CB0 10751' 10663'18828' 4-1/7'12.6# L-80 10852' - 10945' 10889' 13917' 11 � � (n� �0�" eemptETION— 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE 1 Was hydraulichsictunng used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11148' Set Whipstock 27, PRODUCTION TEST Data First Production- Not on Prod ion Method of Operation (Flowing, gas lift, etc.): WA Date of Test: Hours Tested: Production for OILRbI: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period y Flaw Tubing Press Casing Press: calculated 24 Hour Rete •y Oil -Bbl: Gas -MCF: Water -Bbl: Oil Grevitv - API(corn: Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ftRt6W RBDMS QCs- FEB 1 3 2019 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes ❑ No 21 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29, GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 10 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10826' 8898' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 10270' 8563' Shublik 10314' 8601' Sadlerochit-Zone 4 10416 8683' CGL - Zone 3 10670' 8831' Base of CGL Zone 2 10826' 8893' Formation at total depth: Zone 2 10826' 889T 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, cone 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: Hartley, Josephine Contact Email: Josephine.Hartley@bp.cem Authorized Title: SI p ialistqq / Authorized Signature: Date: f/ V/� Contact Phone: +1 9075644570 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 10407 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 welt 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 tb. 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 ceresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only Daily Report of Well Operations J -07A nrrnnrvnA7SI IMMARY CTU 9 2.375" CT Job Objective: Mill XN and WS Drift MIRU. Pump drift ball and perform weekly BOP test. 10/30/2018 **"Job in Progress*** CTU 9 - 2.375" CT. ***Continue from 10/30/18*** Job Objective: Mill XN and WS Drift Complete weekly BOP test, recovered 1.75" drift ball from coil. MU & RIH w/ Baker Left Handed milling MHA w/ 3.80" parabolic mill. Mill XN at 10925CTMD. Continue in hole with LH milling assembly and mill various spots down to 11500CTM. pullback up hole and dry drift from 10600 to 11500. OOH with LH assembly and the mill is still a 3.800 no-go and a 3.81" go. Makeup and RIH with WS drift BHA. RIH to 11500CTM, POOH. While POOH started having overpulls @ 4400', reached GLM #6 and unable to pull through, made several attempts to RIH and PBUH without luck. RIH and worked tools through GLM #5 @ 6092', PUH and still getting overpulls. Came online w/ Slick 1% KCL down backside and well pressured up, unable to PUH. RBIH in made multiple passes through GLM #5 attempting to wash tools. After 94 bbls away pressure finally fell off and well went back on a vac. POOH without issue, continue pumping safelube while POOH. Freeze protect well with 35bbl of 60/40. 10/31/2018 ***In progress*** TWO = CTU/15/150. Temp = SI. IA FL (CTU REQ). No AL. IA FL @ near surface. 10/31/2018 CTU in control of well upon departure. 22:00 CTU 9 - 2.375" CT. ***Continue from 11/01/18`** Job Objective: Mill XN and WS Drift Continue rig down. Travel to SLB shop 11/1/2018 ***Complete*** CTU #8 1.75" Job Objective: Set Whipstock pre -CTD MU Whipstock Drift. RIH w/ 3.77" BOT WS drift. Drift well through tight spots to 11300ft. Re drift until clean. POH. 12/1/2018 *** In Progress *** CTU #8 1.75" Job Objective: Set Whipstock pre -CTD Continue to POH with drift BHA. LD drift BHA. Cut 1 00f for chrome management. Change packoffs & check chains. MU & RIH w/ HES logging carrier. Log from 10,300' to 11,250'. POH. MU Whipstock Anchor and set mid element of anchor at 11,159.8'. POH. Download caliper data for setting orientation. Wait on Whipstock setting BHA 12/2/2018 *** In Progress *** CTU #8 1.75" Job Objective: Set Whipstock pre -CTD MU & RIH w/ Whiipstock BHA. Unable to get past 10859ft. POH. 12/3/2018 `** In Progress *** CTU #8 1.75" Job Objective: Set Whipstock pre -CTD MU & RIH w/ Whipstock BHA. Unable to get past 10,859 ft. POH. Modify snap latch by grinding flat bottom to a taper. RIH and latch whipstock into Anchor at 11,173', confirm snapped in with overpull. Drop ball to release setting tool from whipstock. TOWS 11148', 160deg LOHS. POOH. Laydown BHA. RDMO 12/3/2018 *** Complete *** T/1/0=0/0/50 Installed CDR Kill line # . Installed wing platform. R/D IA and OA risers. PT'd kill line flange and IA and OA integrals, see "Field Charted Tests" FW P's 0/0/0 see log for 12/7/2018 details. 12/17/2018 T/I/0=700/0/0 R/U CIW Lubricator W/ 4" "H" TWC #431 **`JOB INCOMPLETE*`*. SEE LOG. 12/17/2018IT/I/O = SSV/0/0. Torqued WVxBlind flange to 750 FT LBS. RDMO. ***Job Complete***. Daily Report of Well Operations J -07A T/1/0=560/vac/180. Temp = SI. TBG FL (Pre CTD). No AL, flowline or wellhouse. Kili line installed on flow cross. TBG FL @ 2310' (35 bbls). 12/18/2018 SV, W V, SSV = C. MV=O. IA, OA = OTG. 12:30. T/l/O = 595/0/0. Set 4" H TWC #439 @125" with Lubricator 840, Perfored LTT on TWC (Pass), PT'd against TWC 3500 PSI (Pass) Charted and Retained. RD Tree cap bonnet assy, RU 4" Tapped Blind Flange to SV, Torqued to 750 FT LBS, PT'd against SV 350/5000 PSI (Pass) Charted and Retained. PT'd WV Blind flange 350/5000 PSI Charted and 12/19/2018 Retained. RDMO. ***Job Complete***. FWPs = TWC/0/0. T/1/0 = TWC/0/110. Temp = SI. WHP's (Pre Rig). No change in pressures from prvious day. 12/20/2018 SV, SSV = C. MV=O. IA, OA = OTG. 23:30. T/I/O = TWC/0/110. Temp = SI. WHP's (Pre Rig). OAP increased 110 psi since yesterday. No change in IAP. 12/20/2018 SV, SSV = C. MV = O. IA, OA = OTG. 04:30. T/I/O = TWC/0/110. Temp = SI. Hold open bleed on OA (Pre Rig). OA FL @ Surface. No AL, flowline or wellhouse. Kill line installed on flow cross. Bled OAP to BT from 110 psi to 0 12/21/2018 psi in -45 min as/fluid mix 35 al Held open bleed. Continued on WSR datedl2/22/18. Continued from WSR dated 12/21/18. T/I/O = TWC/0/0. Temp = SI. Hold open bleed on OA (Pre Rig). OA FL @ Surface. No AL, flowline or wellhouse. Kill line installed on flow cross. Continued with open bleed on OA. Bled OAP and left open for a total of 6.5 hours. Bled a total of -35 gals of fluid to the BT. Monitored for 1 hour. No change in OAP. Final WHP's = TWC/0/0. SV, SSV = C. MV = O. IA, OA = OTG. 04:30 12/22/2018 T/I/O = TWC/0/10. Temp = Sl. WHP's (Pre Rig). No AL, flowline or wellhouse. Kill line installed on flow cross. OAP increased 10 psi since yesterday. 12/23/2018 SV, SSV = C. MV=O. IA, OA = OTG. 03:00 T/I/O = TWCNac/?. Temp = SI. WHPs (Pre Rig). No AL, flowline or wellhouse. Unable to obtain OAP due to gravel work yesterday. According to the DSO, the OA was inadvertanly covered with gravel. 12/26/2018 SV, SSV = C. MV = O. IA = OTG. 04:10 TWO = TWCNac/30. Temp = SI. Bleed OAP to 0 psi (Pre RIG). No AL. No well house, scaffold or flow line. Kill line installed on flow cross. OA cemented to surface. Bleed OAP to BT from 30 psi to 0 psi in 3 min (all gas). Monitored for 30 min. OAP increased 2 psi during monitor. Final WHPs =TWCNac/2. 12/28/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:45 TWO = TWCNac/20. Temp = SI. WHPs (Pre RIG). No AL. No well house, flow line or scaffold. Kill line installed on flow cross. OA cemented to surface. Bled OAP to BT from 20 psi to 0+ psi in 2 min (all gas). Monitored for 30 min. OAP unchanged. Final WHPs = TWC/Vac/O+. 12/31/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:30 TWO = TWCNac/20. Temp = SI. WHPs (Pre Rig). Flowlines and wellhouse removed. OA valve and wireless gauge burried in -3' of snow. Shoveled out snow to visually confirm OA CV = O and OA = OTG. Unable to check OAP with calibrated gauge due to the placement of installed cellar boards. OA wireless gauge reading -20 psi. SV, WV, SSV = C. MV = O. IA, OA= OTG. 23:50 1/7/2019 Common Well Name: J-07 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU Rig Name/No.: CDR -2 Rig Contractor. NABORS ALASKA DRILLING INC. Active datum: KB @75.80usft (above Mean Sea Le Date From - To Him (hr) 1/10/2019 10:00 - 14:30 4.50 1430 - 1830 4.00 18:30 - 22:00 3.50 North America - ALASKA - BP Operation Summary Report Start Date: 1/10/2019 Site: J APE No End Date: 1/20/2019 X3 -0197K -C'.(1,534,876,00) Rig Release: Task Code NPT Total Depth Phase Description or Operations (usft) RIGID P PRE RELEASED RIG FROM P-D4A FINISH RIG DOWN. PULL OFF WELL INSTALL JEEPS RIGID P PRE MOVE RIG FROM P -PAD TO J -PAD RIGU P PRE ARRIVE ON PAD Page 1 01?4, Printed 1/28/2019 11:26:38AM **All depths reported in Drillers Depths" VERIFY PRESSURE ON IA / OA. SHUTALL VALVES. LAY DOWN HERCULITE AND 12X 12 CHOCK BLOCK. PJSM FOR PULLING OVER WELL PULL SUB OVER WELL. SPOT MUD -MODULE 2200'. - 0000 2.00 RIGU P PRE ACCEPT RIG AT 22:00 - BEGIN RIG UP CHECK LISTS 1/11/2019 00'.00 - 0800 6.00RIGU P PRE CONTINUE WITH RIG UP CHECKLIST PERFORM LTT BETWEEN MASTER AND SWAB TO 3500# GOOD TEST RIG UPANCILLARY EQUIPMENT AROUND RIG. WELL SUPPORT RIGGING UP FLOW BACK TANK INSTALL MPD LINE. _ 06:00 - 0830 2.50 RIGU P PRE RIG DOWN SLINGS ON BOP STACK. PREP RIG FLOOR FOR BOP TEST. CHECK VALVE LINEUP THEN CIRCULATE WARM WATER AROUND. GREASE RIG VALVES THAT WILL BE TESTED. OPEN BLEEDERS WHILE CIRCULATING TO PURGE AIR OUT OF SYSTEM. 08:30 - 10'.00 _ 1.50 BOPSUR P PRE PJSM WITH CH2 GREASE CREW. GREASE TREE VALVES. PJSM WITH NABORS CREW FOR TESTING BOPS. DRILLER AND WSL REVIEW PRESSURE XCHECK VERIFICATION CHECKLIST. LINE UP VALVES FOR SHELL TESTAGAINST MASTER VALVE. SHELL TEST TO 250 / 4500 PSI, GOOD. CALL AOGCC REP MATT HERRERA TO COME OUTAND WITNESS. 10:00 - 14:00 4.00 BOPSUR P PRE TEST BOPSAS PER AOGCCAND BP GUIDELINES TO 250/ 3,500 PSI: TEST 1: BLIND / SHEARS, R1, BLtA, B1, B4 - PASS TEST 2: ANNULAR (2-3/8"), TIW2, B3, B2, BL1 - PASS TEST 3: UPPER 2-3/8"PIPE /SLIPS, TIW1, BL2, R2, T2, C15 - PASS TEST 4: C16, Ti, C11 -PASS TEST 5: VBR (2-3/8"), C7, C9, C10, TV2 C10 LEAKING, CYCLE AND GREASE. RE -TEST IS GOOD. C10 - FAIL / PASS C9, C7, TV2-PASS TEST 6: LOWER 2-3/8" PIPE /SLIPS, C5, C6, C8, TV1-PASS TEST 7: CHOKE A, CHOKE C - PASS Printed 1/28/2019 11:26:38AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name. J-07 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 1/10/2019 ,End Date: 1/20/2019 X3 -0197K -C:(1,534,876.00) Project: PBU Site: J Page 2 Rig Name/No.: CDR -2 Spud Date/time: 7/25/1977 12:00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usit) J _ 14:00 - 16:45 2.75 BOPSUR P PRE CREW CHANGE AND PJSM WITH ONCOMING CREW. REVIEW DRAWDOWN TEST PROCEDURE. CONDUCT DRAWDOWN TEST, RECORD CLOSING TIMES. TEST GAS ALARMS. RECONFIGURE TEST JOINT FOR REMAINING BOP TESTS. TEST 6: ANNULAR (3-112"), Cl. C4 ANNULAR HAS SLOW DRIP. CYCLE ANNULAR AND RETEST, GOOD. ANNULAR - FAIL/ PASS, C1, C4 - PASS TEST 9_ VERS (3-1/21, C2, C4-- PASS 16.45 - 21:00 4.25 BOPSUR P PRE PREP FOR TEST I0. REMOVE TEST JOINT. INSTALL DRILLING RISERS / QTS EQUIPMENT. BLEEDING AIR PRESSURE OFF COIL. TAKING AWHILE LOAD COIL WITH FRESHWATER TO HELP EVACUATEAIR. PUMPAT1.5BPM. REMOVE FLOATS FROM UQC. MAKE UP UPPER QUICK 21:00 - 22:00 1.00 BOPSUR P PRE STAB INJECTOR FLUID AERATED. PUMP VOLUME FORWARD TO FLUID PACK. LINE UP VALVES FOR TEST 10 22:00 - 22:30 0.50 j BOPSUR P PRE TEST#10 IRV/RACKOFF/C9&CIO BACKWARDS ATTEMPT TO GET LOW PT. LEAKINGAT C168L. TROUBLESHOOT. C9 LEAKING. GREASE/ CYCLE. PERFORM 250 PSI LOW / 3500# HIGH IRV/PACKOFF/ C10 BACKWARDS PASS C9 FAIL/ PASS 22:30 - 00:00 1.50 BOPSUR P PRE PJSM WITH CREW. VALVE CREW TORQUED TREE WHILE INJECTOR_ STACKED ON IT. 1/12/2019 22:30 - 00:00 1.50 KILLW P PRE BULLHEAD KILL - PRESSURE UPAGAINST MASTER TO 1500# WITH METHANOL - 10 BBLS SPEAR OF METHANOL 1500# @ 1.5 BPM 290 BBLS OF 1% KCI -4.7 BPM @ 2600# 00:00 - 04:00 4.00 KILLW P PRE FINISH WITH TORQUEING TREE BOLTS. INSTALL FLOATS. PRESSURE TEST TO 3500# PASSED PRESSURE TEST UQC. DISPLACE COIL OVER TO DRILLING MUD. 10400 - 06:00 2.00 KILLW P PRE PJSM, REVIEW PROCEDURE FOR PULLING TWO PRIOR TO BULLHEAD. j FLUID PACK BPV LUBRICATOR WITH MEOH AND PT TO 25013500 PSI, GOOD. 06:00 - 06:45 0.75 KILLW P PRE BLEED DOWN BPV LUBRICATOR, NOT BLEEDING OFF. TROUBLESHOOT. LINE TO TIGER TANK IS FROZEN. 06:45 - 08:30 1.75 KILLW N PRE PJSM WITH NABORS CREW FOR CLEARING LINE TO TIGER TANK. HARDLINE CREW COMING TO HELP THAW OUT THE LINE. WARM UP RIG SIDE OF HARDLINE AND DISCONNECT BLEED HOSE, WARM IT UPAND CLEAR IT. Printed 1/2812019 11:26:38AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 dA Operation Summary Report Common Well Name. J-07 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 1/10/2019 End Date: 1/20/2019 X3 -0197K -C:(1,534,876.00) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12:00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB Q75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 08:30 - 10:30 2.00 KILLW N PRE PJSM WITH HARDLINE CREWAND NABORS FOR THAWING REST OF LINE. WRAP LINE WITH VISOUEEN AND HEAT FROM BOTH ENDS. TWO MORE HEATERS ARRIVE, HEAT LINE FOR ABOUT HOUR. 10.30 - 11'.00 0.50 KILLW N PRE TRY TO PURGE THE LINE WITH AIR FROM THE RIG SIDE. FLUID IS SEEN LEAKING OUT THE HARDLINE FROM A SPLIT IN THE LINE, ABOUT 2 FEET FROM A UNION AND MIDWAY BETWEEN THE RIG AND THE TIGER TANK. ABOUT 1 GAL OF FRESH WATER HAS LEAKED OUT, CAUGHT IN CONTAINMENT. CLEAR AREA, DISCUSS PLAN FORWARD WITH HARDLINE CREW AND RIG CREW. NOTIFY SR WSLAND CTD SUPT. 11:00 - 13:30 2.50 KILLW N PRE HOOK UPA VAC TRUCK TO THE RIG SIDE OF THE HARDLINE, EVACUATE FLUID FROM THE SPLIT TO THE RIG. CONTINUE HEATING THE TANK SIDE OF THE HARDLINE, CHECK OCCASIONALLY TO SEE IF _ ITSTHAWED. 13:30 - 16'00 2.50 KILLW N PRE ABLE TO PUSH AIR FROM THE TIGER TANK BACK TOWARDS THE RIG. EVACUATE ALL REMAINING FLUID FROM HARDLINE WITH VAC TRUCK. KNOCK APART HARDLINE, TWO MORE JOINTS ARE FOUND WITH SPLITS. REMOVE ALL HARDLINE AND MAKE UP NEW LINE FROM RIG TO TIGER TANK. PRESSURE TEST LINE TO TIGER TANK TO 250 3500 PSI, GOOD. 16:00 - 20:30 4.50 KILLW PRE PJSM WITH VALVE CREW AND RIG CREW FOR PULLING TWC. PUMP 10 BBLS MEOH INTO STACKAND OUT STAINLESS STEEL LINE TO TIGER TANK, VERIFY RETURNS. PRESSURE TEST BPV LUBRICATOR 7O 3500 PSI, GOOD. PULL TWO. 1500# ON WELLBORE. PURGE LUBRICATOR WITH AIR. OFFLOAD LUBRICATOR. VALVE RECOVERED WITH SEAL INTACT 2030 - 21:00 0.50 KILLW P PRE PERFORM PRESPUD WITH ROY CREW AAR FOR BULLHEAD / PULL TWC WITH ROY CREW 21:00 - 22:30 1.50 KILLW P PRE PJSM, MAKE UP STINGER AND NOZZLE STAB INJECTOR. FLUID PACK FOR LUBRICATOR BREAK TEST. 250 PSI Printed 1/28/2019 11:26:38AM '"All depths reported in Drillers Depths" Printed 1/26/2019 11:26:38AM "All depths reported in Drillers Depths" North America - ALASKA - BP Page 4 qCtF Operation Summary Report Common Well Name: J-07 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 1/10/2019 End Date. 1/20/2019 X3 -0197K -C:(1,534,876.00) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean See Level) Date From - To Him Task Code NET Total Depth Phase Description of Operations _ _L _(hr) (usft) _ 1/13/2019 00:00 - 01:05 1.08 KILLW P PRE BULLHEAD KILL CONT'D - COMPLETE PUMPING A TOTAL OF 280 BBLS OF 1% KCL. - PUMP 20 BELS OF 8.BPPG QD-N PILL (HI VIS) - PUMP 152 BBLS OF 8.6 PPG QD-N - DRILLING MUD PUMPED AT 1980 PSI @ 4.5 BPM. - PRESSURE INCREASE WHEN HIVIS HIT OPEN PERFS. -SWAPPED TO COIL. PUMPED AT HIGH RATE OUT TO TIGER TANK TO FLUSH WATER OUT END OF COIL. OPEN SWAB WHEN PRESSURE HIT ZERO. PUMPACROSSTOP. WHEN CLEAN FLUID. BRING INSIDE. _ 01:25 - 02:00 0.58 KILLW P PRE PERFORM 30 MIN FLOW CHECK WHILE BUILDING BHA#1 WELLSTATIC. FILL HOLE AFTER 30 MIN. 1.1 BBL HOLE FILL. (2.2 BPH LOSS RATE) _ 02:00 - 03:00 1.00 STWHIP P WEXIT PJSM, DISCUSS BHA#1 MAKE UP. DISCUSS WELL CONTROL. MAKE UP WINDOW MILLING BHA INJECTOR ON: 03:00 _ 0300 - 04:00 1.00 STWHIP P WEXIT RIH WITH 3.80' WINDOW MILLING BHA#1 - RATE: 0.46 BPM IN, 0.99 BPM OUT. CIRC PRESSURE. 610 PSI _ - MUD WEIGHT'. 8.52 PPG IN, 8.45 PPG OUT 04'.00 - 05:00 1.00 KILLW P WEXIT DURING WALK THROUGH. TEFLON SPACER ON GRIPPER BLOCKS WAS SEEN WORKING ITS WAY OUT. STOP MOVEMENT. LOCKOUT INJECTOR. (2) CARRIER BLOCKS TABS BROKEN. TOOLPUSHER DISCUSSED WITH TOWN. 0500 - 06:15 1.25 KILLW N WEXIT DECISION TO PULLOUT OF HOLE TO REPAIR. 0615 - 07:00 0.75 KILLW N WEXIT NEAR SURFACE, 10 MIN FLOWCHECK IS GOOD. PJSM WITH NABORS AND BHI CREW FOR UD BHA. UD COILTRAK AND HANG 2 JTS pHs + MOTOR FROM_POL WINCH. _ 07:00 - 11:30 4.50 STWHIP N WEXIT PJSM WITH TOOLPUSHER AND MECHANIC FOR REPLACING RETAINING TABS ON GRIPPER BLOCKS. PERFORM LO/TO ON INJECTOR AND REEL WHEN NECESSARY. 11:30 - 1230 1.00 STWHIP N WEXIT INJECTOR REPAIRS FINISHED. PJSM WITH NABORS AND BHI FOR RUNNING BHA. MAKE UP BHA#2, SAME AS BHA#1. MILLAND REAMER 3.80" GO, 3.79" NO-GO. TEST QTS TO 3,500 PSI, GOOD. 12:45 - 14:45 2.00 STWHIP P WEXIT RIH BHA#2. 1445 - 1500 0.25 STWHIP P WEXIT LOG GR TIE-IN FROM 10460'. CORRECT -29' Printed 1/26/2019 11:26:38AM "All depths reported in Drillers Depths" Printed 1/28/2019 11:26:38AM **All depths reported in Drillers Depths** North America - ALASKA - BP Page 5 C( c Operation Summary Report Common Well Name: J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 1/10/2019 End Date: 1/20/2019 X3 -0197K -C: (1,534,876 00 ) Project PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12:00:OOAM I Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth I Phase Description of Operations (hr)_ I15DO . - 16:00 1.00 STWHIP P 11,148.00 WEXIT CONTINUE RIH. AT 10730' GETTING LIGHT RETURNS, AROUND B PPG. SHUT OFF PUMP FOR FLOWCHECK 10 MIN FLOW CHECK IS GOOD NO FLOW. TAKE RETURNS TO TIGER TANK FOR AWHILE UNTIL THEY CLEAR UP. NOTIFY CTD SUPTAGREE ON PLAN FORWARD. PASS TUBING STUB AT 35 FT/MIN, NOTHING SEEN. RUN TO 11,100' AND CLOSE EDC. UP WT HERE IS 46K. RIH CAREFULLY, LIGHT TAG AT 11,148' AT 0.5 _ _ BPM._ 16.00 - 1730 1.50 _ STWHIP P 11,148.00 WEXIT PICK UPAND GO TO FULL RATE. EASE DOWN AND START WINDOW AS PER BTT REP. OUT DENSITY STILL FLUCTUATING 7.8 - 8.4 PPG STILL GOING OUT TO TIGER TANK WITH RETURNS. _ 17.30 - 18:00 0.50 STWHIP P 11,148.00 WEXIT AFTER 1 M RETURNS HAVE CLEANED UP. l „O PURGE RISER OUT TO BLEED TRAILER THEN BRING RETURNSINSIDE SEL OUT TO GERT PUMP DIESEL OUT TO TIGER TANK THEN PURGE THE LINE WITH AIR. CONTINUE MILLING WINDOW. _ 18:00 - 21:15 3.25 STWHIP P 11,150.00 WEXIT MILL 3.80° WINDOW IN 4-1/2" LINER PER BAKER REP FROM 11148' MD TO 11150' MD RATE 2.50 BPM IN, 2.50 BPM OUT 1(� J�{ - MUD WEIGHT: 8.57 PPG IN, 8.53 PPG OUT - DWOB: 1.83 - 3.7 KLBS -CIRC PRESSURE: 2050 PSI - NOT DRILLING OFF. PICKUP TO INCREASE RATE AT ZERO WOB 21.15 - 00:00 _ STWHIP P 11,151.80 WEXIT MILL 3.80' WINDOW IN 4-1/2" LINER PER 2.75 BAKER REP FROM 11148' MD TO 11151.8' MD - RATE: 2.70 BPM IN, 2.70 BPM OUT - MUD WEIGHT: 8.57 PPG IN, 8.51 PPG OUT - DWOB: 1.83 - 3.7 KLBS - FREE SPIN CIRC PRESSURE: 2481 PSI 1/14/2019 00:00 - 06:00 bol) STWHIP P 11,151.80 WEXIT MILL 3.80' WINDOW IN 4-1/2" LINER PER BAKER REP FROM 11151.8' MD TO 11156' MD - RATE: 2.70 BPM IN, 2.69 BPM OUT MUD WEIGHT:.6 BGIN, 8.51 PPG OUT SII- 7KBS - FREE SPIN CIRC PRESSURE: 2600 PSI - ESTIMATED CASING EXIT AT 11,156' Printed 1/28/2019 11:26:38AM **All depths reported in Drillers Depths** = CAK43RON 38.46' _'CONDUCTOR 2800' #, 96' Q 11657' p = - 10783' 8800' SS TOP OF 7' SCAB LNR NR 26#, L-800383 bpf, D = 6276' 13-3/8' CSG. 72111. 14-80. D = 12.347' 1/ -It AL bLV, U=b.ZSU- X 7- BKR ZXP FKR. D =i312' IKR HMC LNR I1GR D = 6.187' i18' CSG_ 470_ N-80_ D = B 681' -L267W 8628' Minimum ID = 3.80" @ 10932' MILLED 4-1/2" HES XN NIP 4-1/2' TBG, 12.68,13 -CM .0152 bpf, ID = 3.958' J -0 7A 14 -1/2 -TIEBACK SLV, D=5.250' H 10937' h 4-12' TBG,12.6#, L-80, .0152 bpf, D= 3.958' 10946' 7' X 4-112' BKR HMC LNR FDR D = 4.375' I10848' 1.0383 bot. D = 6.276' SAFETY NOTES: WELL > 70• @ 10963"•' MAX DOGLEG: 12 3- @ 8778'*** 13-318" CSG CRACKED BELOW BRAOENHEAD WELD -30" L "' 4-1/2" CHROMETBG'•• WELLHEAD STARTS AT9-518" CSG - NO ODA "'XN NIP APPEARS WASHED our" 1/2' HES X NP, D = 3.8' GAS LIFT MANDRELS ST MD PERFORATION SLAMRY DEV VLV REF LOG: DPC PERF PORT ANGLEATTOPPERF: 84-@11040' Note: Refer to Production OB for historical pert data SIZE I SPF I INTERVAL Opn/Sgz SHOT I SOZ 2-3/4" 6 11040- 11070 O 05116/16 6092 2-3/4' 6 11070- 11100 O 05/16116 2-7/8' 6 11240 - 11270 C 04/27115 6826 2-3/4' 4 11630 - 11750 C 06/10/96 2-314' 4 11810 - 11950 C 06110196 29 2-314' 4 12140 - 12180 C 06/10196 1.0383 bot. D = 6.276' SAFETY NOTES: WELL > 70• @ 10963"•' MAX DOGLEG: 12 3- @ 8778'*** 13-318" CSG CRACKED BELOW BRAOENHEAD WELD -30" L "' 4-1/2" CHROMETBG'•• WELLHEAD STARTS AT9-518" CSG - NO ODA "'XN NIP APPEARS WASHED our" 1/2' HES X NP, D = 3.8' GAS LIFT MANDRELS ST MD TVD DEV VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DMIJBKO 09123118 5 6092 5474 45 KBG-2 DMI09123118 4 8091 6826 48 KBG-2 DMI07105/04 3 9462 7863 29 KBG2 DW07105/04 2 10158 8466 30 KBG2 DMt'07/05/04 1 10563 8780 56 103G-2 DMI07108!04 9-518- MILLOUT WINDOW (J -07A) 8745' - 8795' Dil 4-1/2' HESX NP, D - 3.813' 10662' I-17' z 4-1/2' BKR S-3 P 10718' 4-1/2' HES X NP. D = 112' HB X NP, D=3.813- 1 X 4-1/2' BKR S-3 PKK D = 3875- 112' FES X NP. ID = 3.813' 7- X 4-1/2- BKR ZXP PKK D = 4.375- 1 11148' 45KB BOT ML SNAP LATCH WHPSTOCK (12/03118) 11560' ELM4-12' WFD ISO RBPM I CATCHER SUB 04122 I PBTD I DATE REV BY COMMENTS DATE REV BY OOMM84TS 10104177 ORIGINAL COMPLEHON 09/26/18 CJNJM) GLV CIO (09123118) 06111/96 SBR SIDEfRACK(J-07A) 11/06/18 JTMJMD MLLEDXNNPFLET03.80' 12/02/02 DMIKK RWO SUSPENDED 12/18118 MR/JMD SET SNAP LATCH WHPSTOCK 07106104 DCRIKAIA RAO 05/30/18 ZV/JMD XN NP WASHED OUT - ADDED NOTE 08/13/18 JNUJMD ADDED OKB, REF 8 BF ELEV P RUDHOE BAY LW WELL J -07A F1;Mff No: 9960870 API No: 50-029-20241-01 SEC 9, T11N. RI3F-848' FTL 8 804' FEL BP Exploration (Alaska) STATE OF ALASKA likLASKA OIL AND GAS CONSERVATION COMM. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate gi Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 196-087 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20241-01-00 7. Property Designation(Lease Number): ADL 0028278 8. Well Name and Number: PBU J-07A 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: Ft ECM E D Total Depth: measured 12235 feet Plugs measured 11560/12089 feet JUN I 7 1 J C f1 true vertical 8944 feet Junk measured feet JUN 2U 1 6 Effective Depth: measured 11560 feet Packer measured 10663 feet true vertical 8956 feet Packer true vertical 8828.27 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 41 -121 41-121 Surface 2642 13-3/8"72#N-80 40-2682 40-2682 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1298 4-1/2"12.6#L-80 10939-12237 8937-8944 8430 7500 Perforation Depth: Measured depth: 11040-11070 feet 11070-11100 feet 11240-11270 feet 11630-11750 feet 11810-11950 feet 12140-12180 feet True vertical depth: 8962-8964 feet feet 8964-8964 feet 8962-8962 feet 8949-8943 feet 8943-8940 feet 8943-8943 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 0 7 2016, 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: 127 1878 570 2000 176 Subsequent to operation: 1722 31851 2496 1260 488 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development (1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ' IA- C / `--,c�1�.�— Phone +1 907 564 4424 Date 6/15/16 Form 10-404 Revised 5/2015 V I"7-1- 7. '1110 RBDMS 1,v JUN 2 1 2016 Submit Original Only 7L /I • m U)• o o O O O O m rr � c0oLe3oo r-- 17, ) N o 0 0 0 0 0 CO 'Cr N- CO CO CO • O N CO Cr m I- (O 00 CO 00 N N 'CrCO O CO O CO CO CO CO r- (NI0) CO CA N N— ti co co co H N- ti O 00 C7 L() CO CO C N O ti N co c N CA N 00 CO C\ OCO ✓ o 2 Q < N- C7) CO O I� CO (h Ln CO coDI 'Cr V CO CO 0 CO 0 • CO W CL OO O O 00 co O 00 O Cn _ Z Z' J J J O __ G) ch N J *k Co c.0 . N X r *k N N U (NJ N N N 0) ' i i V L a)0 V O 0") M C 00 (O O N- N CO J N CO CO w w _Q Q c� woo N U w w O LL � C c Z Z O Z w w w m m UU) Zf- • • Packers and SSV's Attachment PBU J-07A SW Name _ Type MD TVD Depscription J-07A TBG PACKER 10662.54 8828.27 4-1/2" Baker S-3 Perm Packer J-07A PACKER 10947.3 8939.61 5" Baker ZXP Top Packer • • C m = f a ± O • C cc 2 % L \ = 2 % � I o § p (a ± _ / * / a 2 \ a) : c *7 @ # c E d C G = oE D , u t 2 e ƒ a \ (0 0 tet G E / r E _0 \ g:)- = - c 6 \ o 2 • e E E co ± ƒ ri o § / / P § i t„, 0_ o = oe m 9- 2222 , \ o / a 2E6 � G $ E § = 2 / -1o » < ■ \ G \ c 6 = a / I ± o » $ / co a ° 1- - § / E E ƒ 7 / 2 f / * O L E E o 22 � 7 2 / / I ' / % = t r ± g b g / / ƒ yb % a % 7 � � / f � 9 \ �¥ � '� c � 0 / CCa � LI & 0t \ c < 'aEk2 kU)a. e I.4 @ _ ® e = g a c a o / o y ƒ co k _ c . - o � ) 0 (0 \ k/ � m § 2 LI- ti k $ ai W o ° q \ / E ° @ Cl) Ct / « 2 .\ 2 / ƒ o Cl)m o I - c \ ƒ o ± of /� � % U � � T- 2 ± , / 2 _ m o / D \ / \ / \ c / / ./ // \ \ : 03 J ® c E= e m c m / 5 = ƒ % R \ ƒ 2 CO w I m 2 . \ \ • _ _ - o § @ _ $ _ & O P o - c -i $ ® ° ® 42 # - © c ° O O 0) ^ e O / \ / \ = o / _v E e CO . £ 2 o £ �� E / % © = f (0 0q \ fK / / / a C) Oa - D0 I ? / ? 2 ,- SDC ° -c -0 ® o R o - o R - e D b R I - m i- 6 = & 2 o O ; - o ± c 2 U o A : 2 O r m L H o o c >a / / N- -' / .- » » o / 3 3 o I22r ® \ r r \ < TREE= VVELLFEAD= FMC ENV • J -07A ----.-40,NOTES: WELL>70* 10963'*** MAX ACTUATOR= OT1S DOGLEG:12.3*@ 8778'***13-3/8"CSG CRACKED SNIT1Al KB.ELE 68.4' >+ rZ1 BELOW BRADENHEAD WELD—30"L***4-1/2" BF.ELEV= 40.16' r r,.;y CHROME TBG*** WELLHEAD STARTS AT 9-518" KOP= 280 "CONDUCTOR, — 7 '' 1 CSG-NO OOA'•* 0' — Max Angle-' 96°@ 11652 —#, f' .�f Datum MD= 10783' D= " �k. ' rte. [tum TVD= 8800'SS + * 2193' --{4-112"FES X NP,D=3.813" I r �-- TOP OF 7"SCAB LNR — } r' 1500' `.+,"� r V''a GAS LFT MANDRELS 7"LM,26#,L-80,.0383 bpf,ID=6.276" — 2118' * i ST MD TVD DEV VLV TYPE LATCH PORT DATE ,.• 6 3638 3619 20 KGB 2 DOME BK 16 07/15/04 13-3/8"CSG,7211,N-80,D=12.347" —2670' +. 5 6092 5474 45 KBG-2 SO BK 20 07/15/04 'r °w 4 8091 6826 48 KBG-2 DMY BK 0 07/05/04 BOTTOM OF SCAB LNR —1 8628' L+. � 3 9462 7863 29 KBG-2 DMY BK 0 07/05/04 7"TIO3ACK SLV,D=6.250' — 8629' y. 2 10158 8466 30 KBG-2 DMY BK 0 07/05/04 1 10563 8780 56 KBG-2 DMY BK 0 07/05/04 19-5/6"X 7"BKR ZXP PKR D=6.312* —1 .' 8637' r 9-5/8"X 7"BKR HMG LNR HGR,D=6.187" —{ 8642' a9-5/8"M1LLOUT VVI! OW(J-07A) 8745'-8795' F9-5/8"CSG,47#,N-80,D=8.681" —{ 8745' 1 1 10631' —14-1/2" Minimum ID = 3.725" @ 10932' z X 10652' H7"x 4-1/2"BKR S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE 1071$'-1—(4-1t2"HES XNP,D=3.813" 1 I 4-1/2'TBG,12.6#,13-CR,.0152 bpf,D=3.958' —{ 10739' ` 10740' —14-1/2"MULESHOE WLEG,ID=3.958" 4-1/2"TBG STUB(XX/XX/XX) H 10841' 1-- ' ' 10878' -14-1/2"HES X NP,D=3.813" Z Z---4 10889' }—7"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 10912' —14-1/2"HES X NP,13=3.813" I I 10932' H4-1/2"HES XN NP,D=3.725" 4-1/2"TIEBACK SLV,D=5.250" —1 10937' 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" — 10943' . 10945' H4-112"WLEG,D=3.958" 7"X 4-1/2'BKR HMC LNR HGR,D=4.375" H 10949' J 1 10945' —17"X 4-1/2"BKR ZXP PKR,D=4.375" PERFORATIONS&M4ARY 11560'ELM 4-1/2"WFDISO RBPw/JUNK REF LOG: DR FEW S''...... "F` �CATCHDT SUB(04/22!15) ANGLE AT TOP PBTF: 84°(4,)11040' `Note:Refer to Production DB for historical pert data SIZE SPF INTB VAL Opn/Sqz SHOT SOZ ` 12089' —(0 /29/13) BP 2-3/4" 6 11040-11070 0 05/16/16 44k) {04/29!13}23/4" 6 11470-11100 O 05!16/167"LNR,26#,L-80 , —1 11069'—I2-7/8" 6 11240-11270 O 04/27/15 . ___., _0383 bpf,D=6.276"2-3/4" 4 11630-11750 C 06/10!96 / ` 2-3/4" 4 11810-11950 C 06/10/96 ''V• 2-3/4" 4 12140-12180 C 06/10/96 ,����� PBTD H 12194' 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.953" —1 12235' DATE REV BY COIVIVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/04/77 ORIGINAL COMPLETION 08/14/11 JLJ/PJC GLV CORRECTION WELL: J-07A 06/11/96 SBR SIDETRACK(J-07A) 05/08/13 JRPfJMDSET 4-1/2CEP(04/29/13) PERMIT No:'1960870 12/02!02 DDW/KK MO SUSPENDED 04/22/15 CJS/PJC SET WFR ISO RBP _ API No: 50-029-20241-01 07/06/04 DCWKAII RWO 04/27/15 CJS/PJC ADPSTF SEC 9,T11N,R13E,848'FM..&804'FEL 07/15/04 GJB/KAK GLV 00 05/16/16 JLS/JMD ADPERFS(05/16/16) 08/06/04 ATIYTLP 13-3/8"CHANGE,SAFETY NOTE BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMioSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon Li Plug Perforations L2I Fracture Stimulate I] Pull Tubing LJ Operations shutdown ❑ Performed Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pod❑ Repair Well ❑ Re-enter Susp Well ❑ Other ROP ±r- 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 196-087-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6 API Number Anchorage,AK 99519-6612 50-029-20241-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028278 PBU J-07A 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 r! F Total Depth measured 12235 feet Plugs measured See Attachment feRE C E P V E D true vertical 8943 51 feet Junk measured None feet JUN 0 2 20155 Effective Depth measured 11560 feet Packer measured See Attachment feet true vertical 8955 65 feet true vertical See Attachment feet ,A0(3CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 38-118 38-118 0 0 Surface 2642 42 13-3/8"72#N-80 37 5-2679 92 37 5-2679 88 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1298 28 4-1/2"12 6#L-80 10938 02-12236 3 8936 16-8943 51 8430 7500 Perforation depth Measured depth 11240-11270 feet 11630-11750 feet 11810-11950 feet 12140-12180 feet True Vertical depth 8962 39-8962 09 feet 8949 29-8943 37 feet 8943 37-8940 24 feet 8943 34-8943 42 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment ' 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 SC.ANNEU 4 Ft L,,i�� 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 560 35649 2388 1160 1638 Subsequent to operation 97 2515 714 1100 172 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations 0 16 Well Status after work Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron a�.BP.Com Printed Name Garry Catron Title PDC PE Signature )f( Ci/e- Phone 564-4424 Date 6/2/2015 1777_ /i s(l)s RBDMS JUN - 3 2015 J-07A 196-087-0 Plugs Attachement SW Name Date MD Description J-07A 4/23/2015 11560 4-1/2"WFD Iso RBP J-07A 4/30/2013 12089 4-1/2"WFR CIBP Packers and SSV's Attachment ADL0028278 SW Name Type MD TVD Depscription J-07A PACKER 10662.54 8828.27 4-1/2" Baker S-3 Perm Packer J-07A _ PACKER _ 10889.12 8917.34 4-1/2" Baker S-3 Perm Packer J-07A PACKER 10946.25 8939.22 5" Baker ZXP Top Packer CD Ca 000000D cD — OcDLON- 00Ln0 — tiv �nLU C 4 N I" U 4g O� cc M M M M 7 OD N V' CO CO CID CO CO CO CO C7) r r CO N- I- O U) 00 ' M N- M O Lo CO O CO (3) ti 00 OD (O N O) CO OD O) N- N- CO N OD CO CO CO 00 CO (h (C7• Lo. CO C j co co O) M N M O) co co 4-0 O CO O O s- CO co Lo 11) N ON- N- O) CO CON co 0 0 0 r r r Cti CO 2 �+Q N 00 M co c0 I- M co CO Lo CO N co co Mg M N M 8 C o 1:2C Q O O O O O O Q corn 5O? c ' O J Z M J J r C dM # -ICN1* CCDCCOO � w X :co CSO r - (NJr C•1 03 O N _ CO _ C) N � N (j - NN 4 s ++ d) Cr) CO N ' 0 C co ON- CO N co J CO co .- N O O W W U0WW ac Z Z ZVocc � Z W W W m m m � HZDDDD 0UZZJU) F- HH a) Com • c E _ n = 2 n o a) - , o a) (1) ' N O p., N LL O O tL > - c0 U L 0r -c .0 (B -0 J C N 0- (N6 CO C C m o Q U -p F- Ili Q Q M y C -6 C L > }L� C C Q(N- EC a) 0 >- L a) a) -o oz. _ d C) O N 0 - 0 (n 0.. U D (1) > O L L > J � a) � o) a) > C C o) 0 p a) Q) as L 0 0 0 0 I _ C C L C C cn > U cM O_> a) a) c -0 C - (B . O *t O (n N N L O 3 c w o o ~ Q m m m o z tNy° 3 cU o o °)� °� co C Z U .0 � 0 Q o a) -0CLI -0 a� Q 0 0 0) W L C) U) 0) ca U) 3 a) u) c p a0 mi c N L E o +-' ,- CO C L NO a)ia) 3 co -0 -0 C — o ` N ` a) YC:i . _o TD OQDa U O � Ocn in 0: o >O E. o ~ Q C Q(O O CO O O J > L L z ci 0 a a3 — ND co nn0 N Lo a ALo� Q * Z '— o O Z COw "E a) Q LL O co C a) "a * 06 L c L , E - 0 Q a) o r 0_ CD Q * U � Q C Q r (g w-. O O '- oo � v = o c � H O Ntf) O o 0 0 0 O 0 O U o ,� = u) < a d I I o 7 II Ti (1 0 C II 0 co a) (6 (0 0 LL a. ca O CL Q U O O 0 O o CI) a E o � - Naa. O a) E � Q (�a- oMa" ch pO coCe o I— �� er)N °a c ~ �� co Q m C E 0 •� Qt!) = oi5o) c > (!) 0 Q- 'Qo J : > m •Q> (n Q o � 0 p -0 ai-0 CO o u_ H 0)U .° c ° C) � � U o^ zU o^ O 0 * _ N o c —C\I o a) •Fr)— Eng > a) oQ :,-, 0) ;� * N L * o m o a- c (o m o U c C a a) ru C") Q Q * CC) i0 Q N 73 co II i0 a n to Q n 0 N C a) _ ,- 0 v) c) N- a) M N CC v . > N- a) -0 UA N- a) -O O 0 Q 0 o . . Q) o 0 � -CD . LLL a a L) a -0U -0co co .- 0 CL Q_c ,_ - - U) U > 2 o in CL 2 0 > > 'S o -oo ac) > ° j 3 > > U > aO ca C0) o c° U J c CO 0 5 0 1 N N J % 0 N a0i Q W II * O D * U 0 = 0Y LC) a) a) acn ) Q Q.I— i TREE_ " CA MSN - - - J WELLJ-EAD= FMC GEN V -07A SAF_.(NOTES: W F1 l >70'@ 10963'••' MAX DOGLEG:12.3^@ 8778'"' 13-3/8"CSG CRACKED ACTUATOR= OTIS I ` I INITIAL KB.FIE 68.4 ., ' BELOW BRADENHEAD WELD-30"L•••4-1/2" BF.ELEV= 40-16' _'COPDUCTOR ? - > .a? CHROME TBG•" WELLHEAD STARTS AT 9-518" KOP 2800' #, ••• "1i ,1 CSG-NO 00A*** MaxAngle= 96'@11652' --= r..qty Datum MD= 10783' r?"l.�r WwmTVD= 8800'SS0 1 r`+ 'r 2193' -4-1/7FES XNP,13=3- . 813" TOP OF 7'SCAB LNR - 1500' ° el -4 L..'r GAS UFT MANDRELS r LW,26#,L-80,.0383 bpf,ID=6.276' H 2118' ' ST MD TVD DEV VLV TY FE LATCH PORT ATE 13-3/8'CSG,72#,N-80,D=12.347" -I 2670' t.r: 6 3638 3619 20 KG8 ME 2 DOBK 16 07/15104 r: 1115 6092 5474 45 KBG-2 SO BK 20 07/15104 4 8091 6826 48 KBG-2 DMY BK 0 07/05/04 BOTTOM OF SCAB LNR -I 8628' 3 9462 7863 29 KBG-2 DMY BK 0 07/05104 7' ACK SLV, =6.250' - 8629' N. P.4rA TD 2 10158 8466 30 KBG-2 DMY BK 0 07/05104 9 5/8'X 7"BKR ZXP PKR D=6.317 8637' F'a 1 10563 8780 56 KBG-2 DMY ;, BK 0 07/05/04 9-5/8'X 7'BKR ICAC LNR F$GR ID=6.187' - 8642' 9 5/8"MLLOIff VMDOW(J-07A) 8745' 8795' 9-5/8'CSG,47#,N-80,D=8.681' H 8745' 1 1 10631' -14-1/2"HES X NIP, D=3.813' Minimum ID = 3.725" @ 10932' C >- 10652' -17"x 4-1/2'BKR S-3 PKR D=3.875• 4-1/2" HES XN NIPPLE L_10718' -14-1/2'FES XNIP.13=3.813' It 1 [4-1/2'TBG, 12.6#,13-CR,.0152 bpf,D=3-958" - 10739' _ -- 10740' -4-1/2'Ml1LESHOE WLEG,D 3.95r (XX/XX/XX) = 4-1/2"TBG STUB -I 10841 ' ' 1087W H4-1/2"HES X NP,D=3.813' C Z-1 10889' -7'X 4-1/2'BKR S-3 PKR,D=3.875' ' 10912' -14-1/2"1-ES X NP,D=3.813" I I 10932' H4-12INV,D "HES XN =3.725' 4-1/2'TIEBACK SLV,D=5.250" - 10937' 4-1/2'TBG,12.6#,L-80,.0152 bpf,D=3.958' - 10943' , 10945' -14-1/2"WLEG,D=3.958" K 1'X 4-1/2'BKR I-IMC LM HGR ID=4.375' H 10949' ' 10945' H 7'X 4-1/2'BKR ZXP PKR,I)=4.375' 11560' ELM -4-1/2'Vs/FD ISO RBP w/JUNK Pft CATCHER SUB(04/22/15) PP .iii�iii... . F Mt ORATIONSUv1ARY ►•••••••• REF LOG: OFC FEW la1111111111111 ` ,1.1.1.11.1.1.1 12089' -4-12"WFRCBP ANGLE AT TOP PERF: 91'@ 11240' �/ ` (04/29/13) Note:Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn/Sgz SHOT SO7l 7"LNR 26#,L-80 H11069' 2-7/8' 6 11240- 11270 0 04/27/15 .0383 bpf.D=6.276' ` 2-3/4" 4 11630-11750 C 06/10/96 2-3/4' 4 11810-11950 C 06/10/96 /1�1�1 '111 2-3/4" 4 12140-12180 C 06/10/96 PBTD 12194' X4111 4-1/2"LNR 12.6#,L-80,.0152 bpi,D=3.953' - 12235' [SATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/04/77 ORIGINAL COMPLETION 08/14/11 JLJ/PJC GLV CORRECTION WELL: J-07A 06/11/96 SBR SIDETRACK(J-07A) 05/08/13 JRA'JM) SET 4-1/2CEP(04/29/13) PERIATNb.'1960870 12/02/02 DOW/KK RWO SUSP'BNDEO 04/22/15 CJS/RE SET WFR ISO RBP API No: 50-029-20241-01 07106/04 DCR/KAN MO 04/27/15 CJS/PJC ADPERF SEC 9,T11 N,R13E 848'FNL 8 804'FFl 07/15/04 GJB/KAK GLV(70 08/06/04 ATtYTLP 13-3/8"CHANGE. SAFETY NOTE BP Exploration(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the Original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Bevedy i~~incent Nathan Lowell Date: ~ '1 ~ Isl~ [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA • RECEIVED 0 SKA OIL AND GAS CONSERVATION COMMISSION MAY 2 9 2013 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well L] Plug Perforations U Perforate L] Other [J AOGCC Performed: Alter Casing ❑ Pull Tubing0 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 Q t Exploratory ❑ 196 -087 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20241 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028278 PBU J -07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL. 11. Present Well Condition Summary: Total Depth measured 12235 feet ' Plugs measured 12089 feet true vertical 8943.51 feet Junk measured None feet Effective Depth measured 12089 feet Packer measured See Attachment feet true vertical 8943.15 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" x 30" 30 - 110 30 - 110 0 0 Surface 2641 13 -3/8" 72# N -80 29 - 2670 29 - 2669.96 4930 2670 Intermediate 8717 9 -5/8" 47# N -80 28 - 8745 28 - 7260.79 6870 4760 Production 8602 7" 26# L -80 27 - 8629 27 - 7183.66 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11630 - 11750 feet 11810 - 11950 feet 12140 - 12180 feet True Vertical depth 8949.29 - 8943.37 feet 8943.37 - 8940.24 feet 8943.34 - 8943.42 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment 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 JUN ` 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 803 39015 2076 0 1731 Subsequent to operation: 794 21846 4224 0 1415 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ID . Gas L] WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Summerh s , Title Petrotechnical Data Technician -/ Signal_ - — / %/!/,�� / /��. J Phone 564 -4035 Date 5/23/2013 t; -F RBDMS MAY 2 9 201 ,f4- .5 Form 10 -404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0028278 CTU #9 1.75" Coil Job Objective: Set CIBP for GSO Rigged up and Pressure Tested. 4/28/2013 «Job Cont'd on 04- 29 -13» CTU #9 1.75" Coil Job Objective: Set CIBP for GSO .Cont'd from 04 -28- 13 Run PDS (GR /CCL) in 2.875" carrier, 3.70" CIBP drift 10823' CTM (Chemical Cut) Attempt to get in pumping down coil, down back side. No Joy. 3K overpull at 10720' CTM (TTL) Pooh. RIH with logging tools and 3.7" round nozzle. Tag TD at 12169' ctm. Logged from 12000 to 10000, flag pipe on the way at 12060' CTM. EOP at flag = 12064'.29' + 11' to mid element. RIH with 4 1/2 Weatherford CIBP to flag. Shift electronic depth to mid element depth at flag (12075') Rih to 12090' Set depth. Launch 5/8" ball. Good indication of set. Pick off clean. Rih and stack 3K on plug. Good set. Pooh. Plug gone. 5/8" Ball recovered. Rig down CTU 4/29/2013 «Job continued on 04- 29 -13» CTU #9 1.75" Coil Job objective: Set CIBP «Job continued from 04 -29- 13 Continue rig down of CTU, Travel to W -37 4/30/2013 «Job Complete» FLUIDS PUMPED BBLS 103 60/40 METH 103 TOTAL Casing / Tubing Attachment ADL0028278 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" x 30" 30 - 110 30 - 110 INTERMEDIATE 8717 9 -5/8" 47# N -80 28 - 8745 28 - 7260.79 6870 4760 LINER 2440 7" 26# L -80 8629 - 11069 7183.66 - 8963.82 7240 5410 LINER 1298 4 -1/2" 12.6# L -80 10937 - 12235 8935.78 - 8943.51 8430 7500 PRODUCTION 8602 7" 26# L -80 27 - 8629 27 - 7183.66 7240 5410 SURFACE 2641 13 -3/8" 72# N -80 29 - 2670 29 - 2669.96 4930 2670 TUBING 10714 4 -1/2" 12.6# 13Cr80 26 - 10740 26 - 8859.1 8430 7500 III TUBING 104 4 -1/2" 12.6# L -80 10841 - 10945 8898.58 - 8938.76 8430 7500 • • Packers and SSV's Attachment ADL0028278 SW Name Type MD ND Depscription J -07A PACKER 10652 8748.08 4 -1/2" Baker S -3 Perm Packer J -07A PACKER 10889 8841.49 4 -1/2" Baker S -3 Perm Packer J -07A PACKER 10945 8862.96 4 -1/2" Baker ZXP Packer TREE = ' _ CAMERON ill WELLHEAD FMC GEN V SAFETY NOTES: WELL> 70 @ 10950' GOES HORIZ ACTUATOR 0713 J-07A _ E S 11108'. PRDTRK WELLBORE NOT SHOWN ON RNTIAL KB. ELE 68.4' DIAGRAM BELOW 9-5/8" CSG MILLOUT WINDOW. BE ELE' = • - 4 16' • • i i • 13 -3/8" CSG CRAB BELOW BRADENHEAD WELD KOP= 2800' i i • '* 4 APPROX. 30" LONG. *"*4 - 112" CHROME IBM** Nix Angle = 9 ' ' 11652' ii ► ►• ii W � STARTS AT 9 -518" CSG - NO 00A. Date ND = 107 83' ∎•4 ► •∎ ∎• � ■ Datum TVD = 8800' SS . • • • 111 • • *Al ► �� ►• 1.11 I TOP OF SCAB LNR H 1500' �Q ► ► 11 �•� ►� • ► ••4 • .. 2193' H4 -1/2" HES X NP, D = 3.813' 17" LW, 26#, L-80, .0383 bpf, D = 6.276* I 2118' r • ► • •►•• ►• • ► • ► ' 4 • ►• I 13 -3/8" CSG, 72 #, N-80, D = 12.347" H 2670' ;•1 ' • GAS LET MANS ► A ST M3 TV D DEV VLV TYPE LATCH PORT DATE i i • *4 6 3638 3619 20 KGB DONE BK 16 07/15104 ► ►� 5 6092 5474 45 KBG-2 SO BK 20 07/15/04 D 4 8091 6826 48 KBG-2 DRMK BK 0 07/05/04 ' • ► • 3 9462 7863 29 KBG-2 DMY BK 0 07/05/04 I BOTTOM OF SCAB LM I 8628' ► ,� 2 10158 8466 30 KBG-2 DNK BK 0 07/05/04 I TOP OF 7" *TIEBACK SLV, D = 6.250' I 8629' 1 1 63 8780 56 KBG 2 OW BK 0 07/05/04 I 9-5/8" X 7" BKR ZXP PKR, D = 6.312" H 8637' 0 Mk •� 0 ��� LOUT VIIMDOVM - 8745' - 8795' 9-5/8" X 7" BKR MAC LW HGR, D = 6.187" 8642' "® ® W/ 9-5/8" SECTION NFL 9-5/8" CSG, 47 #, N-80, D = 8.681' I- { 8745' I 1 10631' H4 -1/2" FE5 X NP, D = 3.813° I Minimum ID = 3.725" @ 10932' _. I 10652' 1---17" x 4 -1/2" BKR S-3 PKR, D= 3.875" I 4-112" HES XN NIPPLE I I 10718' H4- 1 /2"FESX WI, D= 3.813" I 10740' H4-1/2" MULESHOE WLCG, 13= 3.958" I4-1/2" 713G, 12.6#, 13-CR, .0152 bpf, D = 3.958" 10739' 10841' CFA CUT I I 10878' H4 1/2" FES X NP, D = 3.813' ►IC I 10889' H 7" x 4 -1/2" BKR S-3 PKR, D = 3.875' I I TOP OF 4-1/2" TRACK SLV, D = 5.250' H 10937' I 10912' H4 112" HES X 1■8 D = 3.813" 10932' H4 -1/2" I-ES XN Imo', D = 3.725" I I 4- 112" TBG,12.6#, L-80, .0152 bpf, D = 3.958" }-I 10943' I ► =' ► =, 1Q5' --I4- 112" WLHS, I) = 3.958" I I r X 4-1/2" BKR MAC LNR HGR, D = 4.375" H 10949' -a a 10945' H r X 4-1/2" BKR ZXP PKR, [7= 4.375" I FERFORATiON SUMMARY REF LOG: DPC PERF f ANGLE AT TOP R: 96' @ 11630' I F ft Note: Fiefer to Production DB for historical pert data 1 •4.4.4.4.4► I 12089' I 41/2' WFR CEP SIZE SPF MSZVAL Opn/Sqz SHOT SW. ■ • ■ • 1(04/29/13) 2 -3/4" 4 11630 -11750 0 06/10/96 1••••••••• % •••••••••• / 2 -3/4' 4 11810 - 11950 0 06/10/96 •• 14•••4••6• 2 -3/4" 4 12140 -12180 C 06/10/96 1 • • • • • • • • • • • • • • • • • • 1 / ♦ PBTD H 12194' I •••••••••1•• •• • • • •• • • I 7" LM , 26#, L-80, .0383 bpf, D = 6.276" H 11069' I �•••••i • 4 -1/2" LNR, 12.6#, L -80, .0152 bpf, D = 3.953" 12235' DOTE F V BY COMMENTS DATE REV BY COMMITS PRUDHOE BAY UNIT 10/04/77 ORIGINAL COMPLETION 08/14/11 JLJ/ PJC GLV GCTION WELL J-07A 06/11/96 SBR SIDETRACK 0-07A) 05/08/13 JRP/JM) SET 4-1/2 GBP (04/29/13) PERMT' No: '1960870 12102102 DDW/KK RWO SUSPENDED API No: 50- 029 - 20241 -01 07/06/04 DCRIKAK IMO SEC 9, T1114 R13E, 848' R4_ & 804' FEL 07/15/04 GJB/KAK GLV C/O 08/06/04 ATDrTLP 13 -3/8" CHANGE, SAFETY NOTE BP Exploration (Alaska) . STATE OF ALASKA ,,- ALASKÄ vlL AND GAS CONSERVATION Cdllll,\l1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage I Alaska 99519-6612 7. KB Elevation (ft): 75.8' 8. Property Designation: ADL 028278 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Tieback Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): IBI Repair Well 0 Plug Perforations 0 Stimulate IBI Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 12235 8944 12194 8943 feet feet feet feet Size 110' 2670' 8745' 20" x 30" 13-3/8" 9-5/8" 2432' 1290' 6522' 7" 4-1/2" 7" 11630' - 12180' 8949' - 8943' Tubing Size (size, grade, and measured depth): 0 Other 0 Time Extension 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Dnll Number: 196-087 6. API Number: 50-029-20241-01-00 9. Well Name and Number: PBU J-07 A 10. Field / Pool(s): Prudhoe Bay Field / pru~o~a~ po~~ ,- t(C'CEb ~,~.r~,~" \Ib n::( II None /. , . .~~ ,). " '1 .' ? None Alastå Oil & Ga,::~: ~'fJ"4 ,.J¡f!~ll:.-o~, O$; (.;:"'M;j!~k.... ~'c. '- W~I ., 'II... .''''I~ ~I II TVD Burst -. .,' Collapsé' Plugs (measured) Junk (measured) MD 110' 2670' 8745' 110' 2670' 7261' 5380 2670 6870 4760 7240 5410 8430 7500 7240 5410 8637' - 11069' 10945' - 12235' 2118' - 8640' 7189' - 8964' 8939' - 8944' 2118' - 7191' 4-1/2", 12.6# 13Cr & L-80 10945' Packers and SSSV (type and measured depth): (2) 7" x 4-1/2" Baker 'S-3' packers; 4-1/2" HES 'X' Nipple 10889' & 10652' 2193' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Perf two intervals to squeeze cement in the 13-3/8" x 9-5/8" annulus: 1965' - 1970' and 2010' - 2015' Treatment description including volumes used and final pressure: Place approximately 629 cu ft of Arcticset I in the 13-3/8" x 9-5/8" annulus. 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram RBDMS Sf 1. AUG 0 5 ?OO~ Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Conlacl Paul Chan, 564-5254 N/A Printed Name Terrie Hubble Signature /fR~ Çiu1WQ. Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date 08;64 /ð <{ Prepared By Name/Number: Terrie Hubble, 564-4628 SubmilOriginal Only 564-4628 Well: J-07 A, Rig Workover Accept: 11/28/02 Accept: 06/15/04 Field: Prudhoe Bay Unit Spud: NIA Spud: NIA API: 50-029-20241-01 Release: 12/01/02 Release: 07/05/04 Permit: 1 96-087 Rig: Nabors 4ES Rig: Nabors 4ES Date PRE-RIG WORK 10/12/02 TIO= 400/380/440 OA FL @ SURFACE. (PRE MITOA) 10/14/02 MIT OA TO 2000 PSI. 10/15/02 MIT OA TO 2000 PSI. MIT PASSED. 10/16/02 T/I/O = S1/40010. PPPOT-T PASSED. [OA WAIVER EVAL] TESTED TUBING HANGER VOID TO 5000PSI. VOID LOST 1 OOPSIIN 30 MIN. PPPOT-IC PASSED. TESTED PACK-OFF VOID TO 3000PSI. VOID LOST 50PSIIN 30 MIN. 11/27/02 PUMP 350 BBLS WATER DOWN IA FOLLOWED BY 100 BBLS DIESEL HEATED TO 120°. RIG UP TO TBG. PUMP 229 BBLS DOWN TBG FOLLOWED BY 35 BBLS DIESEL HEATED TO 120ü. INJECTION RATE OF 5 BPM @ 200# DOWN TBG. RIG DOWN. LEAVE WELL SHUT IN FOR SWS. RUN 1 : DRIFT WITH 3.5". TAG COLLAPSE AT 1788'. RUN 2: STRINGSHOT 10 FT. 240 GM. 3 WRAPS, POSITION & SHOOT AT 1746 FT. RUN 3: CHC 3.625" SEVERING HEAD. POSITION & SHOOT AT 1746 FT. 03/16/04 T/I/O= BPV/OIO. TEMP=SI. INSTALLED WELLHEAD CLAMP TO STABILIZE SPLIT 13-5/8" CASING (PRE RWO). 06/05/04 T/I/O= 01010 PPPOTrr-IC ROLL LDS TEST TUBING HANGER 5000, TEST IC HANGER TO 3200 PSI. ALL TESTS PASSED Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date { BP EXPLORATION Operations Summary Report Page 1 of 13 J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code P 11/28/2002 15:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 11/29/2002 00:00 - 01 :30 01 :30 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 11 :30 11 :30 - 14:30 14:30 - 18:00 18:00 - 21 :00 21 :00 - 22:00 22:00 - 23:00 23:00 - 00:00 11/30/2002 00:00 - 01 :30 01 :30 - 03:30 03:30 - 06:00 5.00 MOB 1.00 RIGU P 1.00 RIGU P 0.50 RIGU P 1.00 RIGU P 0.50 RIGU P 1.50 RIGU P 2.50 RIGU P 0.50 RIGU P 1.50 RIGU IP 2.00 RIGU P 1.00 RIGU P 2.50 RIGU P 3.00' RIGU P 3.50 RIGU N 3.00 RIGU P 1.00 RIGU I P 1.00 FISH P 1,00 FISH P 1.50 FISH P 2.00 FISH P 2.50 FISH P Spud Date: 7/2511997 11/29/2002 End: 12/1/2002 12/1 12002 4ES Start: Rig Release: Rig Number: NPT I Phase Description of Operations SFAL MOVE RIG 4ES FROM F-06 SPOT RIG OVER WELL J-07A. I LAY MATTING BOARDS,BERM SKIDS. CONNECT HOSES ACCEPT RIG AT 2000 HRS RAISE AND SCOPE DERRICK SLIP SAND LINE CALL ELECTRICIAN FOR BREAKER IN PIT MODULE. SCOPE UP DERRICK RD BLIND FLGIVALVES OFF TREE. RU INTRIGAL FLG. HARDLlNE TO TREE, RU LINES TO TIGER TANK. ACCIDENT INVESTIGATION AND SAFETY TIME OUT. NAD EMPLOYEE SEVERED TIP OF FINGER. COMPLETE ACCIDENT INVESTIGATION 1 SAFETY TIME OUT. PU LUBRICATOR, PULL BPV, FINISH RU LINES TO TREE AND TIGER TANK. PJSM I SPUD MEETING; DISCUSS JOB SCOPE, SAFETY, IMPORTANCE OF KEEPNG HOLE FULL, MULTI-TASK, FISHING OPER, RUNNING I LAYING ON PIPE. WELL ON VAC, PUMP 1 1/2 TBG VOL (-245 BBLS, TBG X IA ON V AC AFTER PUMP SHUT DOWN. SHOOT FLUID LEVELS ON TBG #1 AT 1080' - 30 MIN LATER TBG FL #2 AT 1120' SET AND TEST TWC NO TREE AND ADAPTER FLG, CHECK LOS 1 TORQUE PACKOFFS NOTIFIED AOGCC INSPECTOR CHUCK SCHIEVE OF UPCOMING BOPE TEST. MR SCHIEVE WAIVED WITNESSING THE TEST. NU BOPE FOUND CRACK IN 13318 CSG BELOW BRADEN HEAD. CRACK RAN ALONG WELD THEN SPIRALED DOWN APP 4 " FOR APP 18". CONFER WITH ANC / NS SUPV l ENG. AS TO THE NEXT STEP. THE DECISSION WAS MADE TO SECURE WELL, RDMO UNTIL FURTHER EVALUATION AND PROCEDURES CAN BE DETERMINED. CONDUCT BOPE TEST 250 I 3500 AS PER BP AND AOGCC PROCEDURES. GOOD TEST. PU LUBRICATOR AND PULL TWC PJSM: DISCUSS PULLING HGR / TBG. CONTROL LINES MONITORING 13318 CSG CRACK. RIH WITH BOT SPEAR. SPEAR INTO HGR, PU WT 40K. PULL HGR THRU BOPE AND ABOVE THE ROTARY TABLE. NO PROBLEMS WERE OBSERVERED WITH THE CRACKED CSG DURING THIS OPERATION. LD SPEAR AND HGR. RU TBG TONGS. CONTROL LINE SPOOLER, ATTACH CL TO SPOOLER. FINISH OUT OF HOLE W/40 JT 41/2" TBG AND A 24.95-FT CHEM CUT STUB. ALSO RECOVERED 1.700-FT (+1-) OF CONTROL LINE #1 AND 1,025-FT (+1-) OF CONTROL LINE #2. RECOVERED 20 SS BANDS. RD 4 1/2" EQUIP. RU 3 1/2" EOUIP. LOAD PIPE SHED W/3 1/2" DP. MU FTA #1 AS FOLLOWS: ROPE SPEAR, XO, BUMPER SUB, OIL JAR, XO, 6 EA. 6 1/4" DC. XO. START TIH. CREW Prlr,¡~,j ~ ¿ 2C"jJ 1 .15:29 pr.ll f c Page 2 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: J-07A Common Well Name: J-07A Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I From - To I Hours I Task Code NPT Phase 11/30/2002 03:30 - 06:00 2.50 FISH 06:00 - 06:30 0.50 FISH P P 06:30 - 07:30 07:30 - 08:30 1.00 FISH 1.00 FISH P P 08:30 - 09:30 1.00 DHB IN SFAL 09:30 - 10:30 1.00 DHB N SFAL ! 10:30 - 11 :30 1.00 DHB N SFAL 111:30 - 12:00 0.50 DHB N SFAl 12:00 - 14:00 2.00 DHB N SFAL ! 14:00 - 15:30 1.50 DHB N !SFAL 15:30 - 16:30 1.00 DHB N SFAl 16:30 - 18:30 2.00 DHB :N ,SFAL i 18:30 - 19:00 0.50 DHB IN SFAL 19:00 - 21 :00 2.00 DHB N SFAl 21 :00 - 22:30 1.50 DHB 'N SFAl 22:30 - 23:00 0.50 DHB N SFAL 23:00 - 00:00 1.00 DHB N SFAl 12/1/2002 00:00 - 01 :00 1.00 DHB IN SFAL 01 :00 - 02:00 1,00 DHB N SFAL 02:00 - 03:00 1.00 DHB N SFAl I 03:00 - 03:30 0.50 DHB N SFAl 03:30 - 05:30 2.00 BOPSUP P I 05:30 - 06:00 0.50 WHSUR: P '06:00 - 08:30 2,50 WHSUR P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:30 1.00 WHSUR P ! 10:30 - 12:00 1.50 RIGD P 6/15/2004 11 :00 - 12:00 1.00 MOB P PRE 12:00 - 16:00 4.00 MOB P ,PRE ! 16:00 - 18:00 2.00 RIGU IP : DECOMP I Spud Date: 7/25/1997 Start: 11/29/2002 End: 12/1/2002 Rig Release: 12/1/2002 Rig Number: 4ES Description of Operations CHANGE. WORK FTA 1 DOWN TO 1,707-FT DRillER'S DEPTH...TOF (4 1/2" CHEM CUT STUMP). TOOH. lAY DOWN CONTROL LINE FISH. RECOVERED 100°0 OF BOTH CONTROL LINES {BOTH LINES PUllED OUT OF THE CONNECTIONS IN THE SSSV). RECOVERED 3 MORE BANDS FOR A TOTAL OF 23 EA. (34 BANDS REMAIN IN THE HOLE) MU 8 1/2" Mill AND 9 5/8" CSG SCRAPER (DRIFT RUN FOR RBP). TIH TO 1 ,676-FT DRILLER'S DEPTH. PUW = 48K...SOW = 36K. lD 2 SINGLES. CASING DRIFTED OK. TOOH WICSG SCRAPER. LD MILL AND SCRAPER. RU FIRST ENERGY. PT LINES TO 3,000 PSI...GOOD. PUMP 20 BBlS DIESEL. PU HOWCO 9 5/8" RBP. TIH AND SET AT 1,642-FT DRILLER DEPTH. BRIDGE PLUG NOT SETTING, FILL HOLE WITH DIESEL. SETIRESET TEST BP SEVERAL TIMES. MONITOR WELL, ORDER MORE DIESEL RESET BP FLUID BYPASSING BP. SET 27K ON BP. Fill HOLE WITH DIESEL, TEST TO 2500 PSI, HOLD 15 MIN WITH WT ON BP RELEASE FROM BP, TEST TO 2500, HOLD 15 MIN. NO LOSS IN PRESSURE, GOOD TEST. PULL 1 JT/DP. FLUID LEVEL IS STATIC. POH, LD 32 JTS DP, PU 4 DC AND 9 5/8 BP RIH WITH BP AND SET AT 740' DRILLER DEPTH. TEST BP TO 2500 PSI FOR 15 MIN. NO LOSS IN PRESSURE. GOOD TEST. TOH LD DP.DC AND BRIDGE PLUG SETTING TOOL. FINISH TOOH. LD DP AND DC. C AND C FLOOR. RU 4 1/2" EQUIPMENT. PU TAILPIPE ASSY AND 1 JT OF 4 1/2" TBG. DUMP 20 SXS OF 20/40 MESH SAND ON TOP OF RBP AT 740-FT. TOS = 715-FT TIH WITH KILL STRING AS FOLLOWS: WLEG, PUP JT, X NIPPLE, PUP JT, AND 15 JTS OF 4 1/2" X 12.6 LB, L-80. IMP MOD BUTT TBG. LAND HANGER WITH WLEG AT 667-FT OKB. RllDS. LD LANDING JT. SET AND TEST TWC. ND BOPE. PREPARE TO NU ADAPTOR HEAD. CREW CHANGE. PJSM. FINISH NU ADAPTOR HEAD. TORQUE AND TEST TO 5K...GOOD. NU TREE. TORQUE AND TEST TO 5K...GOOD PU LUBRICATOR. PULL TWC. INSTALL BPV. LD LANDING JT. BLOW DOWN LINES. FINISH CLEANING RIG PITS. SECURE TREE AND CELLAR. RELEASE RIG. RD off of J-06. Move Rig and support Equipment from J-06 to J-07a Take on Seawater lo rig pils. RIU hard lines lo tiger tank & tree. Pr,r,I€:-:1: ;' t,200. , .15:19 PU Page 3 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/1 5/2004 Date J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours I Task I Code NPT Phase 2.00 RIGU P 1.00 PULL P 0.50 PULL I P 0.50 PULL P 0.50 PULL P From - To 16:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 20:30 DECOMP DECOMP DECOMP DECOMP DECOMP 20:30 - 21 :00 0.50 WHSUR P DECOMP 21 :00 - 21 :30 0.50 WHSUR P DECOMP 21 :30 - 00:00 2.50 BOPSUR P DECOMP 6/16/2004 00:00 - 03:30 3.50' BOPSUF P DECOMP 03:30 - 04:30 1.00 WHSUR I P DECOMP 04:30 - 05:00 0.50, PULL P DECOMP 05:00 - 07:00 2,00 PULL P DECOMP 07:00 - 07:30 0.50 DHB P DECOMP 07:30 - 09:00 1.50 DHB P DECOMP 09:00 - 10:30 1.50 DHB P DECOMP 10:30 - 12:00 1.50 DHB P DECOMP 12:00 - 13:00 1.00 I DHB P DECOMP 13:00 - 13:30 0.50 DHB P DECOMP 13:30-14:00 0.50 DHB P DECOMP 14:00 - 15:00 1,00 DHB P DECOMP I 15:00 - 16:00 1.00 DHB P DECOMP 16:00 - 17:00 1.00 CLEAN P DECOMP 17:00 - 19:00 2.00 CLEAN P DECOMP I I 19:00 - 20:00 1.00 CLEAN P DECOMP 20:00 - 00:00 4.00 CLEAN P DECOMP 6/17/2004 DECOMP Set back kelly. POOH to check shoe. Cleaned out junk basket. Had 1/2 cul of melal milling & 1 piece of control band. Inspect shoe. Shoe worn smoothe on inside & bottom cutting edge. DECOMP M/u BHA # 2. . 1/8" X 6" , Shoe & washover Pipe Assy. as follows: 8 1/8" x 6" Shoe, 4 jts Washover Pipe, Junk Basket, Bunper Sub, Oil Jars. XO, 96 1M." DCs. XO, XO. TL = 431.28'. RIH wI BHA #2. DECOMP Tag up @ 1726'. P/U kelly & wash down to 1759'. Con't to washlmill from 1759 to 1777'. Free Torq 2.3K. Mill Torq 3.4K. 8-12K WOB, 30-60 RPMs. No further progress made. DECOMP POOH. Clean Junk Baskets (metallillings). Inspect Shoe I 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 02:30 1.00 CLEAN P 02:30 - 08:30 6.00 CLEAN P 08:30 - 10:30 2.00 CLEAN P Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1/2002 Description of Operations Accept Rig at 16:00 hrs. M/U lubricator. Pull BPV. LID lubricator. Finish RIU lines to tree & test to 3500 psi. Hold Pre-spud & PJ8M meeting wI crew. Open well. SITP = 0 psi. SICP = 0 psi. Circulate out diesel freeze proleclion fluid thru kill string @ 668'. Pumped 5 BPm @. 280 psi. Pumped 60 Bbls os seawater, SID & mOnitored well.. Install TWC & tested same. Break down lines on lree. Bleed off hanger void. N/D X-mas tree & adapter flange. N/U BOPE. Pressure lest BOPE. LP 250 psi, HP 3500 psi. Tested as per BP/AOGCC requiremenls. BOP tesl wilnesslng waived by Jeff Jones wi AOGCC @ 1800 hrs, 6/15/2004. R/U lubricator & pull TWC. LID lubricator. M/U landing It Pull hanger & kill string lo floor. LID hanger. P/U wt = 18K. POOH & LID 4 1/2" kill string. Load 6 1/4" Drill collars in Pipe Shed. PU Halco Reteriving Tool and 9 ea 61/4" Drill Collars. PU 3 1/2" Drill Pipe. RIH...looking for lop of sand al -715'. TOS not there...RBP has went down hole. Continue pick-up 31/2" Drill Pipe. Found TOS at 16'+5'. Reverse Circulate oul sand, Lalch RBP. POOH. Lay down RBP #1, RIH wllh Reteriving Tool again. Tag TOS above RBP #2 al 1661' Reverse Circulate sand down to 1672'. Latch RBP #2. Work free, Well went on big vacuum. POOH & LID RBP. Clear & clean rig floor. R/U wash pipe handling tools. M/U BHA #1, Wash pipe assy as follows: 8 1/8" x 6 5/8' Shoe. 4 jts wash pipe, Junk baskel, Bumper sub, Oil Jars. XO. 9 -6 1/4" DCs, XO,XO. TL = 431.28'. RIH wI BHA #1 on 31/2" DP. Tag up on top of tbg Slub @ 1706'. P/U = 57K, 8/0 = 57K. P/U kelly. begin circulation, no returns. Work down over tbg stub from 1706 lo 1759'. started to have torquing. Rotate & wash/mill to 1570'. WOB 4-12K. 30 - 60 RPMs. Ran out of fluid. Not making hole. Plu to above stub @ 1706'. RIH & now tagging up @ 1726'. Pr,r'l.:-,j 7'':, ze,,:,--I , --15:29 pr,' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i BP EXPLORATION Operations Summary Report Page 4 of 13 J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 11/29/2002 12/1/2002 4ES Spud Date: 7/25/1997 End: 12/1/2002 Start: Rig Release: Rig Number: N PT ! Phase Description of Operations 6/17/2004 08:30 - 10:30 From - To Hours Task Code 2.00 CLEAN P DECOMP #2...Face of Shoe was gone...no cutting matenalleft, smooth. Inside of Shoe was good. Change Shoe. Remainder of BHA remains same as BHA 2. DECOMP RIH with BHA #3...8 1/8" x 6 5/8" Shoe. DECOMP Tagged TOF at 1,737' (TOF has moved down hole 31' from orginal tag of 1,706'...?). Swallow fish and tag up again at ,1,777'. Pick-up Kelly. Easy Washing/Milling down to 1 ,863'. Now bottomed out on "Drive-Sub",.. 125' or Tbg swallowed. This depth is also -31' deeper then it shaul be. (Collasped Jt maybe inside nexl Jt). DECOMP ¡ Circulate Well clean from 1,860' at 3 bpm...good returns. Monitor Well. DECOMP POOH with BHA #3. DECOMP : Lay down Shoe and Oil Jars. Clean Junk Basket...some metal filings. Pick-Up BHA #4...0ut Side cutter RIH wilh Oul Side Culter. Tag TOS al1 ,737'. Space out culter, locate collar & make cut 'g' 1853'. Pump 20 Bbls seawater. Set back kelly. monitor well. POOH w/ culting lools. DECOMP 1 Clean junk baskels. UD fish. Cut & recovered as follows: , 16.20' cut jt. 24.03' telescoped jt, 31.32' telescoped jt, 41.27' partially plugged full jt. & 3.00' outside cut it. Outside cut looked clean. TL of fish = 115.82'. DECOMP ,Finish laying down cullbg & culling assy. DECOMP ¡Clear & clean rig floor. RD washpipe lools. R/U lO RIH w/4 1/2" work slring. DECOMP M/U overshot wI 4 1/2" grapple to 4 1/2' tubing. DECOMP P/U 4 1/2" work string & RIH wI Overshot to 1853'. Enguage fish, PIU to 150K & check engaugemenl. Slack back off & set slips. Clear floor. RID tbg lools. Hold PJSM. R/U Slick line equip, RIH w/ 3.70" drift & brush on slickline to 10,932' POOH, Pick-up TT Plug..,3.725" RIH to 1,830' wlm (plug at 1,853 4es deplh which is depth of mechanical outside cut). Plug set down. Pull free (500 Ibs over). POOH. DECOMP Inspect Plug...saw nothing. Also discovered that Gauge Ring ran first was not 3.70"...but 3.497". Call oul for a 3650" - 3.70" GR. Discussed with Anch Eng and decided not to run TT Plug. Continue to drift for a 3.625" Chemical Cutter. DECOMP Continue to wait for proper sized GR. Pick-up a 3.695" Tappered Fluted Centrilizer to drifl through mechanical cul area. Ran down to 2,000' wilh no problems. (3.650" GR arrive Ion location). POOH. DECOMP Pick-up Brush and 3.650" GR. RIH and set down al2,055' wlm. Attempllo work lhrough. No-Joy. POOH. Inspect GR. Lip had several "Dings". Abort using lhe 3 625" Chem Cutter. Discuss with Anch Eng using a Jet Cutter or a 3.3ì5" Chem Cutter. DECOMP Pick-up lhe 3.497" GR and RIH to verify that it will still go to botlom. Ran to 10,932' with no problems. POOH. Discuss resulls with Anch Eng and decide to go with a 3 3/8" Chemical I I 10:30 -11:30 11 :30 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 15:30 115:30 - 17:00 17:00 - 17:30 17:30 - 21 :30 21 :30 - 23:00 23:00 - 00:00 1.00 CLEAN 1.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 1.50 CLEAN 1 P 0.50 CLEAN P 4.00 PULL P 1.50 PULL P ! DECOMP DECOMP I DECOMP DECOMP 1.00 PULL P 6/1 8/2004 00:00 - 01:00 1.00 PULL P 101 :00 - 01:30 0.50' PULL P 01 :30 - 02:00 0.50 PULL ¡p 02:00 - 03:30 1.50 PULL P 03:30 - 04:00 0.50 PULL P 04:00 - 05:00 1.00 PULL P 05:00 - 06:30 1.50 PULL P 06:30 - 07:00 0.50 I PULL P 07:00 - 08:00 1.00 PULL P DECOMP DECOMP DECOMP DECOMP 08:00 - 10:30 2.50 PULL P I I 10:30 - 11 :30 1.00 PULL P I 11 :30 - 13:30 2.00 ¡PULL P I P"r,l¿.d 7':, -'.ü(,.¡ ''¡5 2'~ PI.' ~ BP EXPLORATION Operations Summary Report Page 5 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/18/2004 J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I Hours I Task I Code NPT Phase 11 :30 - 13:30 2.00 PULL P 13:30 - 14:30 1.00 PULL P 14:30 - 15:00 0.50 PULL P 15:00 - 17:00 2.00 PULL P 17:00 - 19:00 2.00 PULL P Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1/2002 Description of Operations 15:30 - 17:30 2.00 FISH I P Cutter. Call SWS E-Line. Lay down Tools. Rig down S-Line Unit. SWS E-Line arrive on location. R/U Schlumberger E-line equip. M/U tubing punching tools. RIH & punch holes in tubing from 10818- 10820' Perf'ed 4 spf.Total 9 holes. POOH wI tools. DECOMP Change out tools. RIH wI string shot. Shoot from 10835-1084T. POOH wI tools. DECOMP P/U & put tension in tubing string wI 145K. Set slips for cutting operation. Hold PJSM for cutting operations. Change out tools & M/U chemical cutter. RIH. DECOMP RIH & cut tubing @ 10846'. (Gol sluck several times in lail pipe section. Worked free. ) POOH & LID cutting tools. Set back E-line equip. DECOMP PIU & work pipe to 170K. Tubing came free. Now have 130k weight. appears to be complele string weight to cut @ 10846'. Pull 1 it & LID same. RID Schlumberger E-line equip. DECOMP Lay down 4 1/2" Work String and Overshot. Continue to single down Production String. Total Joint count (Including 40 Jls from previous time Rig was on lhis Well) = 258 Jts, 20.10 Chemical Cut Stub, 6 GLMs and a SSSV. Chem cut was clean. Threads (Pins) on first 100 Jts laid down were in very bad to bad condition. Remainder of Stnng had fair to good lhreads. Tube bodies good on enUre slring. Recovered 8 ¡more SS Bands. Total Bands recovered 28 ea. DECOMP Pick-Up Overshot with Fish from Outside Cut. Break out and lay down same. Run 3 slands of 6 1/4" Drill collars from Derrick. Single down in Pipe Shed. RD Handling Equiprnenl and clear Floor. DECOMP Make-up BHA #5 as follows: 6" x 4 1/2" Shoe, 2 ea Wash Pipe Extentions, TC Sub, XO. 7" Casing Scraper. 3 ea Boot Baskets. Bit Sub, Bumper Jar, Oil Jar. and 9 ea 4 3/4" Drill Collars. DECOMP PIU 31/2" DP, 1 x 1& RIH. Tagged up & look weight @ TOL, 8629'. 1 DECOMP PIU kelly, pump & rotate down thru TOL from 8629 to 8635'. Appear to be pushing junk ahead of shoe. PIU 127K, 8/0 107K, Rol119K. Blow down & set back kelly. DECOMP Con't to pick up & RIH w/3 1/2" DP. Pushing junk ahead of shoe. DECOMP Con't to PIU DP & RIH. Tagged up @, 10823'. (23' above cut) 330jlS. + 14' of jt 331. DECOMP PIU kelly begin pumping & rotating down on junk. P/U 163K, SIO 125K, Rot 140K. Max Torq 6.5K. PP 700 psi, 4 BPM, 40 RPMs. Milled on junk & made 12' 10 10835'. Had no returns al first, then gol returns. Now getting gas to surface. DECOMP Circulate out gas & oil. PP 700 psi. 5 BPM. DECOMP Con't to mill on junk. No further progress. Now at 10,838'. Blow down & set back kelly. DECOMP POOH wI BHA #5. DECOMP Break down BHA #5. Recovered three pieces of mangled 4 1/2" Tbg jammed up inside of the Shoe, and Extentions. Tbg slabs carne from washing over lhe Collasped Joint. Total DECOMP DECOMP DECOMP DECOMP DECOMP 19:00 - 22:00 3.00 PULL P 22:00 - 00:00 2.00 ¡ PULL P I 6/19/2004 00:00 - 03:30 3.50 PULL P 03:30 - 04:00 ~ 0.50 PULL P 04:00 - 13:00 9.00 ¡PULL ,P 13:00 - 15:30 2.50 PULL P 17:30 - 23:00 5.50 FISH P 23:00 - 23:30 I 0.50 ¡ FISH P 23:30 - 00:00 0.50 FISH P 6/20/2004 00:00 - 01 :00 1.00 FISH P 01 :00 - 03:00 2.00 FISH P 03:00 - 05:00 2.00 FISH P 05:00 - 05:30 0.50 FISH P 05:30 - 09:30 I 4.00 FISH P 09:30 - 11 :30 2.00 ¡ FISH P i P"r'I.;,j 7" ¿: 2O:,,)J 1 ~5.29 pr...1 ¡ Page 6 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Ho u rs Task ¡Code NPT I 6/20/2004 09:30 - 11 :30 2.00 FISH P 11 :30 - 12:00 0.50 FISH P 12:00 - 13:00 1.00 FISH P 13:00 - 16:00 3.00 I FISH P 16:00 - 17:00 1.00 FISH P I 17:00 - 21:00 4.00 FISH P 21 :00 - 22:30 1.50 FISH P 22:30 - 00:00 1.50 FISH P 6/21/2004 00:00 - 00:30 0.50 FISH 00:30 - 02:30 2.00 FISH 02:30 - 03:30 ' 1.00 FISH 03:30 - 05:00 1.50 FISH 05:00 - 07:30 2.50 FISH 07:30 - 10:30 10:30 - 11 :30 3.00 FISH 1.00 FISH 11 :30 - 12:00 12:00 - 14:30 14:30 - 15:30 0.50 FISH 2.50 FISH 1.00 FISH 15:30 - 19:00 3.50 FISH 19:00 - 19:30 0.50 FISH 19:30 - 20:00 0.50 FISH 20:00 - 23:00 3.00 FISH 23:00 - 00:00 1.00 FISH 6/22/2004 00:00 - 06:00 6.00 FISH P 06:00 - 06:30 0.50 FISH P Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1/2002 Phase Description of Operations DECOMP length recovered = 9.50'. Clean Boot Baskets. Recovered 2 112 gals of metal fillings and pieces of SS Bands. DECOMP Clear and Clean Floor. DECOMP Make up BHA #6 as follows: 6 118" x 4 1/2" Shoe 3 ea WP Extentions. TC Sub with inside Dress Mill, XO. 3 ea Boot Baskets, Bit Sub. Bumper Jar. Oil Jar, 9 ea 4 3/4" Drill Collars. DECOMP RIH wI BHA #6. Tag up @ 10832'. (6' high from previous run). DECOMP PIU kelly & break circulation. Mill & wash down to 10838' rapidly. Con't to mill & made l' addillonally lo 10839'. Could nol made more hole. P/U 165K, SIO 125K, Rol142K. 5 BPM, PP 650-1100 Psi. 10-12K WOB, Torq 6-8.5K, 60-80 RPMs. Have at least 10K overpull when coming off bottom every time. Had 'max. of 40K overpull once. DECOMP POOH wI BHA #6. DECOMP LID BHA, inspect shoe & clean out bool baskets. Recovered approx. 1/2 cup of fine melal milling in baskets. Shoe had some wear on inside & on edges. DECOMP Clear & clean rig floor. M/U BHA # 7. DECOMP : Finish M/U BHA #7 & RIH. Clear floor. DECOMP RIH WI BHA on 3 1/2' DP to 6000'. DECOMP Cut & slip 84' of drilling line. Adjust brakes. DECOMP Con't to RIH wI BHA #7 & tag up @ 10838'. DECOMP P/U kelly, break circulation. No returns. Mill from 10838 to 10854' (this depth put shoe 8' below top of 4 112" Chern Cut Slump...however we should be able lo swallow 16' of stump wilh lhis BHA). P/U 169K, S/O 118K. Rol 142K. 4-8K WOB, 60 RPMs, PP 375-600 psi. 4 BPM. Torq 66K. Made no progress below 10,854'. DECOMP Discuss options with Anch Engs. POOH with BHA #7. DECOMP Clean out Junk Baskets...some metal fillings. Change BHA configuration. Add a In-Line Box Tap (5" x 4" catch) between WP Ext #1 and #2. DECOMP ,Service rig. DECOMP RIH wI BHA # 8 DECOMP Tag up @ 10841'. P/U kelly break circulalion & rotate slowly down over fish. Engauge box lap into fish. P/U wI maximum of 20K overpull. Continue to work Fishing Tools. Never got an other solid bit again. DECOMP POOH wI BHA # 8. DECOMP LID BHA # 8. Clean out junk baskels. LId Box Tap, No recovery. DECOMP M/U BHA #9. Milll dress off Assy. 6" x 4 1/2' Shoe, 3 - extensions wI Inside mill. TL = 331.21'. DECOMP TIH wI BHA # 9 on 31/2" DP. P/U kelly & tag @ 10838'. DECOMP Mill & dress from 10838 lo 10840'. P/U 164K, SIO 119K, Rot 137K. 60 RPMs, PP 350 psi, 2112 BPM, Torq 7-9K, 2-6 WOB. DECOMP Con'l to mill- dress from 10840 lo 10853.32'. P/U 164K, S/O 119K, Rot 137K, 2-6 K WOB, 60 RPMs, 2 1/2 BPM. PP 350 psi. Torq 7-9K. attempt to work down over stub wlo rotating. No good. Mill & dress additional ft of tbg to 10841 '. (bottom of shoe @ 10853') Work up & down & could nol get over stub wol rotating. DECOMP Discuss plan forward wilh Anch Eng. Service rig. Pr,nl",d '7 t. 2004 1 ~5:29 pr,1 ( Page 7 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 11 129/2002 1 2/1/2002 4ES Date From - To Hours Task Code 6/22/2004 06:30 - 10:00 3.50 FISH P 10:00 - 11 :00 1.00 FISH P 11 :00 - 14:00 3.00 FISH P 14:00 - 17:00 3.00 FISH P 17:00 - 20:30 3.50 FISH P 20:30 - 23:30 3.00 FISH P ,23:30 - 00:00 0.50 FISH P 6/23/2004 100:00 - 01 :30 1.50 FISH N 2.00 FISH N ,01 :30 - 03:30 03:30 - 06:00 2.50 FISH N 06:00 - 07:30 1.50 FISH N : 07:30 - 12:30 5.00 BOPSUP P I 12:30 - 15:00 2.50 FISH N 15:00 - 19:30 ' 4.50 FISH IN 19:30 - 00:00 4.50 FISH N 6/24.'2004 4.00 FISH 00:00 - 04:00 04:00 - 08:00 4.00 FISH N 08:00 - 09:00 1.00 EVAL P 09:00 - 09:30 0.50 EV AL P 09:30 - 10:30 1.00 EVAL P 10:30 - 13:30 3.00 EV AL P 13:30 - 17:30 4.00 EV AL P I Start: Rig Release: Rig Number: NPT ! Phase Spud Date: 7/25/1997 End: 12/1/2002 Description of Operations N POOH wI BHA #9. LID BHA #9. Clean out junk baskets. (empty) Clean & clear rig floor. Wait on Slickline unit. R/U Slickline unit. RIH wI 8.50" Gauge ring & junk basket. Tag top of liner @ 8629'. Had tight spots @ 4460'. 4522', 4610', 5400'. 5600', 6000'. Appeared to be pushing lunk ahead of Gr. POOH. LID GR & JB. DECOMP M/U 5.5" Lead Impression Block to 10850'. POOH & inspect same. Did not see tbg impression. Had some scarring on low side. LID same, DECOMP M/U 3.70" drift & RIH. ! DPRB DECOMP Con't to RIH wI 3.70" drift to 10870'. This 20' deeper lhen Slickline's top of tbg stub @ 10850'. POOH & LID same. DPRB I DECOMP RIH wI 3.75" Lead Impression Block slopped @ 10850'. POOH , & inspect same. Top of tbg easily distinguishable in 1 impression. LID same, DPRB DECOMP M/U 3.5" UBI Drift & RIH to 10866' This is 4' shallow to the ! 3.70" drift run. POOH & inspect boltom of drift. Discuss plan forward wI engineer. 'DPRB DECOMP PJSM. Rig down Schlumberger wireline. DECOMP PJSM. Pull wear bushing, sellest plug. Commence weekly BOPE test, test plug leaking, replace seals on same. Perform full BOPE test, witnessing of lest waived by AOGCC Rep I ¡ Chuck Sheve. No failures. Pull Test plug, set wear bushing. DPRB DECOMP PJSM. Break down & lay down wash pipe. Pick up 3.77" parabolic diamond speed mill on Wealherford 2 7/8" motor, (6) I its 2 7/8" PAC. bumper sub. oil jars. i9) 4 3/4" DCs. DPRB DECOMP RIH wI BHA # 10. Tag up on tbg stub @ 10841'. I DPRB DECOMP, P/U Kelly Set motor parameters. Wash & mill down lhru Tubing & tailpipe assy. P/U 173K. Slo 115K, 2-3K WOB, 550 RPMs, PP off bottom 450 psi, PP on bottom 750 Psi. Mill "XN" nipple @ 10924'. Millon junk @ 10938'. DPRB DECOMP Con't to mill, drill & wash from 10940 to 11026'. ( 11034' OKB) P/U 173K, SIO 115K. 2-3K WOB, 550 RPMs, PP off 450 Psi, PP on bottom 750 Psi. Mill junk @ 10951'. Collars were rough in 4 1/2" liner. Mostly appeared to be soft fill? Pumped 2 - 20 Bbls Hi-Vis sweeps. Losses averaged 40 Bbls per hr. Had partial returns thru out milling operation, DPRB DECOMP Set kelly & POOH wI BHA #10. DECOMP PJSM. Stand back collars, LID mill & motor. Mill gauged out @ 3.76". DECOMP PJSM. Clear I clean rig floor, service rig. DECOMP PJSM. P/U Halliburton 7" Champ Packer. DECOMP RIH wI Halliburton 7" Champ Packer on 3 1/2" DP. Set @ 10,785', (110 slands & 22' in on single). Up wt = 175K, Down wt = 105K. DECOMP PJSM. Fill hole. (40 bbls). Pressure test lines, OK. Close pipe rams & pressure up II A to 3500 psi. Started to flat line & began bleeding off. Pipe a little off center. Bleed pressure. open pipe rams, close annular preventor & test. Still bleeding off. No indica lion of communicaliopn to O/A. O/A = 0 psi. Bleed pressure, open annular preventor & check all equipment. DECOMP DECOMP DECOMP DECOMP DECOMP Pr,r,I""j 7 ê' 2()ûJ 1 JS 2'3 PM BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: From - To J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hour~ I Task Code NPT Phase 4.00 EVAL P Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1/2002 Date Description of Operations 6/25/2004 23:30 - 00:00 00:00 - 03:30 1 03:30 - 07:30 0.50 REMCM-P 3.50 REMCM-P 4.00 REMCM-P DECOMP Replace sending unit on remote pressure gauge. Repeat test. bled off 350 psi in 20 minutes, 550 psi in 35 minutes. Bleed off pressure, open annular preventor. pull up hole 25' to 10.760' & I retest @, 3500 psi, 30 minutes, held solid. DECOMP Bleed off pressure. Unset packer. RID test equip. DECOMP POOH wI champ packer. DECOMP Cut & slip 84' of drilling line. DECOMP Con't to POOH wI Champ packer. LID & inspect packer. Some rubber (chunks) missing from lower element on packer. DECOMP Clear floor. M/U RBP & selling lool. RIH wI same. DECOMP 'RIH wI RBP. Sel RBP @ 9195'. DECOMP Fill hole wI 40 Bbls. R/U lines & pressure tesl RBP. Holds for 5-7 minutes then bleeds off. Check all valves & isolate sensor straight off annulus. No test. Unsel RBP. P/U 20' & reset. I Release from bridge plug. Pressure test @I 1000 psi / 10 minutes, OK. DECOMP PJSM wI Schlumberger. Pressure test lines. OK. Spot sand on top of bridge plug. Mix & pump 550 Ibs sand I slurry & displace wI 59 bbls seawater. Blow down lines. RID Schlumberger. DECOMP PJSM. POOH wI RBP running tool & 3 1/2" DP. DECOMP PJSM. P/U 95/8" Halliburton bridge plug & RIH on (9) 43/4" drill collars & 3 1/2" DP. DECOMP PJSM. Set Halliburton retrievable bridge plug @ 2493' DPM. 6/24/2004 13:30 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 23:30 0.50 EV AL P 1.00 EVAL P 1.00 EVAL P 3.50 EVAL P 07:30 - 08:30 1.00 REMCM-P 08:30 - 11 :30 3.00, REMCM-P 11 :30 - 12:30 I 1.00 i REMCM-P 12:30 - 13:00 0.50 REMCMTP 13:00 - 14:00 1.00: REMCM-P 14:00 - 15:00 1.00 REMCM-P ! 15:00 - 17:00 2.00 REMCM-P 17:00 - 21 :00 4.00, REMCM-P 21 :00 - 23:00 2,00 REMCM-P 23:00 - 00:00 1.00 I REMCM-P 6/26/2004 00:00 - 02:00 2.00 REMCM-P 02:00 - 02:30 0.50 REMCM-P 02:30 - 03:00 0.50 I REMCM-P 03:00 - 06:00 3.00 REMCM-P DECOMP DECOMP 08:00 - 09:00 2.00 REMCMTP I 1.00 I REMCM-P DECOMP PJSM. POOH w/3 1/2" DP. DCs & LID running lool. PJSM. Pick up 7" lubricalor, close bag & drop 1100 Ibs of river sand down 9 5/8" annulus. PJSM. R/U Schlumberger E-Line to run USET log. RIH wI USIT. Tagged PBTD @ 2493' Log from 2492 to 1800' Top of Cement @ 2032', Completely free of cement trace above 2022'. POOH & LID US IT tools. Re-head line. RIH, correlate & Perf as follows: Interval 2010- 2015', 4 JSPF, Total 21 holes. POOH & LID Perf gun. All shots fired & had very good fire indication @ surface. , R/U lines & attempt to circulate oul Artie-Pac. pressured up to 800 psi, held solid. No good. discussed wI schlumberger & town engineer. Centralizer bow on perf gun was compressed, possibly not in contact wI casing wall. Install new centralizer on perf gun. RIH & Re-perf same interval. 2010- 2015', 4JSPF, Total 21 holes. POOH. All shots fired. good indication @ surface, Attempt to circulate. pressured up to 1000 psi, held steady. Annulus possibly frozen. RID Schlumberger. RIH w/3 1/2" DP & muleshoe lo 2020'. Displace 9 5/8' casing wI 150 degree seawater. Circulale 150 degree seawater down DP & up 9 5/8" casing in an attempl to thaw 9 5/8" x 133/8" annulus. At 0500 hrs, SI & pressure up to 1000 psi wI annulus open. lost 50 psi in 5 min, Con't to circulate & thaw annulus. Continue to circulate hol seawaler to lhaw 95/8" x 13 3/8" annulus. PJSM. Close pipe rarns & altempt to break circulation. Pressure up to 2000 psi, see approximately 1 gall min of DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 06:00 - 08:00 DECOMP P"r,r.:.,j' "7 ¿ '¿úù-l 1 ~5 29 P~.' Page 9 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date J-07 A J-07 A WORKOVER Start: NABORS ALASKA DRILLING I Rig Release: NABORS 4ES Rig Number: From - To I Hours Task Code I NPT I Phase 08:00 - 09:00 1.00 REMCM-P DECOMP 6/26/2004 6/27/2004 09:00 - 10:00 1.00 REMCM-P DECOMP 10:00 - 11 :00 1.00 REMCM-P I DECOMP 11 :00 - 11 :30 0.50 REMCM-P DECOMP 11 :30 - 12:30 1.00 REMCM-P DECOMP 12:30 - 14:00 1.50 REMCM-P DECOMP 14:00 - 14:30 0,50 I REMCM-P DECOMP I 14:30-16:00 1.50 REMCM1P DECOMP 16:00 - 16:30 0.50 REMCM-P DECOMP 16:30 - 17:30 1.00 REMCM..LP DECOMP 17:30 - 00:00 I 6.50, REMCM-P , DECOMP 00:00 - 06:00 6.00 REMCM-P DECOMP 06:00 - 07:30 07:30 - 08:30 08:30 - 10:00 ' 1.50 REMCM-P 1.00 REMCM-P 1.50 REMCM-P DECOMP DECOMP DECOMP 10:00 - 11 :30 : 1.50 REMCM-P DECOMP 11 :30 - 12:00 0.50 REMCM-P DECOMP 12:00 - 13:00 1.00 REMCM-P DECOMP 11/29/2002 12/1/2002 4ES Spud Date: 7/25/1997 End: 12/1/2002 Description of Operations returns up 13 3/8" x 9 5/8" annulus. Increase pressure to 2200 psi. Observe BOPE stack rise approximately 1'. Shut down & bleed off all pressure. No returns up 13 3/8" x 9 5/8" annulus. PJSM. Appears 9 5/8" rose 9 1/2" Slack off on 3 1/2" DP, open pipe rams, no downward movement of stack. Surmise 9 5/8" was set in compression & combination of thermal expansion & pressuring up to circulate caused 9 5/8" casing to raise up. PJSM. POOH wI 3 1/2" DP & DCs. PJSM. Test primary & secondary seals on 9 5/8" packoff @ 3500 psi. OK. PJSM, Rig up Schlumberger E-Llne. RIH wI (5') of 1.56" HSD 4 spf tubing punch & punch holes in 9 5/8" casing from 1965' - 1970'. POOH WI E-line. PJSM. Attempt to pump down 9 5/8" casing taking returns up 13 3/8" x 9 5/8" annulus. pressure up to 1500 psi, no relurns. PJSM. RIH wI Schlumberger 1.56" HSD. 4 spf & punch holes from 1889' - 1894'. POOH wI E-Line. Rig down Schlumberger E-Line. Attempt to break circulation as before, down 9 5/8" casing & up 9 5/8" x 133/8" annulus, pressure up to 1500 psi. no returns. PJSM. M/U mule shoe on --+ 3/4" drill collsrs & RIH w/3 1/2" DP to 2023'. Circulale down DP wI 135 degree seawaler. 5 BPM @ 500 psi. Every 2 hrs, SI annular preventenler & pressure up to 1500 psi & allempt to break circulation around 13 3/8" annunlus. At 2330 hrs started to see some drop off of pressure & fluid seep out annulus. Pressure up lo 1800 psi wI annular closed. pressure dropped off to 1400 psi & started to get intermttant returns. Hold pump pressure @ 1500 psi & returns increased. Con't to increase rate & started to get Artie-Pac returns, Pump out Artie-Pac. Has consitancy of wet cement. Con't to flush annulus to max rate of 6 BPM, 700 psi. Appear to have Artie-Pac circulated out. SID & wait 30 min For addilional softening. Resume pumping @ 6 BPM & flush annulus. Getting hot seawater back. Fluid returns are clean wI only occasional clump of Artic-Pac POOH wI DP & collars. PJSM. M/U 9 5/8" Halliburton Fasdrill cement retainer. RIH wI Halliburton cement retainer. 19 stds & 2 singles. 35K up wt, 35K down wt. Break circulation @ 4 bpm I 250 psi, circulate 20 bbls. Set relainer @ 1870'. Shear off in steps achieving 50K overpulllo 85K. Pt retainer lo 1000 psi. OK. Rig up Schlumberger I Dowell cementers wI vacuum truck & trash pump rigged up to cellar. Sting back into retainer & break circulation to verify. OK. PJSM wI Schlumberger. DIscuss overview of operation, fluid monitoring. communication, etc. Pump 5 bbls water ahead, pressure test lines to 4000 psi, OK, Pump 5 bbls water & 112 bbls ARCTICSET 1 D816 15.7 ppg cement. Monitor returns coming up 13 3/8" x 9 5/8" annulus. See cement relurns wI 85 bbls pumped away. Take sample from annulus returns w/1 00 bbls away lo send to lab. WI 112 Prlnt""j 7'6'?Oû~ 1 -15,,29 PI.' Page 10 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS4ES Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1/2002 6/27/2004 12:00 - 13:00 1.00 REMCM-P From - To Hours Task Code NPT Phase Description of Operations Date 13:00 - 14:00 1.00 REMCMIP 2.00 REMCMIP 1.00 REMCM-P 7.00 REMCM-P 6.00 REMCM-P 14:00 - 16:00 6/28/2004 16:00 - 17:00 17:00 - 00:00 00:00 - 06:00 06:00 - 07:30 07:30 - 08:00 1.50 REMCM-P 0.50 REMCM-P 6.00 REMCMfp I 08:00 - 14:00 14:00 - 18:00 I 4.00 WHSUR N 18:00 - 21 :30 3.50' WHSUR N 21 :30 - 00:00 2.50 WHSUR N 6/29/2004 00:00 - 06:00 6.00 WHSUR N 06:00 - 08:00 2.00 WHSUR N 08:00 - 08:30 0.50 WHSUR N 08:30 - 09:00 0.50 WHSUR N 09:00 - 11 :00 2,00 WHSUR N 11 :00 - 16:00 5.00 BOPSUF N 16:00 - 20:00 4.00 BOPSUP P 20:00 - 21 :00 1.00 WHSUR P 21 :00 - 23:00 2.00 CLEAN P 23:00 - 00:00 1,00 CLEAN P 6/30/2004 00:00 - 06:00 6.00 CLEAN P 06:00 - 12:00 6.00 CLEAN P DECOMP away follow wI 10 bbls water & unsting from retainer. letting remaining 2-3 bbls fall out of DP. CIP @ 13:00 hrs. DECOMP PJSM. Reverse circulate (1) DP volume. hook up cool seawater truck & reverse circulate to clean 78 degree returns. DECOMP PJSM. Flush lines, clean & flush cement I Arctic Pac out of cellar. DECOMP PJSM. POOH w/3 1/2" DP & running tool & UD same. DECOMP WOC. Service rig. Paint & clean rig. DECOMP ,Con't to wait on cement. Checked wI Schlumberger lab after 12 I hrs, t0100 hrs) compressive strength on submllted sample only 450 psi. Waited 3 hrs. t 0400 hrsl Compressive strength now 500 psi. Lab lech says should be increasing 50 pSl/hr now thal "G" cemenl portion is starting to cure. DECOMP WOC. UCA @ 07:20 AM = 850 psi & climbing steadily. DECOMP PJSM. Ensure hole is full, close blind rams, line up on kill line & pressure up 9 5/8" annulus to 1500 psi 115 minule lest, flat line, charted. Bleed pressure. DECOMP PJSM. Commence nippling down. Appears 9 5/8" dropped, (shrank back down), approximately 5". Remove binders holding stack I 9 5/8" casing centered in 13 3/8" & 9 5/8" now up against 13 3/8" casing wall. Continue nippling down. removing annular preventor so as to replace wllh Hydril GK. NID rams & flow cross. SFAL DECOMP PJSM. Bleed off hanger void. Remove tubing hanger. Remove ! 13 3/8" casing brace. Cut off & remove casing head. SFAL DECOMP Make final cut & dress casing slub, Preheal & weld on starting head. SFAL DECOMP Wrap & inslall heal blanket around starting head. Allow to slowly quench & cool. Clean, paint & work on rig equip. SFAL DECOMP Allow starting head to quench & cool. Paint. clean & service rig equip. Continue to allow wellhead to cool. PJSM. Test weld on starter head @ 1500 psi wI nitrogen for 15 minutes. held solid. Continue lo allow starter head to cool sufficiently to nipple up Install wellhead tubing spool. Test seal to 1500 psi; test ,metal-to-metal seal to 1000 psi; both successful. N/U BOPE. Install flow nipple. Inslalllest plug and run-in 2 LDS. Test BOPE to 250/3500 psi. RID test equipment. UD test joint. P/U running tool, pull lest plug. Set Wear Ring. P/U and M/U 8-1/2" mill tooth bit and 9 DCs; RIH wI 16 slands 3-1/2" DP + 1 jt. Tag lop of cement @ 1845' RKB and drill through lo Fasdrill retainer. Parameters: P/U, 8/0 wt = 52K; WOB 5-10K; 80 RPM: 5 BPM; 300-350 psi. P/U 2nd single of 3-1/2" DP and continue to drill out Fasdrill retainer to 1950'. Penelration rales from 10 min/ft to 5 minlft. ROPs increasing once below the perfs. Mill/wash down to lop of sand on RBP. Virtually no cement to speak of over lhe last -150' down lo lhe sand. Verify sand returns by reversing up one drill pipe volume and confirming SFAL DECOMP SFAL DECOMP 8FAL DECOMP SFAL DECOMP SFAL DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Prlr,tëO:;L -: e 2ÜÜ"'¡ , -t5"29 pr',,1 ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/30/2004 7/112004 J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 06:00 - 12:00 6.00 CLEAN P , DECOMP 12:00 - 1~:OO I 2.00 CLEAN P DECOMP 14:00 - 15:30 1.50 CLEAN P DECOMP 15:30 - 17:00 1.50 CLEAN P DECOMP 17:00 - 17:30 0.50 CLEAN P DECOMP 17:30 - 19:30 2.00 CLEAN P DECOMP 19:30 - 20:30 1.00 CLEAN P DECOMP 20:30 - 22:30 2.00 CLEAN P DECOMP 22:30 - 23:00 0.50 CLEAN P DECOMP 23:00 - 00.00 1.00 CLEAN P , DECOMP 00:00 - 01 :30 1.50 CLEAN P DECOMP 01 :30 - 03:30 2.00 CLEAN P DECOMP 03:30 - 06:00 2.50 CLEAN P DECOMP 06:00 - 07:00 1.00 BOPSUP N WAIT TIEB1 07:00 - 09:00 2.00 BOPSUF P TIEB1 09:00 - 12:30 ' 3.50 CASE P TIEB1 12:30 - 00:00 I 11.50 CASE P TIEB1 7/2/2004 00:00 - 04:30 ' 4.50 CASE P TIEB1 04:30 - 06:00 1.50 CASE P TIEB1 06:00 - 09:30 3,50 CEMT P TIEB1 Page 11 of 13 Start: 11/29/2002 Rig Release: 12/1/2002 Rig Number: 4ES Spud Date: 7/25/1997 End: 12/1 12002 Description of Operations sand over the shaker. Wash down to top of RBP. CBU at 5 bpm, 300 psi. POH w/BHA #11. Stand back drill collars. Break-out bit. Clean and clear floor. RIH with 9-5/8" RBP pulling tool. 9 6-1/4" DCs on 3.5" drill pipe. Pressure test casing to 1000 pSI and record for 20 minutes. No annular communication. Continue RIH and work down to RBP and latch up and work DP to release RBP. Circulate bottoms up, and prepare lo POH wI DP, DCs. pulling tool and RBP. POH RBP on pulling lool WI 6-1/-1-" DCs and 3-1/2" DP. LID DC and SIB D. B/O and LID pulling tool and RBP. Clear and clean rig floor. M/U BHA #12: 7" liner tie-back polishing mill on 3-112" DP and RIH to TOL @ 8629'. RI H BHA #12, 7" liner lie-back polishing mill on 3-1/2" DP to TOL at 8629'. Tag TOL @ 8624' DPM: dress lop of ì" liner wI 7" polishing mill. Ran mill into tie-back receplacle 8-10 limes lo dress off. Reverse CBU for 60 Bbls. Prepare lo POH. POH & SIB DP, B/O 7" polish mill. Wear pattern on polish mill confirms that tie-back receptacle has been dressed and is in good shape. Wait on delivery of 7" pipe rams from Nabors yard In Deadhorse. Change oul VBRs to ì" pipe rams. Pressure lesl 7" rams 250/3500 psi. Prepare 7" handling equipment. Clear floor. PJSM on running 7" liner. RIH witt, 7",26#, L-80 tie-back liner as follows: - tie-back ported stem (6.74') - pup joint 7",26#. L-BO BTC-M (26.53') - 1 joint 7".26#, L-80. BTC-M t41.35') - HES float collar w/0.375" hole drilled to.95') - 1 joint 7", 26#. L-80. BTC-M (41.47') - 153 joints 7" 26#, L-BO, BTC-M (6370.19') -7",26#, L-80 cross-over joint BTC-M pin x NSCC box (40.91') - 53 joints 7",26#, L-BO NSCC (2118.30') - Cross-over pup 7" NSCC pin x 7" BTC box (2.16') Continue RIH wI 7" lie-back liner and spaceout for cementing operations. P/U wt 201 K; SIO wt 155K I R/U Dowell, diesel truck, Vac Trucks. and install cementing head on 7" casing. PJSM on upcoming cemenling ops. Fill cementing line w/fresh wtr and PT lo 4200 psi (OK). Flush wtr lo pits w/diesel until clean diesel returns at pits. Open up cementing manifold and pump 100 bbls diesel down 7" liner at 5.5 bpm, 350 psi. Drop bottom plug and follow w/186 bbls 15.8 ppg cl "G" cement. Drop 2nd plug and displace w/1 0 bbls wtr. Swap to rig pump and continue displacement w/sea-wtr at 6 bpm. Slow rate as cement turns corner and builds head on backside. Down to 1 bpm, 2300 psi when plug should'Ve hit. Did not see plug bump P"nlE-d' ,'e '::(104 , .\5.29 pr'.1 BP EXPLORATION Operations Summary Report Page 12 of 13 Legal Well Name: J-07 A Common Well Name: J-07 A Spud Date: 7/25/1997 Event Name: WORKOVER Start: 11/29/2002 End: 12/1/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/1/2002 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT I Phase Description of Operations 7/2/2004 06:00 - 09:30 3.50 CEMT P TIEB1 after pumping 1/2 of the shoetrack. SD pump. CIP @ 9:30 am. 09:30 - 11 :00 1.50 CEMT P TIEB1 Immediately slack off on liner and sting rest of seal stem Into I receptacle wIno problems down to no-go ring. Bled pressure while stinging in. Stack 10K compression. Check for flow up 11 :00 - 14:30 I 7" --> none. RD cemenling equip. P/U to 140K and set brake. 3.50 CEMT P ¡TIEB1 Swap 7" pipe rams for VBRs. Split stack below tbg spool to expose 7" liner. Prep liner and set slips w/180K tension. NOTE: While seillng slips. noticed 9-5/8" casing sliding down hole. Measured 1.625" over lasl 70K. 7" never moved. slips are sel. 13-3/8" never moved. Consult w/Engineering. Proceed with 7" casing cutting opera lions. 14:30 - 16:00 1,50 CEMT P TIEB1 RU Wach's casing cutter. Cut 7" casing. Actual operating lime of cutter = 8 minutes. RD Wach's cutter and prep 7" stub for pack-off. NOTE: Cut joinl of 7" 26# L-80 NSCC strapped at TIEB1 32.40' leaving 8.43' in well. 116:00 - 17:30 1.50 CEMT P Inslall 7" Pack-off. NU stack. Tesl pack-off to 3500 psi. 17:30 - 21:00 3.50 CEMT P 'TIEB1 Pressure test BOPE, lines. Load pipe shed wI 9,4-3/4" DCs. : 21 :00 - 00:00 3.00 CEMT P TIEB1 P/U 6-1/8" bit. 9 x 4-3/4" DCs and RIH to +1- 8580' to drill out [p cemenl, floats, and float collars and continue clean out to top of 7" RBP @ 9200', 7/3/2004 00:00 - 00:30 0.50 CEMT TIEB1 Tagged lop of cement @ 8328' = 84 stds + 1 single + 14' of 3-1/2" DP. 00:30 - 02:00 1.50 CEMT P TIEB1 Line up manifold lo pressure test 7" casing to 3500 psi and chart for 30 minutes. Successful test. 02:00 - 05:00 3.00 CEMT P TIEB1 Drill out cemenl from 8328' lo 8412'. 105:00 - 15:30 Paramelers: P/U wt 135K, S/O wt 93K, Rol wt 11 OK. 2-5K on bil, 3-6 BPM, 450-650 psi. 10.50 CEMT P TIEB1 Continue drilling hard cement at 5 bpm. 1000 psi. Drill-out float collar. RIH washinglrotating with bit lo -8900' dpm (ROPs increasing once below seal stem). Single in drill pipe and dry lag fill @ 9090' dpm. PU kelly and lry washing down w/o rotating...no-go. Rotate thru crust and wash down last jt w/o rotation easily to 9179' dpm and tag solid. No wash-off - appears lo be RBP, Pick up to 9170'. 15:30 . 16:30 1.00 CEMT P TIEB1 CBU at 6 bpm. 1600 psi with bit parked al9170' dpm, Check for sand in returns on bottoms-up. No sand confirmed - hard to see even on shaker. 16:30 - 21 :00 4.50 CEMT P TIEB1 POH w/BHA #13. 21 :00 - 23:30 2.50 CEMT P TIEB1 P/U HES RBP pulling tool and RIH; tag fill @ 9164'. 23:30 - 00:00 0.50 CEMT P TIEB1 R/U to rev circ fill off top of RBP. and begin circ at 4-5 BPM @ 900-1200 psi. 7/4/2004 00:00 - 02:00 2.00 CEMT P TIEB1 Rev circ until relurns across shaker cleanup. Hookup to vac trucks and swap well bore fluids wilh clean seawater. 02:00 - 02:30 0.50 CEMT P TIEB1 Parameters: P/U wt 147K, S/O wt 87K Work DP and RBP running lool and latch into RBP and pull free wI 5K. Well fluid level dropped--well on vacuum. 02:30 - 04:30 2.00 CEMT P TIEB1 Cut and slip drilling line and prepare equipment for 3-1/2" DP laydown, 04:30 - 11 :30 7.00 CEMT P TIEB1 POH and LID DP; using double displacement wI clean seawater. 11 :30 - 12:00 0.50 CEMT P TIEB1 At surface w/RBP. Break-oul and LD same. 12:00 - 13:00 1.00 CEMT P TIEB1 RIH with 13 stands of drill pipe left in derrick and LD In singles. pnnre-ct ~ t.'2'jO"¡ 1"¡5';:';¡ pr., f Page 13 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/4/2004 7/5/2004 J-07 A J-07 A WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I_Hours Task Code Start: Rig Release: Rig Number: NPT I Phase 13:00 - 00:00 11.00 RUNCOW RUNCMP 00:00 - 06:00 6.00 RUNCOMP RUNCMP 06:00 - 08:30 2.50 RUNCOMP RUNCMP 08:30 - 09:30 1.00; RUNCOMP RUNCMP 09:30 - 11 :00 1.501 RUNCOIvP RUNCMP 11 :00 - 13:00 2.00 RUNCOMP RUNCMP 13:00 - 15:00 2.00 RUNCOMP RUNCMP 15:00 - 18:30 3.50 RUNCOMP RUNCMP 18:30 - 21 :00 , 2.50! RUNCO~P RUNCMP 21 :00 - 21 :30 0.50 DHB P POST 21 :30 - 22:00 0.50 RIGD P POST 11/29/2002 12/1/2002 4ES Spud Date: 7/25/1997 End: 12/1/2002 Description of Operations Prep floor for completion handling equip. Pull wear ring. RU 4-1/2" tongs and Torque Turn equip. RIH with 4.5",12.6#, 13Cr-80 VamTop completion. Baker-Lock all connections below packer. Torque connections below packer to 4800 ft-Ibs. connections above packer to 4440 ft-Ibs. Conlinue RIH wI 4-112" completion to place WLEG @ 10,ì40' and S-3 packer at 10652'. Line up to pump inhibiled seawater down the backside. Limit rate to 3 bpm. Able to reverse after 24 bbls pumped, Pump 100 bbls seawater w/o inhibitor followed by 200 bbls seawater wilh corr inhib. Rale = 3 bpm, 200 psi. Seawater temp = 140 deg F. Land tbg hanger. RILDS. Close annular and PT above hanger to 2000 psi (OK). LD landing jt. Drop 1-5/8" ball & rod. Install integral flange on IA. PT integral. Leaking. Swap oul 2x and get a test to 3500 psi. Pressure up on tubing lo 3650 psi to set packer. Chart tbg press f/30-min. Observe open annulus --> no flow. Good test. Bleed lbg down to 1500 psi. Pressure up on IA lo 3500 psi. Chart f/30-min. Good test. Bleed tbg press down and see DCK valve shear. Confirm clrculalion both ways for 10-bbl each @ 2 bpm, 500 psi. No problems. FMC set TWC. PT from below -> no lest. Pull TWC and re-dress. PT to 1000 psi from below - OK. ND BOPE. NU FMC adapler flange. NU lree. PT lbg hanger pack-off lo 5000 psi. PT tree/adapler to 5000 psi. RU LRS Hot Oil. Pump 90 bbls diesel down lhe IA. RU jumper to lbg and allow diesel to U-tube. P/U lubricator and install BPV. Pressure lest to 1000 psi. Bleed down and break out lines. Clean pits; secure cellar. Released rig at 2200 hours. Pr,nltë,j "7 € 2')')..1 1 -IS.29 pr., I. ~ z ~~ ,~ r TREE = WB..LHEAD = A CflJA. TOR = KB. ELEV = BF. ELEV = KOP= Max Ange = Datum MD = Datum TVD = CAMffiON Ff\C GEN V OT6 75.8' 40.16' 2800' 96 @ 11652" 10783' 8800' 55 I TOPOF SCAB LNR H 1500' I 7'LNR.26#,L-80..0383bpf,ID=6.276" H 2118' 13-3/8" CSG. 72#. N-80,ID = 12 347' H 2670' ~ l BOTTOM OF SCAB LNR I- I TOP OF 7" TIEBACK SLV, 10 = 6.250" - I 9-518"X7"BKRZXPA<RID=6.312" 1--1 I 9-5/8" X T' BKR HMC LNR HGR ID = 6.187' - I 9-5/8" CSG. 47#, N-8Q, D = 8.681" - 8628' 8629' 8637' 8642' 8745' Minimum ID = 3.725" @ 10932' 4-1/2" HES XN NIPPLE I 4-1/2" TBG, 12.6#, 13-CR, .0152 bpF, ID = 3.958" 1--1 10739' ~ I TOPOF4-1/2"TIEBAO< SLV, ID= 5.250" 1--1 I 4-1/2" TBG,12.6#, L-80, .0152bpF, 10= 3.958" 1--1 I 7" X 4.-1/2" BKR HrvlC LNR HGR 10 = 4.375" 1--1 PERF ORA 1l0N SUMMA RY REF LOG' DPC PffiF ANGLE AT TOP PffiF: 96 @ 11630' Note: Refer to Production DB for historical perf data SIZE SPF INTffiVAL Opn/Sqz DATE 2-3/4" 4 11630 - 11750 0 06/10/96 2-3/4" 4 11810- 11950 0 06/10/96 2-3/4" .. . 12140- 12180 0 06/10/96 10937' 10943' 10949' J-07 A z ~ ~x <x O{ (X )() < y x y . . SAFETY NOTES: WELL> 70° @ 10950' & GOES HORIZONTAL @ 11108'. PRE-5DTRK WELLBORE NOT SHOWN ON DIAGRAM BROW 9-5/8" CSG MILLOUT WINDOW. 13-3/S" CSG CRACKED BELOW BRADENHEADW RD APPROX. 30" LONG:**4-1J2" CHROMETBG""" 2193' H.!-1/2"HES XNIP,ID= 3813" I ~ GA S LIFT t\,IANDRELS TVD DEV VLV 1YPE LATCH 5.!7.! 45 KBG-2 00 ME BK 6826 48 KBG-2 SO BK 7863 29 KBG-2 DMY BK 8.. .66 30 KBG-2 Dr\i1Y BK 8781 56 KBG-2 DMY BK PORT DATE 16 07115/().¡ 20 1)7/15/1).. . (I 07l05/0... . 0 07/05/üJ, 0 07105/1).. . l - z 5T MD 5 6092 .. . 8091 3 9.!62 2 10158 1 10563 MILLOUT WINDOW - 87.. .5' - 8795' ~ WI 9-5/8" SECTION rvuLL 10631' 1-+~-1/2" HES X NIP, ID= 3.813" I 10652' 1-i7" x 4-1/2" BKR 5-3 A<R ID= 3.875" I 10718' 1-14-1/2" HES X NIP, ID= 3.813" I 10740' 1--14.-112" rv1ULESI-OEWLEG, ID= 3958" I 1 0841' - CHEM CUT I 10878' - 4-1/2" HES X NIP, 10 = 3.813" I 10889' H7" X 4.-1/2" BKR S-3 PKR. 10 =? 875" I 1 0912' 1-14-1/2" HES X NIP, 10 = 3.813" 10932' 1-14-1/2" HES XN NIP, D = 3.725" I 1 0945' 1-+~-1/2" WLEG, ID = 3.958" I I-iT' X.t-1/2"BKRZXPPKR ID=.. ..375" I I FelD l-i 12194' I 7" LNR 26#, L-80, 0383 t,pf, ID = 6,276" 1--1 11069' I DA TE REV BY COMMENTS 10/04177 ORIGINAL COMPLETION 06/11/96 SBR SIŒTRACK (J-07 A) 12/02/02 DDNIKK RWO SUSPENDED 07/06/04 DCRlKAK'RWO 07/15/04 GJB/KAK GLV 00 DATE REV BY .!-1/2" LNR. 126#, L-80, .0152bpf.ID= 3953" 1-1 12235' I Corv1tv1ENTS PRUOI-OE BA Y urJIT WELL: J-07A Pffil'v11T f\b: 1960870 API 1\10' 5ü-029-20241-û 1 SEe 9, Tl1 N, R13E. 8.t8' FNL & 8e¡.. .' ÆL BP Exploration (Alaska) ON OR BEFORE W c:LO~LM-DOc PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 06/09/98 RUN RECVD 96-087 96-087 GR/EWR4 - TVD GR/EWR4 - MD ~8440-8944 2-8 09/16/96 2-8 09/16/96 96-087 GR/CN - MD ~z~0129-12235 2-8 09/16/96 96-087 GR/CN- TVD 96-087 7462 ~L"~844 O- 8944 ~~P E RRY RES/GR/CNP 2-8 09/16/96 2-3 09/20/96 10-407 ~COMPLETION DATE 6 / I / / q~/ DAILY WELL OPS /R _%--/2)/~,6 / TO 6//,L/q~/ Are dry ditch samples required? yes ~And received? Was the well cored? yes _~An- alysis & description received? Are well tests required? ,yes ~_~.Received? Well is in compliance ..~ Initial COMMENTS T WELL LOG TRANSMITYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Hoxvard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 M~VD Formation Evaluation Logs - J-07A AK-MM-960528 September 20, 1996 "The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 0 I=! I I_1_ I I~ G S ~:: FI~'I C E S WELL LOG TRANSMITTAL To: State of Alaska Alaska 0il and Gas Conservation Comm. Attn.' Howard 0kland 3001 Porcupine Drive Anchorage, Alaska 99501 ~ _ (_~ ,_/, MWD Formation Evaluation Logs J-07A, AK-MM-960528 September 15, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20241-01 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-20241-01 2" x 5"MD Neutron and Gamma Ray Logs: 50-029-20241-01 2" x 5" TVD Neutron and Gamma Ray Logs: 50-029-20241-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia R CEIVED SEP 1 ~ Oil & Gas Cons. Comm~ion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Comaanv STATE OF ALASKA " - ALASK~ OIL AND GAS CONSERVATION CL,,~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-87 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20241-01 At top of productive interval 137' NSL, 1151' WEL, SEC. 33, T12N, ELBE} ~- -'~------ ....... ' ....................... -*..'-'-'~' ..... '~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 75.80'I ADL 028278 12. Date Spudded 113. Date T.D. ,eached I 14. Date Comp., Sump., or ^~and.115. Water depth, if offshore 116. No. of Comp,etions 05/28/96 06/07/96 06/11/96 N/A MSI_I One 17. Total Depth (MD+'I-VD)I 18. Plug Back Depth {MD+'I'VD)I19. Directional Surveyl20. Depth whore SSSV set~l. Thickness el Permafrosl 12235 8944 F-q 12194 8944 F'r] []Yes •No I 2188' UD/ 1900' (Approx.) 22. Typo Electric or Other Logs Run MW•, kW•, GR, RES, NELl, •IR, CNL, 4-Phase RES '~3. CASING, LINER AND CEMENTING RECORD CASING SE'FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'R'OM SIZE CEMENTING RECORD AMOUNT PULLED "'20" x 30" Insulated Conductor Surface 110' 36" 213 cu ft 13-3/8" 72# N-80 Surface 2670' 17-1/2" 4140 cuff 9-5/8" 47# N-80 Surface 8745' 12-1/4" 1910 cuft 7" 26# L-80 8637' 11069' 8-1/2" 506 cuft Class 'G' 4-1/2" I 12.6# L-80 10945' 12235' 6" 196 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diamter, 4 spf 4-1/2", L-80 10945' 10889' MD TVD MD TVD 11630' - 11750' 11810' - 11950' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12140'- 12180' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 120 Bbls Diesel ...... 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 28, 1996 F owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. OEIGIhIALRECEIVED JUL 1 2 1996 Alaska 011 & ~a~ Cone. C0mmit~io~ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark~.:. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 10270' 8563' Shublik 10314' 8601' Top of Sadlerochit 10416' 8683' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~an Sto~ / ~ / ~/~/'~v Title Senior Drilling Engineer r~:t Prepared By Name/Number Te -4628 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED JUL 1 ~ 199~ Form 10-407 Rev. 07-01-80 0il & (~,'.~; Cons. Commission SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WelIName: J-07A Rig Name: Nabors 28E AFE: 4P0813 Accept Date: 05/23/96 Spud Date: 05/28/96 Release Date: 06/1 1/96 May 23 1996 (1) Rigged down Drillfloor / Derrick. Rig waited: Service personnel. Rig moved 100 %. May 24 1996 (2) Rigged up Drillfloor / Derrick. Rigged up Circulating head. Retrieved Hanger plug. Held safety meeting. Circulated at 9412 ft. Circulated at 9412 ft. Installed Hanger plug. Pulled Adapter spool. Rigged up All functions. Rigged down Top ram. Rigged up Top ram. Rigged up Bell nipple. Serviced BOP stack. May 25 1996 (3) Retrieved Hanger plug. Rigged up Tubing handling equipment. Retrieved Tubing hanger. Laid down 9412 ft of Tubing. Serviced Drillfloor / Derrick. Serviced Top ram. Worked on BOP - All functions. Installed Bore protector. Held safety meeting. Made up BHA no. 1 . Singled in drill pipe to 2800 ft. May 26 1996 (4) Singled in drill pipe to 9050 ft. Functioned downhole tools at 9050 ft. Circulated at 9050 ft. Laid down 1050 ft of 5 in OD drill pipe. Pulled out of hole to 30 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 2698 ft. Set Bridge plug at 37 ft with 0 psi. Rigged down All functions. Removed Casing spool. Installed Casing spool. Tested Slip %s seal assembly. Rigged up BOP stack. Tested Wellhead connector. Installed Bore protector. Retrieved Drillpipe landing string. R.I.H. to 4000 ft. May 27 1996 (5) R.I.H. to 8745 ft. Tested Casing - Via annulus and string. Milled Casing at 8745 ft. Circulated at 8795 ft. Pulled out of hole to 210 ft. Pulled BHA. Serviced Flowline. R.I.H. to 6500 ft. Operations Summary for: ,~ ../A May 28 1996 (6) R.I.H. to 8785 ft. Worked toolstring at 8790 ft. Pumped spacers - volume 20 bbl. Mixed and pumped slurry - 30 bbl. Backreamed to 7690 ft. Held 1500 psi pressure on 1 bbl squeezed cement. Pulled out of hole to 30 ft. Laid down 1085 ft of 5 in OD drill pipe. Retrieved Bore protector. Tested BOP stack. Made up BHA no. 4. R.I.H. to 6500 ft. Serviced Block line. R.I.H. to 8573 ft. Drilled cement to 8750 ft. Drilled to 8770 ft. May 29 1996 (7) Drilled to 8793 ft. Drilled to 9710 ft. May 30 1996 (8) Drilled to 10129 ft. Circulated at 10129 ft. Pulled out of hole to 850 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 10069 ft. Reamed to 10129 ft. Drilled to 10300 ft. May 31 1996 (9 ) Drilled to 10323 ft. Circulated at 10323 ft. Pulled out of hole to 835 ft. Pulled BHA. Made up BHA no. 6. R.I.H. to 10143 ft. Reamed to 10323 ft. Drilled to 10662 ft. Jun I 1996 (10) Drilled to 10676 ft. Circulated at 10676 ft. Pulled out of hole to 835 ft. Pulled BHA. Retrieved Wear bushing. Made up BHA no. 7. R.I.H. to 8700 ft. Serviced Block line. R.I.H. to 10520 ft. Reamed to 10676 ft. Drilled to 10847 ft. Jun 2 1996 (11) Drilled to 10930 ft. Circulated at 10930 ft. Pulled out of hole to 10708 ft. Reamed to 10930 ft. Circulated at 10930 ft. Pulled out of hole to 834 ft. Pulled BHA. Made up BHA no. 8 . R.I.H. to 10681 ft. Washed to 10930 ft. Drilled to 11010 ft. Jun 3 1996 (12) Drilled to 11043 ft. Circulated at 11043 ft. Pulled out of hole to 8700 ft. R.I.H. to 11043 ft. Drilled to 11069 ft. Circulated at 11069 ft. Pulled out of hole to 834 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 2441 ft (7 in OD). Ran Casing on landing string to 10800 ft. Page 2 Operations Summary for: ,~- ../'A Jun 4 1996 (13) Ran Casing on landing string to 11069 ft. Circulated at 11069 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry- 90 bbl. Displaced slurry - 238.5 bbl. Reverse circulated at 8632 ft. Pulled Drillpipe in stands to 0 ft. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 9 . Singled in drill pipe to 3730 ft. Circulated at 3730 ft. Serviced Block line. R.I.H. to 10872 ft. Drilled to 10989 ft. Circulated at 10989 ft. Tested_ Casing - Via annulus and string. Jun 5 1996 (14) Drilled installed equipment - Landing collar. Circulated at 11079 ft. Drilled to 11480 ff. Jun 6 1996 (15) Drilled to meeting. 11420 ft. 11522 ft. Circulated at 11522 ft. Pulled out of hole to 8000 ft. Held safety Pulled out of hole to 180 ft. Pulled BHA. Made up BHA no. 10. R.I.H. to Reamed to 11522 ft. Drilled to 11713 ft. Jun 7 1996 (16) Drilled to 11984 ft. Pulled out of hole to 180 ft. Pulled BHA. Made up BHA no. 11. R.I.H. to 11870 ft. Reamed to 11984 ft. Jun 8 1996 (17) Drilled to 12235 ft. Circulated at 12235 ft. Pulled out of hole to 11000 ft. R.I.H. to 12235 ft. Circulated at 12235 ft. Pulled out of hole to 180 ft. Pulled BHA. Rigged up Casing handling equipment. Held. safety meeting. Ran Casing to 1310 ft (4.5 in OD). Circulated at 1310 ft. Jun 9 1996 (18) Ran Casing on landing string to 11030 ft. Circulated at 11030 ft. Ran Casing on landing string to 12235 ft. Circulated at 12235 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 35 bbl. Displaced slurry - 181 bbl. Reverse circulated at 10936 ft. Reverse circulated at 10936 ft. Pulled Drillpipe in stands to 0 ft. Made up BHA no. 12. R.I.H. to 10936 ft. Serviced Block line. R.I.H. to 12084 ft. Drilled cement to 12194 ft. Jun 10 1996 (19) Circulated at 12194 ft. Tested Casing - Via annulus and string. Pulled out of hole to 0 ft. Held safety meeting. Rigged up sub-surface equipment - Gun assembly. Ran Drillpipe in stands to 12194 ft. Held safety meeting. Perforated from 11630 ft to 12180 ft. Reverse circulated at 10810 ft. Rigged down High pressure lines. Laid down 8000 ft of Drillpipe. Page Operations Summary for: ,, _,/A Jun 11 1996 (20) Laid down 3615 ft of Drillpipe. Rigged down sub-surface equipment - Gun assembly. Retrieved Wear bushing. Rigged up Tubing handling equipment. Held safety meeting. Ran Tubing to 10944 ft (4.5 in OD). Reverse circulated at 10944 ft. Set packer at 10888 ft with 4000 psi. Retrieved Tubing landing string. Jun 12 1996 (21) Rigged down BOP stack. Installed Xmas tree. Retrieved BOP test plug assembly. Freeze protect well - 120 bbl of Diesel. Installed BOP test plug assembly. RECEIVED JUl.. 1 2 1996 0ti & 12~ Con~. Commission Anchora0o Page 4 SRE, RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING PBU/J-07A 500292024101 DATE OF SURVEY: 060796 MWD SURVEY JOB NUMBER: AK-MW-60065 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/24/96 KELLY BUSHING ELEV. = 75.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DIRECTION DEGREES DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8707.40 7236.14 7160.34 48 17 8750.00 7264.28 7188.48 49 1 8778.13 7283.35 7207.55 45 35 8808.26 7304.87 7229.07 43 12 8840.29 7328.71 7252.91 40 35 N 4.54 E .00 N 5.00 E 1.87 N 4.33 E 12.28 N 3.54 E 8.17 N 2.61 E 8.35 3656.81N 101.73W 3656.94 3688.68N 99.07W 3688.62 3709.29N 97.39W 3709.11 3730.31N 95.94W 3730.02 3751.67N 94.78W 3751.29 8871.85 7353.18 7277.38 37 42 8903.97 7379.07 7303.27 34 54 8937.15 7406.70 7330.90 32 17 8968.90 7433.68 7357.88 31 17 9000.87 7461.03 7385.23 31 6 N 1.59 E 9.41 N .40 E 8.99 N .40 W 7.95 N .50 E 3.49 N 1.00 E 1.02 3771.58N 94.05W 3771.13 3790.59N 93.71W 3790.09 3808.95N 93.71W 3808.42 3825.68N 93.69W 3825.13 3842.24N 93.48W 3841.65 9096.67 7544.13 7468.33 28 36 9190.41 7626.35 7550.55 28 47 9284.92 7708.97 7633.17 29 17 9380.73 7792.40 7716.60 29 36 9476.22 7875.59 7799.79 29 12 N 4.20 W 3.75 N 6.20 W 1.05 N 10.40 W 2.22 N 15.10 W 2.43 N 15.00 W .42 3889.86N 94.73W 3889.27 3934.68N 98.81W 3934.25 3980.06N 105.44W 3979.92 4025.97N 115.84W 4026.32 4071.23N 128.01W 4072.18 9572.22 7959.79 7883.99 28 12 9668.06 8044.18 7968.38 28 23 9763.77 8127.88 8052.08 29 36 9859.91 8211.10 8135.30 30 30 9955.77 8293.00 8217.20 32 5 N 14.30 W 1.10 N 16.20 W .96 N 17.80 W 1.49 N 19.70 W 1.36 N 18.50 W 1.79 4115.83N 139.67W 4117.35 4159.66N 151.62W 4161.76 4204.03N 165.20W 4206.80 4249.60N 180.68W 4253.15 4296.66N 196.97W 4301.02 10053.01 8375.64 8299.84 31 30 10154.94 8463.14 8387.34 30 12 10249.50 8545.24 8469.44 29 17 10278.71 8570.67 8494.87 29 36 10310.89 8598.43 8522.63 31 12 N 17.60 W .79 N 18.80 W 1.41 N 19.80 W 1.09 N 19.40 W 1.23 N 18.70 W 5.09 4345.37N 212.84W 4350.52 4395.03N 229.16W 4400.99 4439.31N 244.66W 4446.05 4452.84N 249.48W 4459.82 4468.23N 254.79W 4475.47 10342.87 8625.37 8549.57 10375.01 8651.53 8575.73 10406.94 8676.52 8600.72 10438.86 8700.42 8624.62 10470.98 8723.31 8647.51 34 0 N 17.50 W 8.99 37 0 N 16.10 W 9.67 40 0 N 14.60 W 9.84 43 0 N 12.70 W 10.19 46 5 N 10.80 W 10.50 4484.61N 260.14W 4492.12 4502.47N 265.52W 4510.25 4521.64N 270.77W 4529.67 4542.19N 275.75W 4550.46 4564.25N 280.33W 4572.74 10503.33 8745.02 8669.22 10535.39 8764.97 8689.17 10567.30 8783.23 8707.43 10599.26 8799.90 8724.10 10611.20 8805.70 8729.90 49 35 53 24 56 47 60 17 61 35 N 10.80 W 10.82 N 10.10 W 11.98 N 10.30 W 10.67 N 8.60 W 11.85 N 7.90 W 12.03 4587.81N 284.83W 4596.50 4612.48N 289.37W 4621.38 4638.23N 294.01W 4647.35 4665.12N 298.47W 4674.44 4675.45N 299.97W 4684.84 RECSIVED JUL Al~k~ 011 & (~s Con~. Commi[~sion S~_~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU/J-07A 500292024101 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/24/96 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10665.90 8829.79 8753.99 10697.64 8842.52 8766.72 10729.73 8855.22 8779.42 10762.01 8867.88 8792.08 10793.87 8880.33 8804.53 COURS INCLN DG MN 66 7 66 34 66 48 66 58 67 1 DATE OF SURVEY: 060796 MWD SURVEY JOB NUMBER: AK-MW-60065 KELLY BUSHING ELEV. = 75.80 OPERATOR: BP EXPLORATION COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N 4.62 W 9.88 4724.25N 305.30W N 4.53 W 1.44 4753.23N 307.62W N 5.63 W 3.23 4782.58N 310.23W N 4.41 W 3.52 4812.16N 312.82W N 3.61 W 2.32 4841.41N 314.87W FT. VERT. SECT. 4733.85 4762.92 4792.37 4822.04 4851.37 10825.71 8892.76 8816.96 10858.00 8905.36 8829.56 10889.32 8917.57 8841.77 10910.01 8925.62 8849.82 10946.43 8939.44 8863.64 67 67 67 67 68 0 2 5 5 17 N 4.52 W 2.63 4870.65N 316.95W N 5.39 W 2.48 4900.27N 319.52W N 4.64 W 2.21 4929.00N 322.04W N 3.96 W 3.03 4948.01N 323.47W N 2.28 W 5.37 4981.65N 325.30W 4880.67 4910.39 4939.22 4958.27 4991.96 10978.90 8950.13 8874.33 11010.93 8957.81 8882.01 11037.64 8961.82 8886.02 11044.31 8962.48 8886.68 11076.16 8964.14 8888.34 11108.01 8964.40 8888.60 11139.98 8964.23 8888.43 11171.70 8963.78 8887.98 11203.54 8963.17 8887.37 11235.27 8962.61 8886.81 11267.10 8962.26 8886.46 11299.13 8962.49 8886.69 11331.05 8963.25 8887.45 11363.09 8964.00 8888.20 11395.41 8964.55 8888.75 11426.78 8964.29 8888.50 11458.98 8962.94 8887.14 11490.60 8960.95 8885.15 11522.56 8958.66 8882.86 11554.63 8956.22 8880.42 11587.76 8953.46 8877.66 11618.87 8950.54 8874.74 11651.62 8947.26 8871.46 11683.65 8944.69 8868.89 11715.17 8943.65 8867.85 73 15 78 58 83 44 84 52 89 8 89 56 90 39 90 59 91 11 90 49 90 25 88 43 88 33 88 46 89 17 91 37 93 12 93 58 94 15 94 26 95 7 95 39 95 51 93 21 90 24 N 1.63 W 15.42 5012.28N 326.34W N .76 W 18.05 5043.35N 326.99W N .76 W 17.82 5069.75N 327.34W N .61 W 17.24 5076.39N 327.42W N .12 E 13.57 5108.19N 327.56W N .84 E 3.38 5140.03N 327.29W N 1.56 E 3.16 5172.00N 326.62W N 2.29 E 2.54 5203.69N 325.55W N .08 E 6.97 5235.51N 324.90W N .51 E 1.79 5267.24N 324.73W N .88 W 4.54 5299.06N 324.83W N .58 E 7.00 5331.09N 324.92W N 1.69 W 7.13 5362.99N 325.23W N .34 W 4.27 5395.01N 325.79W N .48 W 1.67 5427.33N 326.03W N .91 W 7.58 5458.69N 326.41W N .67 W 4.96 5490.85N 326.85W N 2.26 W 5.58 5522.40N 327.66W N 2.82 W 1.96 5554.24N 329.07W N 1.02 W 5.62 5586.20N 330.14W N 2.70 W 5.45 5619.19N 331.21W N 1.17 W 5.18 5650.14N 332.26W N 3.36 W 6.68 5682.70N 333.55W N 2.80 W 8.00 5714.57N 335.26W N 3.00 W 9.41 5746.03N 336.85W 5022.60 5053.67 5080.04 5086.67 5118.43 5150.22 5182.10 5213.69 5245.43 5277.10 5308.88 5340.86 5372.74 5404.74 5437.02 5468.36 5500.50 5532.04 5563.91 5595.88 5628.88 5659.85 5692.42 5724.34 5755.84 RECEIVED JUL 1 2 1996 S~RRY-SUN DRILLING SERVICES ANCHOP~AGE A_LASH PAGE SHARED SERVICES DRILLING PBU/J-07A 500292024101 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/24/96 DATE OF SURVEY: 060796 MWD SURVEY JOB NUMBER: AK-MW-60065 KELLY BUSHING ELEV. = 75.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11746.64 8943.53 8867.73 90 3 11779.13 8943.55 8867.75 89 50 11808.95 8943.52 8867.72 90 15 11840.81 8943.29 8867.49 90 35 11872.89 8942.76 8866.96 91 17 N 2.17 W 2.85 5777.46N 338.27W N 2.47 W 1.13 5809.93N 339.59W N 3.86 W 4.85 5839.70N 341.23W N 3.65 W 1.26 5871.49N 343.32W N 2.27 W 4.82 5903.52N 344.98W 5787.31 5819.80 5849.61 5881.47 5913.54 11904.66 8941.95 8866.15 91 39 11917.82 8941.53 8865.73 91 56 11937.06 8940.85 8865.05 92 7 11968.03 8939.82 8864.02 91 41 12000.02 8939.92 8864.12 87 55 12019.21 8940.79 8864.99 86 55 12031.24 8941.41 8865.61 87 9 12063.51 8942.74 8866.94 88 5 12095.80 8943.34 8867.54 89 46 12126.82 8943.45 8867.65 89 49 N 3.77 W 4.86 5935.23N 346.65W N 2.36 W 10.92 5948.37N 347.35W N 1.24 W 5.89 5967.58N 347.96W N 2.82 W 5.28 5998.52N 349.05W N 2.07 W 12.02 6030.47N 350.42W N .01 W 11.95 6049.63N 350.77W N 1.37 W 11.46 6061.65N 350.91W N 1.62 W 2.98 6093.88N 351.75W N .41 E 8.18 6126.16N 352.09W N 3.45 E - 9.80 6157.15N 351.05W 5945.30 5958.45 5977.67 6008.62 6040.60 6059.75 6071.76 6103.98 6136.24 6167.13 12171.84 8943.56 8867.76 89 54 N 1.98 E 3.27 6202.12N 12235.00 8943.66 8867.86 89 54 N 1.98 E .00 6265.24N 348.92W 6211.92 346 . 73W 6274 . 83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6274.83 FEET AT NORTH 3 DEG. 10 MIN. WEST AT MD = 12235 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 356.89 DEG. TIED INTO J-07A AT 8707.40' KICKOFF POINT 8750.00' INTERPOLATED DEPTH 12235.00' SP~_~.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/J-07A 500292024101 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/24/96 DATE OF SURVEY: 060796 JOB NUMBER: AK-MW-60065 KELLY BUSHING ELEV. = 75.80 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8707.40 7236.14 7160.34 3656.81 N 101.73 W 1471.26 9707.40 8078.78 8002.98 4177.63 N 156.85 W 1628.62 157.36 10707.40 8846.40 8770.60 4762.16 N 308.32 W 1861.00 232.38 11707.40 8943.75 8867.96 5738.27 N 336.45 W 2763.65 902.65 12235.00 8943.66 8867.86 6265.24 N 346.73 W 3291.34 527.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SRERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/J-07A 500292024101 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/24/96 DATE OF SURVEY: 060796 JOB NUMBER: AK-MW-60065 KELLY BUSHING ELEV. = 75.80 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8707.40 7236.14 7160.34 3656.81 N 101.73 W 1471.26 8767.21 7275.80 7200.00 3701.42 N 98.00 W 1491.41 20.15 8899.93 7375.80 7300.00 3788.21 N 93.75 W 1524.13 32.72 9018.06 7475.80 7400.00 3851.04 N 93.41 W 1542.26 18.13 9132.75 7575.80 7500.00 3907.08 N 96.01 W 1556.95 14.68 9246.89 7675.80 7600.00 3961.75 N 102.09 W 1571.09 14.14 9361.64 7775.80 7700.00 4016.86 N 113.38 W 1585.84 14.75 9476.46 7875.80 7800.00 4071.35 N 128.04 W 1600.66 14.82 9590.38 7975.80 7900.00 4124.15 N 141.79 W 1614.58 13.92 9704.01 8075.80 8000.00 4176.08 N 156.39 W 1628.21 13.63 9818.96 8175.80 8100.00 4230.05 N 173.71 W 1643.16 14.95 9935.47 8275.80 8200.00 4286.43 N 193.54 W 1659.67 16.51 10053.20 8375.80 8300.00 4345.47 N 212.87 W 1677.40 17.73 10169.58 8475.80 8400.00 4402.00 N 231.53 W 1693.78 16.39 10284.61 8575.80 8500.00 4455.59 N 250.45 W 1708.81 15.02 10406.02 8675.80 8600.00 4521.09 N 270.62 W 1730.22 21.42 10554.11 8775.80 8700.00 4627.50 N 292.07 W 1778.31 48.09 10782.27 8875.80 8800.00 4830.76 N 314.17 W 1906.47 128.16 12235.00 8943.66 8867.86 6265.24 N 346.73 W 3291.34 1384.87 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED Alaska Oil & (~ Oon~. Oomm~ss~on S?ERR'r- PBU/J-OTR 50029202~10! 060796 NORTH SLOPE BOROUGH -SUN DR ~LL ~[ NO HEIR ~r ZONTFIL PREIJEE T I ON SERVfEES STRRT TVD = 7236. t~ FINISH TVO = 89q3.7! SCRLE IS q90 FEET/IN 65u, 0 i -2940 NEST SSDS 3.13 -2~50 -1960 - lU, 70 DE?FtRTURE MOBIZONTRL DISPLRCEMENT IS 627L~,93 -980 -490 12235 6050 556O 5070 g580 L~090 3600 C: \SURVET\JTR 50029202~01 060796 NORTH SLOPE -/200~ -/69(: RECEIVED JUL 1 2 1996 Alask~ Off & fl~s Co~l~. Cornrrliiliol~ A,ehorage 816 ' LL3 86 89~3.~ t22~5 ~oo YEfi-~ ~ Ci~L SECT ~ ON TONY KNOWLE$, GOVERNOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 16, 1996 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit J-07A BP Exploration (Alaska) Inc. Permit No. 96-87 Sur. Loc. 848'SNL. 804'WEL. Sec. 9. T11N. R13E, UM Btmnhole Loc. 5145'SNL, 1130'WEL. Sec. 33, T12N, R13E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other ' required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approx/mately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by d inspector on the North Slope pager at 659-3607. DavidW.,-J~ston ~ -' ~ Chairman ~ BY ORDER OF THE COMMISSION df/Enclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA tJIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 73.8 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028278 4'. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 848' SNL, 804' WEL, SEC. 9, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 25100302630-277 966' SNL, 1093' WEL, SEC. 4, T11N, R13E J-07A Attotal depth 9. Approximate spud date Amount $200,000.00 5145' SNL, 1130' WEL, SEC. 33, T12N, R13E 06/01/96 12. Distance to nearest property lineI 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ' ADL 028281 135'I No Close Approach 2560 12206' MD / 8968' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8750' MD Maximum Hole Angle 90° Maximum sudace 3300 psig, Attotal depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 2512' 8600' 7167' 11112' 8953' 276 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 1244' 10962' 8930' 12206' 8968' 148 sx Class 'G' _ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate ~'~ Liner . ~ ,~ f) .~.t, ",f,~?'.;r~, '~: i-~1 Perforation depth: measured /,-,l~s',¢- 01, ~-~ _&:3.¢t;o;~9~ true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tim Burns, 564-4315 Prepared By Name/Number Terrie Hubble, 564-4628 21. I hereby certify that ~.~ ;~ going is rue a d correct to the best of my knowledge Signed DanSto~z ,~ "-"- Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Number Approval Date_ I See cover letter I5o- ¢- / I ,__~' ---/~ ~¢¢, J for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Y~s ~ No Sulfide Measures~;~rYes [] No Directional Survey Required ~ Yes [] No Hydrogen Required Working Pressure for BOPE [] 2M; []3M; I~ 5M; [] 10M; [] 15M Other: . :"~-',';,8' Si~lrlsd By by order of Approved By i~)a¥io W. ~ohnBton Commissioner the commission Date ~ (9 ,, Form 10-401 Rev. 12-01-85 Submit In Triplic I Well Name: I J-7A I Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 848' FNL 804' FEL Sec 9, T11N, R13E Pilot Hole Bottom Hole Location: Not applicable Sadlerochit Zone 2 Lateral Start of Horizontal Location: 966' FNL 1,093' FEL Sec 4, T11 N, R13E End of Horizontal Location: 5,145' FNL 1,130' FEL Sec 33, T12N, R13E Start of Horizontal Location: End of Horizontal Location: I AFE Number: I 4P0813 I Not applicable Not applicable Sa~l River Lateral Estimated Start Date: I June 1, 1996 I Mm 112,206, I ITvD: I Ri~l: I Nabors 28-E I Operating days to complete: I 26 18,968' I IRT-GL I KBE: 33.8' +73.8' Well Design (conventional, slimhole, etc.) I Horizontal Formation Markers: Formation Tops MD TVD (SS) ~ ~ C ~:t' Ugnu N/A 3990' Above KOP .. - · ~--- HRZ N/A 6925' Above KOP Put River N/A N/A Above KOP /~,i~¥';~ ? Kingak 8675' 7140' Sag River 10293' 8500' .., ,,.,. ;;~ o r-~.~ S hublik 10351' 8550' ~",~::'" ...... '~' r, -. :....,~ Top Sadlerochit 10448' 8625' Zone 3 10713' 8770' Zone 2/2C 10870' 8830' 7" casing point (at or near horz, in Zone TD of Well 12206' 8895' 4-1/2" liner point Casinq/Tubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb!~ O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC-MO D 2512' 8600'/7167' 11112'/8953' Lower Lateral 6" I 4-1/2" 12.6# L-80 BTC-M O D 1244' 10962'/8930' 12206'/8968' Upper Lateral N/A I N/A N/A N/A N/A N/A N/A N/A I Production Tubing I 4-1/2" 12.6# L-80 BTC-M O D 10515' 35'/35' 10550'/8770' Cementing Program: Lead Cement Tail Cement Casin~Liner Sx / Wt / Yield Sx / Wt / Yield Comments Premium Tail only; Tail FW=0; 7" None 276 / 15.8 / 1.15 30% excess; Pump time = 4+ hrs; TOC =_+1,000' above Sag 4-1/2" None 148/15.8/1.19 Class G: 30% excess; TOC at liner top Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. I Logs: 12-1/4" Hole 8-1/2" Hole Logging Program: 6" Hole I Cased Hole: Not applicable MWD GR/Directional to top of Zone 3; MWD GR/CNL/Directional from Zone 3 to Zone 2 (horizontal); DPC logs are contigency only if MWD logs are inconclusive; MWD G R/Directional/Resistivity None planned Mud Program: Intermediate Mud Properties: I 8-1/2" hole section: LSND Density Yield 10 sec 10 min pH Fluid (PPG) PV Point gel gel Loss Initial 8.6-8.8 6-10 6-8 3-6 8-10 9.0-9.5 8-12 Cretaceous 9.8 10-12 8-12 4-8 8-12 9.0-9.5 <8 Final 9.8 16-20 8-12 LSYP 12-16 16-20 9.0-9.5 HTHP-<15.0 Hazards/Concerns Cretaceous (Kingak) MW to be at least 9.8 ppg. Utilize hi vis sweeps to assist hole cleaning Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could need lubricant use. Reduce APl fluid loss to <6 cc before drilling Kingak Section. Differential sticking due to higher MW. Production Mud Properties: I 6" hole section: FIo-Pro Polymer Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6 Final 9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6 Hazards/Concerns Lost Circulation due to overbalance in Sadlerochit. Differential sticking with overbalance situation. Perform report daily checks on KCI concentrations in Xanvis KCI system. High torque to be combated with lubricants. REC iVED ~1%~r?, Oil & l., ~', .... ~,:~, ~',01'i'3, "' ,.~,~;oe'~.. Directional: I KOP: I 8,750' MD (Sidetrack from 9-5/8" casing) Maximum Hole An~lle: I 90° Tangent Angle I N/A (Slant with horizontal leg) Close Approach Well: None Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal No annular injection permits will be submitted for the J-Pad sidetrack program. Operational J-7A Horizontal Sidetrack Summary . . . , . . . , ! 10. 11. P&A well. Test cement to 1,500 psi. Tag cement minimum of 100' above top perforation @ 11,200' MD. Cut the 7" tubing @ _+9,400' MD. MIRU Nabors 28-E drilling rig. Pull 7" tubing. Test 9-5/8" casing to 3,500 psi for 10 minutes. RIH and set EZSV at _+9,050' MD (255' below proposed 9-5/8" section). PU section mill, TIH and spot _+18 bbl (_+255') of 18.0 ppg milling fluid from EZSV (9,050' MD) to 8,795' MD. Space out and mill section from 8,745' MD to 8,795' MD. POOH. TIH with open-ended drillpipe. Mix and spot a 17.0 ppg cement kick-off plug (per recommended practices) from 8,895' to 8,545' MD. POOH a minimum of 12 stands. Perform a hesitation squeeze. Do not exceed a final squeeze pressure of 2,000 PSI and do not displace cement any closer than 100' above section top. NOTE: Final cement volume should insure slurry placement 100' below milled section, 50' across milled section and 200' inside casing above milled section. PU directional BHA and TIH. Tag TOC. MINIMUM WOC TIME IS 12 HOURS. Dress off cement plug to 8,750' MD (5' below top of section), kick-off and directionally drill to _+11,112' MD (8,953' TVD). Final inclination is planned for 90© along an azimuth of 358©. POOH. If hole conditions warrant, a hole opener may be run prior to running 7" liner. RU and run 7" liner from 11,112' MD and tie back into 9-5/8" casing at _+8,600' MD. POOH and LD liner running tools. PU directional BHA and drill 6" horizontal hole to 12,206' MD (final inclination at ___89°) at an azimuth of 358°. Lateral interval is_+1,100'. POOH. NOTE: Inclination, azimuth and overall lateral length may be shortened by onsite geologist. MW in this interval will be _+9.0 ppg. J-7A Sidetrack Operations Summary Page 2/2 12. 13. 14. 15. 16. 17. Run and run a 4-1/2", L-80 solid liner to TD and cement in place. Top of liner will be at _+10,962' MD. NOTE' A wiper trip may be made, prior to running production liner. RIH with DPC perforating guns and perforate 4-1/2" production liner using MWD logs to select optimum perf interval. POOH. RU and run 4-1/2", L-80, production tubing with 7" x 4-1/2" permanent production packer at _+10,550' MD (_+55© inclination). Set two way check and test to 1,000 psi. ND BOPE. NU tree and test to 5,000 psi. Freeze protect well and release rig. Drilling Hazards KOP will occur in the Kingak shales. MW should be at minimum 9.8 ppg to maintain hole stability. Shublik B interval may be fractured resulting in lost circulation. 7" liner will set across these intervals. Sadlerochit interval has an estimated pore pressure of _+7.4 ppg EMW. Lost circulation may occur due to overbalance conditions. Small (20') faults are expected in the the build interval of Zone 2C. Lost circulation is possible but not likely. No faulting is anticipated in the horizontal interval. There are no known drilling close approaches. No other known drilling hazards are expected. BPX - Shared Services Drilling Alaska State Plane' Zone4 PBU · WOA: J-Pad Slot ' J-O7A Wellpath' J-O7A Wp9 HALLIBURTON PLOT INFORMATION DRAWING NAME / FILE NAME ~/r~m~ SURFACE LOCATION PROPOSED BH~ ~ ~ P~e O ~ TVD 8968.93 MD 12206.93 ~ 0 ~ VS 6271.99 N/S 6262.76 N P~nRTE R.: 0 Date: 09-25-i996 Designed By: Verified By: Ced~3ed By: WELL PLAN PROFILE SUMMARY START MI~ END MD1 PLANNED ACTMTY HORIZONTAL VIE.W (TRUE NORTH) SCALE 200 ft./ in. SUAVEY lIEF: WELM~EAD f, m'.hn!'-3~.! 8400 -8800 -8000 -7800 -7600 -7400 -7800 1.7000 6800 CRITICAL POINT DATA ~ Tn~ ~zl. fvD N/s E/V KDP / TIE IN / 8750 49.05' 5.08' 7863 36~0 N 99 V ST^RT ~F CURVE 8.00'/100 ft . END DF' CURVE 90~8 30.00' 348.00*74733861N 104 TJF 9196 30.00' 348.00'7~4 3946N 182 TJE 9399 30.00' 348.00'77994045 N 143 TJD 9641 30.00' 348.00'80094164N 169 Td~ 9959 30,00' 348,00'8~844319 ~ 808 TJB 10109 30.00' 348.00o84144398N 217 TSGR 10293 30-00' 348.00'85744483 N ST.&J~T OF 1031~ 3~.00o 348,00'8590449~N E38 CUrvE 10,00'/100 Ft TSHU 1035~ 33.94' 349.31'8~4 4513 N ¥S~D ! iv]sh~k 10~48 43.45* 351.60'86994578 N 858 V / Z4 - 48 END ~- CURVE 10690 67.50' 355.00'88354769 N 874 V [Z3 10713 67.50' 355.00'8844479~ N 876 TZ~C 10870 67.50' 355.00'B°-~4 4934 N 889 START OF 10886 67.50' 355.00'89104949 N 890 CURVE IO. O0'/tO0 ~t PGDC 10986 7L45' 355.57'898449~6 N 893 END [~ CURVE 111t3 c)~.O0' 358.00'89545i69 N 303 START DF 11313 90.00' 358.00'89545359 N 310 V CURVE ~.00'/100 F~ END DF CURVE 113(~ Bg. 01' 358.10'89545419N J-OTA N5 18807 89.01' 358.10'89696~63 N 340 V CASING POINT DATA 311 v OD MD lnc Azi fvD N/S E/~ 7 In 11318 B9.90o 358.01' 8954 5374 N II,ri}et N~me TVD NS Eg ~id X ~id y J-O?A NI 8954 516~ N 301 ~ 643150 5975660 J-07A N8 8954 5048 N 618 ~ 648835 5975540 J-OTA N3 8954 5411N~36 ~ 643810 5975910 J-07A N4 8954 5897 N 554 V 648895 5975790 J-07h N5 8969 6863 N 340 ~ 6430~ 5976760 J-07A NG 8969 6849 N 140 V 643890 5976750 HOHZ Poty 8954 5168 N 301V 643130 5975660 HA~ Poty 8961 5411N836 ~ 643210 5975910 VERTICAl, VIEW SCALE 100 ft. / in. TVD REF: WELLHEAD VERTICAl, SECTION REF: WELLHEAD 16oo~ 7863 369~x~ 49,05'88750H~ K~/TIEI~/ST~T~CL~VE~8,~O'II~3ft~.~.~.-...~ ~.. ........ . ...... ,~oo- ~ ....... it has not yet ~n mdlfledl ~799 B2B~ 84OO 64~4 8574 8590 6600 6624 869S 8835 8844 %-= .... -- .... 8904 BglO = B984 '' B954 - ~96g - ~o~o 3600 - - -- 4519 $7 -- - 51?8 5378 54ZB 7 k100, O 11113 MD, ~I'P,/D - 355 57' - 355. ~0' - 354.%0' ~ . 349.31 7799 7473 ' 34 ' HORIZONTAL VIE.W (TRUE NORTH) SCALE 100 ft./ in. SURVEY REF: WELLHEAD 14°° 300 800 II/ 5800 5700 5600 7 c GO0 500 400 3~ 800 too o 38'00 4ob 486o 44'00 4800 VERTICAL SECTION PLANE: 356.89" 54'00 6obo 6zbo 64b~ Halliburton Energy Services - Drilling Systems PSL Proposal Report Pa~e 1 Proposal No: 96-012 Date: 4/25/96. Time: 10:59 am Wellpath ID: J-07A Wp9 Last Revision: 4/25/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.19.37 N - Long. 148.50~09 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 5970505.36 N 643549.68 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.1 Vertical Section Plane: 356.89 deg. WELLPLAN FEASIBILITY STUDY This plan is for feasibility purloCae~ only' it has not yet been certifledl BPX - Shared Services Drilling Alaska State Plane: Zone4 PBU: WOA: J-Pad Slot: J-07A Wellpath: J-07A Wp9 Measured lncl Drift Subsea TVD Course T O T A L GRID Coordinates Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Survey Tool Depth Dir. Depth Length Rectangular Offsets Northing Easting Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (fl[) (deg.) (deg.) (fl[) (ft) (fl:) (fl:) (fl[) (fl;) (fl;) (fl;) (deg.) (ft) (dg/lOOft) (dg/lOOft) (dg/lOOfl:) (deg) (fl;) (f~) (fl[) (fl:) (deg.) (fl[) 8505.53 48.22 2.45 7026.64 7100.57 100.00 3508.21N lll.41W 5974010.52 643371.21 3509.97~358.18 3509.08 -0.26 0.34 0.36 83.2 3508.21N lll.41W 284.42 41.91 88.38 48.43 BPCG-PBD 8605.53 48.00 3.95 7093.41 7167.34 100.00 3582.53N 107.25W 5974084.91 643373.94 3584.13~358.29 3583.07 -0.22 1.50 1.14 84.3 3582.53N 107.25W 290.52 42.69 88.53 48.88 BPCG-PBD TKNG 8675.29 48.21 4.36 7140.00 7213.93 69.76 3634.32N 103.49W 5974136.76 643376.72 3635.79~358.37 3634.58 0.30 0.59 0.53 84.7 3634.32N 103.49W 294.81 42.94 88.63 49.42 BPCG-PBD 8705.53 48.30 4.54 7160.13 7234.06 30.24 3656.81N I01.74W 5974159.28 643378.04 3658.23~358.41 3656.95 0.30 0.59 KOP / TIE IN / INTERPOLATED POINT / START OF CURVE ~ 8.00 deg/100 ft 8750.00 49.05 5.02 7189.50 7263.43 44.47 3690.09N 98.95W 5974192.60 643380.18 3691.42~358.46 3690.03 1.70 1.09 8850.00 41.79 0.30 7259.65 7333.58 100.00 3761.15N 95.47W 5974263.71 643382.31 3762.36~358.55 3760.80 -7.26 -4.73 0.53 84.9 3656.81N I01.74W 296.67 43.05 88.67 49.65 BPCG-PBD 1.88 85.7 3690.09N 98.95W 299.48 42.78 88.74 50.39 BPCG-PBD 8.00 93.7 3761.15N 95.46W 300.29 47.81 88.63 45.73 BPI-IM-PBD 8950.00 34.79 354.03 7338.12 7412.05 100.00 3822.95N 98.27W 5974325.44 643378.33 3824.21~358.53 3822.65 -7.00 -6.26 END OF CURVE 9022.16 30.00 348.00 7399.05 7472.98 72.16 3861.10N 104.16W 5974363.47 643371.70 3862.51~358.45 3861.07 -6.64 -8.36 TJF 9196.46 30.00 348.00 7550.00 7623.93 174.30 3946.35N 122.28W 5974448.34 643351.96 3948.24~358.23 3947.17 0.00 0.00 8.00 101.7 3822.93N 98.46W 300.96 52.37 88.52 40.86 BPHM-PBD 8.00 107.5 3861.03N I04.58W 30i.35 55.27 88.46 37.42 BPHM-PBD 0.00 107.5 3946.16N 123.24W 302.40 55.53 88.42 37.70 BPHM-PBD TJE 9398.53 30.00 348.00 7725.00 7798.93 202.07 4045.18N 143.29W 5974546.75 643329.08 4047.71~357.97 4046.99 0.00 0.00 TJD 9641.02 30.00 348.00 7935.00 8008.93 242.49 4163.77N 168.50W 5974664.83 643301.62 4167.18~357.68 4166.78 0.00 0.00 TJC 9958.56 30.00 348.00 8210.00 8283.93 317.54 4319.07N 201.51W 5974819.46 643265.65 4323.77~357.33 4323.64 0.00 0.00 0.00 107.5 4044.86N 144.87W 303.65 55.84 88.38 38.03 BPHM-PBD 0.00 107.5 4163.29N 170.84W 305.20 56.24 88.32 38.44 BPI-IM-PBD 0.00 107.5 4318.38N 204.83W 307.31 56.81 88.24 38.98 BPHM-PBD TJB 10108.67 30.00 348.00 8340.00 8413.93 150.11 4392.49N 217.11W 5974892.56 643248.65 4397.85~357.17 4397.80 0.00 0.00 TSGR 10293.43 30.00 348.00 8500.00 8573.93 184.75 4482.84N 236.32W 5974982.52 643227.73 4489.07~_~356.98 4489.06 0.00 0.00 START OF CURVE ~ 10.00 deg/100 R 10311.98 30.00 348.00 8516.07 8590.00 18.56 4491.92N 238.25W 5974991.56 643225.63 4498.23~356.96 4498.23 0.00 0.00 0.00 107.5 4391.70N 220.90W 308.34 57.10 88.20 39.24 BPHM-PBD 0.00 107.5 4481.94N 240.68W 309.63 57.46 88.15 39.57 BPHM-PBD 0.00 107.5 4491.00N 242.67W 309.76 57.50 88.15 39.60 BPHM-PBD TSHU 10351.99 33.94 349.31 8550.00 8623.93 40.00 4512.68N 242.40W 5975012.24 643221.08 4519.19~356.93 4519.19 9.85 3.29 10.00 I 11.5 4511.74N 246.96W 310.08 55.54 88.13 42.48 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 4/25/~J6 Wellpath ID: J-07A Wp9 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (fl:) (deg.) (deg.) (fl:) (fi) (fi) (fl:) (fl:) GRID Coordinates Northing Easting Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (fi) (deg.) (fl) (dg/lOOfi) (dg/lOOfl) (dg/lOOff) (deg) (fl) 10411.98 39.87 350.85 8597.95 8671.88 60.00 4548.16N 248.5TN 5975047.59 643214.24 4554.95~356.87 4554.95 9.88 TSAD / Ivishak / Z4 - 4B 10448.19 43.45 351.60 8625.00 8698.93 36.21 4571.94N 252.23W 5975071.29 643210.12 4578.89~356.84 4578.89 9.90 10511.98 49.78 352.72 8668.80 8742.73 63.79 4617.85N 258.53W 5975117.07 643202.95 4625.08~356.80 4625.08 9.92 10611.98 59.72 354.10 8726.44 8800.37 100.00 4698.88N 267.83W 5975197.90 643192.11 4706.51~356.74 4706.49 9.94 END OF CURVE 10690.21 67.50 355.00 8761.19 8835.12 78.23 4768.59N 274.46W 5975267.46 643184.15 4776.48~356.71 4776.45 9.95 TZ3 10713.25 67.50 355.00 8770.00 8843.93 23.03 4789.79N 276.32W 5975288.62 643181.89 4797.75~356.70 4797.72 0.00 TZ2C 10870.03 67.50 355.00 8830.00 8903.93 156.79 4934.09N 288.94W 5975432.65 643166.52 4942.54~356.65 4942.50 0.00 START OF CURVE ~ 10.00 deg/100 fl: 10885.76 67.50 355.00 8836.02 8909.95 15.73 4948.56N 290.21W 5975447.09 643164.97 4957.07~356.64 4957.02 0.00 PGOC 10925.65 71.45 355.57 8850.00 8923.93 39.88 4985.78N 293.2TN 5975484.24 643161.20 4994.40~356.63 4994.35 9.91 10985.76 77.41 356.38 8866.12 8940.05 60.12 5043.53N 297.33W 5975541.90 643156.04 5052.28~356.63 5052.23 9.92 11085.76 87.34 357.66 8879.38 8953.31 100.00 5142.38N 302.46W 5975640.63 643149.03 5151.27~356.63 5151.22 9.92 CASING POINT OD = 7 in, ID = 6.18 in, Weight = 29.00 lb/fi. 11112.60 90.00 358.00 8880.00 8953.93 26.83 5169.19N 303.4TW 5975667.41 643147.50 5178.09~356.64 5178.04 9.92 END OF CURVE 11112.61 90.00 358.00 8880.00 8953.93 0.01 5169.20N 303.47W 5975667.42 643147.50 5178.10~356.64 5178.05 9.70 START OF CURVE ~ 2.00 deg/100 fl 11312.61 90.00 358.00 8880.00 8953.93 200.00 5369.08N 310.45W 5975867.11 643136.70 5378.05~356.69 5378.01 0.00 END OF CURVE 11362.30 89.01 358.10 8880.43 8954.36 49.69 5418.74N 312.14W 5975916.73 643134.07 5427.72~356.70 5427.69 -1.99 CASING POINT OD = 4 I/2 in, ID = 3.95 in, Weight = 12.60 lb/fi. 12206.90 89.01 358.10 8895.00 8968.93 844.60 6262.75N 340.10W 5976759.99 643090.00 6271.98~356.89 6271.98 4}.00 J-07A N5 12206.92 89.01 358.10 8895.00 8968.93 0.02 6262.77N 340.10W 5976760.00 643090.00 6271.99~356.89 6271.99 0.26 Survey Tool (fl) (fl) (fl) (deg.) (fl) 2.56 10.00 117.5 4547.17N 253.37W 310.64 52.24 88.10 46.74 BPHM-PBD 2.08 10.00 121.1 4570.93N 257.18W 311.00 50.05 88.09 49.23 BPHM-PBD 1.74 10.00 127.5 4616.81N 263.76W 311.72 45.92 88.07'53.39 BPHM-PBD 1.39 10.00 137.5 4697.79N 273.53W 313.01 39.00 88.05 59.06 BPHM-PBD 1.15 10.00 145.3 4767.46N 280.5 IW 314.11 33.62 88.05 62.60 BPHM-PBD 0.00 0.00 145.3 4788.65N 282.47W 314.43 33.69 88.04 62.66 BPHM-PBD 0.00 0.00 145.3 4932.89N 295.81W 316.69 34.17 88.01 63.15 BPHM-PBD 0.00 0.00 145.3 4947.36N 297.15W 316.91 34.22 88.00 63.20 BPHM-PBD 1.43 10.00 149.3 4984.57N 300.38W 317.52 31.72 88.01 64.65 BPHM-PBD 1.35 10.00 155.3 5042.30N 304.66W 318.46 28.47 88.02 66.39 BPHM-PBD 1.28 10.00 165.3 5141.15N 310.03W 320.09 25.38 88.06 68.01 BPHM-PBD 1.26 10.00 168.0 5169.19N 303.47W 0.00 0.00 0.00 0.00 BPHM-PBD 0.52 0.00 0.21 9.71 168.0 5167.96N 311.11W 320.53 25.24 88.07 68.16 BPHM-PBD 0.00 168.0 5367.82N 318.51W 323.87 25.38 88.05 68.92 BPHM-PBD 2.00 169.0 5417.48N 320.30W 324.72 25.44 88.05 69.10 BPHM-PBD 0.00 0.00 0.00 169.0 6262.75N 340.10W 0.00 0.00 0.00 0.00 BPHM-PBD 0.26 169.0 6261.45N 349.96W 340.19 26.18 87.98 72.92 BPHM-PBD WELLPLAN FEASIBILITY SI'IJDY This plan ls for feasibility purposes only it has not yet been certified! '-"-'7~ STATE OF ALASKA ~ -,.' .~ ALASKA ~,L AND GAS CONSERVATION COMMISSION ,~ APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend ~ [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plugged Back for Sidetrack 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I [] Development KBE = 68.19' AMSL [] Exploratory 7. Unit or Property Name [] Stratigraphic Prudhoe Bay Unit 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 848' SNL, 804' WEL, SEC. 9, T11N, R13E At top of productive interval 845' SNL, 478' WEL, SEC. 4, T11N, R13E At effective depth 508' SNL, 234' WEL, SEC. 4, T11N, R13E At total depth 485' SNL, 231' WEL, SEC. 4, T11N, R13E ORIGINAL 8. Well Number J~07 9. Permit Number 77-10 10. APl Number 50-029-20241 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11612 true vertical 9192 Effective depth: measured 11567 true vertical 9157 Casing Length Structural -- Conductor 110' Surface 2642' Intermediate 10547' Production -- Liner 1557' feet feet feet feet Size Plugs (measured) Junk (measured) 20" x 30" 8 cu yds 13-3/8" 4140 cu ft 9-5/8" 1910 cuft 7" 320 cu ft Bridge Plug at 11366' MD CaCO3 scale at 11359' MD (on top of B.P.) (04/89) Cemented MD TVD 138' 138' 2670' 2670' 10575' 8434' 10053'- 11610' 8095'- 9191' Perforation depth: measured true vertical 11300'-11310',11325'-11368',11278'-11300'; Squeezed: 11238'-11268' subsea 8835'-8957'(fourintervals) RECEIVED Tubing (size, grade, and measured depth) 7", L-80 stabbed into top of liner at 10053' APR 2:5 1996 Packers and SSSV (type and measured depth) no packer; 4-1/2" SSSV and insert at 21 l~Ir~ska 0il & Gas Cons. Commission Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 1, 1996 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/Number: Tim Burns, 564-4315 Prepared By Name/Number Terrie Hubble, 564-4628 17. I hereby certify that th.~e foregoj~g~correct to the best of my knowledge Signed¢.~ ~ / f~ "/~,'~,~r 7..-~'~,~.~tJ Title Senior Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness I Approval No. Plug integrity ,')( BOP Test __ Location clearance Mechanical Integrity TeS-tr--O~ "" Sub. sequent form required 10---A-~~d Copy ~lgnea i~y ~e~,~rned /,,~ Approved by order of the Commission David W. gohnstoF, 'CommissionerT/'~'~ "/-~' ~ Date Form 10-403 Rev. 06/15/88 Submit In Triplicate · WELL PER, IIT CHECKLIST COMPANY,~/~ GEOL AREA PROGRAM: exp [] dev [] red~21~erv [] wellbore seg [] ann. disposal para req [] UNIT# ///~-~_~' ON/OFF SHORE ¢:~¢t~J ADMINISTRATION 1. Permit fee attached ...................... 2. Lease number appropriate .................. 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from drlg unit boundary .... 6. Well located proper distance from other wells ........ 7. Sufficient acreage available in ddlling unit .......... 8. If deviated, is wellbore plat included ............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ............ 11. Permit can be issued without conservation order ..... 12. Permit can be issued without adminisb'ative approval... 13. Can permit be approved before 1 5-day wait .......... ENGINEERING N N N N N N N N N N N REMARKS APPR ~,~_~ GEOLOGY .,~ D E 14. Conductor string provided ................... Y N 15. Surface casing protects ail known USDWs .......... Y N 16. CMT vol adequate to circulate on conductor & surf csg .... Y N 17. CMT vol adequate to tie-in long swing to surf csg ....... Y N 18. CMT will cover all known productive horizons ......... (~ N 19. Casing designs adequate for C, T, B & permafrost ...... ~ N 20. Adequate tankage or reserve pit ............... .,~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved... 22. Adequate wellbore separation proposed ............ ~ N 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... (~,N 25. BOPEs adequate ....................... r,,~ 26. BOPE press rating adequate; test to 27. Choke manifold complies w/APl RP-53 (May 84) ....... W--N-~'''''*'~ 28. Work will occur without operation shutdown .......... .~ N 29. Is presence of H2S gas probable ............... ~ N 31. Data presented on potential overpressure zones 32. Seismic analysis of shallow gas zones ............. /Y/N / -" N 33. Seabed condition survey (if off-shore) ........... ./ZY N 34. Con~act name/phone for weekl~ progress rep~rt~ ,....//.. Y lexp~oratory on~,j GEOLOGY: ENGINEERING: COMMISSION: BEW DW~ JDH ~ JDN~ TAB ~ Comments/Instructions: g HOW/I~ - A:~FORMStcheklist rev 4/96 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0'SEEEI 000'9 0'690II 000'L 00S'8 (La) HLdaQ (MI) aZIS (MI) ZZIS LI~ SEZqqIEQ DNI S~fD Z~IOH NadO , S8'05 0£'~L 08'qL 508 858 ,~£I 6 NOXIG 'D 8 NnE ~ NOXI(/ 'D L ~3.E (/MN NOXI~ 'D S66IED 'Z 9 NFIE GMN MOXI~ 'D S~I6OL 'D :SSZNLIM EOL¥~Z~O :EZ6MEIN 60£ NOXI(/ S~fI 6OL NIlE NOXI~ 'D £ NflHQM3~ 96-dZS-6I 'DMZ (¥ZS~ml~f) MOILYHO~dXZ d6 IOISEOE6~00S ~L0-£ MOXI~ ' D S~{6IED ' Z 8ES096-~-M~f E N/lq (/MN :SSZMLIM :HZZNI©NZ q :aclXq sT E aIT~qns ,adeL. NATURAL ~ ~ PROBE, SCINTILLATION Ti DETECTOR AND IS NOTED AS NGP/SGRD TYPE DATA. GAMMA RAY DATA FROM 10607' TO 12187' WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS AND IS NOTED AS DGR/SGRC TYPE DATA. WELL J-07A IS DRILLED TO TD AT 12235'. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10059.0 12187.0 10571.0 12187.0 10581.0 11023.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 10129.0 10322.0 3 10322.0 10676.0 4 10676.0 10930.0 5 10930.0 11069.0 6 11069..0 11522.0 7 11522.0 11984.0 8 11984.0 12235.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-07A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 0HMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM NPHI MWD 68 1 PU-S 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 186 4 0 334 30 4 90 334 31 4 90 180 01 4 90 810 01 40 Tape File Start Depth = 12187.000000 Tape File End Depth = 10058.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 46850 datums Tape Subfile: 2 292 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10058.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10251.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 30 -MAY- 96 MSC VER 1.32 / ISC VER 4.54 DEP V.2.04 / V.2.17 MEMORY 10322.0 10129.0 10322.0 0 29.3 30.2 TOOL NUMBER NGP 94 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8600.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.90 52.0 10.3 1100 4.9 .000 .000 .000 .000 .0 150.1 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT BP EXPLORATION (ALASKA) J-07A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10330.000000 Tape File End Depth = 10058.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1636 datums Tape Subfile: 3 70 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10242.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWATHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIM UMANGLE: STOP DEPTH 10607.0 31-MAY-96 MSC VER 1.32 / ISC VER 4.54 DEP V.2.04 / V.2.17 MEMORY 10676.0 10322.0 10676.0 0 29.4 61.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 110 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8600.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTR3ITE AT MT: MUD CAKE AT MT: LSND 9.80 44.0 9.2 1100 4.7 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 3. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-07A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 10680.000000 Tape File End Depth = 10235.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49524 datums Tape Subfile: 4 74 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS EWR4 CNP $ LOG ~ HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10588.0 10901.0 10571.0 10886.0 10581.0 10894.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMARAY $ 01-JI/N- 96 MSC VER'l.32 / ISC VER 4.54 DEP V.2.04 / V.2.17 MEMORY 10930.0 10676.0 10930.0 0 66.1 67.1 TOOL NUMBER P0534CRNGP6 P0534CRNGP6 P0534CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8600.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MI/D CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 45.0 9.3 1000 4.6 1.400 .910 1.100 1.600 110.0 172.0 110.0 110.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 s~Xq 8IOI :q~BusI p~om~ mnm!x~ s~Xq 59 :qjBu~I p~om~ mnmiu!~ · ''sp~oDsl I0I S :sIY~qns smn~p 8EEOI 89 :spoD :A~mmns 5u~poo~p spoo uoy~u~s@~d~ SIq ~ = s~u~ q~d~ ~I~ 00000~'0 = 6u~oPds I~As~ ~I~ sdPi 000000'09SOI = q~d~ puZ ~II~ 000000'0S60I = q~d~ ~S ~IT~ O~ I I I I I I I I I I I0 018 06 ~ I0 08I 06 ~ I£ 5££ 06 ~ 0£ ~££ 06 ~ I0 068 06 ~ 9~ 0ET 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ 9P 0EI 06 P I0 0I£ 06 ~ pon sIO di£ cL{i q~6u~ sz~s Id~ IdV IdV Id~ s~u~ s~Idm~S ~poD IOOi :s~A~nD 0T . ~S~ : ZdO~IS H£%{ON : X~ ZOHCKI~d : ~f/.0 -D : (~O{S~) NOIL~O~IdXZ d~t : NI1OD NM ND : (NT) eletOO_k'-~iS ~00£ 000' : (MI) MOIiOZHEOO ZqOH qOOi NOHJ~qZN 0'89 0'89 0'98I 0'89 00S'~ 0fi£ 'I 0fi9 ' 00L'I I'~ 000I 9'8 0'~ 06'6 iH 0'0098 00S'8 : (If) HIdZG ©NISVO S,EZq~IEG : (NI) ZZIS II~ ZqOH Vi~ ONIS~D ~N%f 9dDN~D~£fi0d 9dDN~D~£fi0d 8'58 5'89 0 0'690II 0'0£60I 0'690II £Y'~'^ / ~o'~'A ~'~ ~A DSI / E£'I E~A 96-Nil~?- E0 (NOiiO~ Oi dOi) O~IEIS ~OOi ~fi~fG E,~(I~,~H OO~I :scl/lq sT 9 STT~qns sd~i T'OOL ~TANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-07A : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 21 Tape File Start Depth = 11075.000000 Tape File End Depth = 10835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54816 datums Tape Subfile: 6 88 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NI/MBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10967.0 EWR4 10973.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMIIM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11474.0 11481.0 05-JUN-96 MSC VER 1.32 / ISC VER 4.54 DEP V.2.04 / V.2.17 MEMORY 11522.0 11069.0 11522.0 0 84.9 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0475SP4 P0475SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11069.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SHEARDRILL 9.10 44.0 8.6 23500 4.8 .220 .140 .180 .280 100.0 192.4 100.0 100.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 6. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-07A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 37 Tape File Start Depth = 11530.000000 Tape File End Depth = 10960.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19357 datums Tape Subfile: 7 102 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NLIMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11444.0 EWR4 11450.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11936.0 11943.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 06-JUN-96 MSC VER 1.32 / ISC VER 4.54 DEP V.2.04 / V.2.17 MEMORY 11984.0 11522.0 11984.0 0 89.9 95.9 TOOL NUMBER P0475SP4 P0475SP4 6.000 11069.0 SHEARDRILL 9.20 45.0 9.0 .25000 4.4 .180 .120 .160 .240 90.0 182.5 90.0 90.0 .00 .000 .0 0 ss~Xq 866 :q~6usI p~oDs~ mnmTx~X ss~Xq E9 :q~Bu~I p~o~z mnmTuT~ · ''~p~oo~ T0I 8 :~I~qns smn~p SE9£9 89 :~poD :A~mmns 6u~poosp ~poo uo~uss~ds~ SI~ 00000S'0 = Bu~seds I~S~ ~I~ 000000'0~II = qqd~ pu~ ~IT~ 000000'066II = q~daG ~AeqS ~IT~ 9£ :sp~oosM e~ I~Oi 866 (0 #~dX£) GHOD~H ~i~Q ~ I0 018 06 5 I0 08I 06 ~ 9~ 0EI 06 5 9~ 0EI 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ I0 0I£ 06 ~ pon SlD cIXi clKi q~Susq sz~s Id~ Id~ Id~ s~Tu~ s~Idm~s spoD IOO£ ~m~X :ssAxnD £ g :GI q~dsp (~9 #~dX£) G%tOO,WH J~0.4 ~ ~Ot S ~l~f : ZdO~IS Hi%tON : X~f~ ZOHGiI%td : ~fLO-£ : (~OtS%f-f~) MOIL~IO~IdXZ dS : N/iOD N~ NM ND 0 0' : (~z) .4.40Gmf, T,S ~OO& 000 ' 00' :(NI) NOIID~HMOD ~qOH :XI~ZtfI4 ~00~ NO~ifl~N 0'E8 0'E8 0 ' P8I 0'~8 0IE ' 06I ' 860 ' 0I~ ' 8'5 000SE 0'9P 0E'6 0'690II 000'9 : (i~) HIdMG OMIS~D :(MI) MZIS ~i~G OMIS~D GN-~ H~OHHMO~ PdS~LPOd PdSSLPOd I'E6 E'L8 0 0'S£gEI 0'P86II 0'S£EEI AZ'Z'A / ~0'Z'A amc ~S'~ ~aA DSI / E£°T ~aA OSN 96-NlrlD- 80 P ' SI SH%t ' D~,~IOMiD,~"I,¢I' PMM,~ ,¢l'&Xi q:OO,T, H(IOD '-ZOO,T, ~O(LIXI:EA (NOiiO~ Oi dO,L) ObII%I.LS q:OOJ.., 0'£8IEI 0'L8IgI H£dHG dOIS ~2ESf2H ~qI~ SI~ :sdX~ sT 6 sIl~qns sdei REMARKS: CN WN FN COUN STAT MWD RUN 8. $ : BP EXPLORATION (ALASKA) : J-07A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 25 Tape File Start Depth = 12187.000000 Tape File End Depth = 11815.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25318 datums Tape Subfile: 9 90 records... Minimum record length: Maximum record length: 38 bytes 998 bytes Tape Subfile 10 is type: LIS 96/ 9/18 01 **** REEL TRAILER **** 96/ 9/18 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 18 SEP 96 3:40p Elapsed execution time = 2.63 seconds. SYSTEM RETURN CODE = 0
