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194-158
1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 194-158 12/26/1994 1/4/1995 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 3907' FSL, 920' FEL, Sec. 35, T11N, R13E, UM 2979' FSL, 4558' FEL, Sec. 35, T11N, R13E, UM 2982' FSL, 4562' FEL, Sec. 35, T11N, R13E, UM Surface: x- y- Zone -654453 5949076 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 4/25/2020 15. 50-029-22530-00-00 16. PBU A-41 Well Name and Number: Surface / Surface 47.40 17. TPI:y- Zone -650835 ASP 4x-5948073 Total Depth: x-y-Zone -650831 ASP 45948076 10375' / 9243' None DNR Approval Number:19. 69-026 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: DIFL / BHCS / AC / GR, FMT, GR CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 7-5/8" 5-1/2" 91.5# 45.5# 29.7# 17# NT-80 NT-95HS 13Cr80 Surface Surface 9760' 9917' 10375' Surface Surface 8628'9243' 8785' 6-3/4" 9-7/8" 260 sx Arctic Set (Approx.) 265 sx Class 'G' 110 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# 13Cr80 9760' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: See Attached Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): H-40 118'30"20" 10-3/4"Surface 3502'13-1/2"1125 sx AS III, 375 sx Class 'G'Surface 3083' 9713' / 8581' Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 118' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028286 319-211 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 81.50 Water Depth, if Offshore:13. N/A Zero API Number: 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 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: N/A 1900' (Approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 8:45 am, May 26, 2020 Abandonment Date 4/25/2020 HEW RBDMS HEW 5/28/2020 xGDSR-5/28/2020MGR29MAY20DLB 06/09/2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Worthington, Aras J Contact Email:Aras.Worthington@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4102 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. 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 corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 9916' 9940' 10017' 10220' 10308' 8784' 8808' 8885' 9088' 9176' Sag River Shublik Sadlerochit - Zone 4 CGL - Zone 3 Base of CGL - Zone 2 Zone 2 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 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. Well Tested? Yes 10308'9176' Top of Productive Interval 9916'8784' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.05.22 15:33:01 -08'00' WWEL L NA ME:A -41 226.Ac i d , Fr ac t u r e, Cem en t Sq u eeze, Et c . Depth Interval (MD) Amount & Kind of Material Used 5126' - 5136' Tubing Punch 2990' 97 Bbls Class 'G' 2495' - 2500' Tubing / Casing Punch ~610' 267 Bbls Class 'G' 600' - 610' Tubing / Casing Punch Surface 65 Bbls Class 'G' ACTIVITYDATE SUMMARY 8/26/2019 ****WELL S/I UPON ARRIVAL**** (Plug & Abandonment) DRIFTED W/ 20' x 2" DUMMY GUNS & 1-3/4" S-BAILER, TAG TOC @ 5,270' SLM (Sample of cement) RIH W/ SLB MEMORY E-FIRE & 10' x 1.56" TUBING PUNCHES ****CONT JOB ON 8/27/19**** 8/27/2019 ****CONT. JOB FROM 8/26/29**** (Plug & Abandonment) PERFORMED SLB MEMORY E-FIRE TUBING PUNCH @ 5,131' SLM (All shots fired) ****WELL LEFT S/I & PAD-O NOTIFIED OS STATUS UPON DEPARTURE**** 8/28/2019 CTU 9 2" 0.156WT Objective: P&A MIRU. Pump 1.375" drift ball. Finish partial bop test. Test in vs out MM. Cut 30' of pipe. ***In progress 8/29/2019 CTU 9 2" 0.156WT Objective: P&A Mu new roll on ctc. Tag at 5349ft. Pump 50 bbls of surfactant wash into IA followed by 160bbls of 9.8 brine. With 9.8ppg brine throughout wellbore, pump 97bbls of 15.8ppg cement into IA & tubing. TOC is 2800ft. IA & tubing have been FP using 9.8ppg brine. RDMO. **Complete** 8/29/2019 T/I/O = 150/90/230. Temp = SI. C&B lines infectivity test (P&A). AL blinded @ CV. Control line = 1030 psi (9 o'clock). Balance line = 580 psi (3 o'clock). Used ~3/4 gallon of hydraulic fluid down balance line locked up and fell off. After third attempt was able to pass a pressure test to 2747 psi loosing 63 psi in the 15 min test. Used ~1/8 gallon to pressure control locked up & would steadily fall off. Made 4 failed attempts to pressure test control line. CT in control of valves upon departure. 11:00 9/4/2019 T/I/O = SSV/0/0. Temp = SI. Attempt to cement C&B Lines (pre P&A). ALP = 1770 psi, SI @ CV. Mixed and sheered cement for 30 minutes. Pumped 1.5 gallons of 14 ppg SqueezeCrete down Balance line before it locked up @ 2500 psi. Pumped ~7 cups of 14 ppg SqeezeCrete down Control line before it locked up @ 2500 psi. Rig down. Hung tags. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 9/8/2019 T/I/O = SSV/Vac/0+. Temp = SI. PT C&B Lines to 2500 psi (pre P&A). ALP = 1770 psi, SI @ CV. Used hydraulic fluid to pressure up control line to 2500 psi. Lost 85 psi in 15 min, showed greater than 5 psi/min loss. Used hydraulic fluid to pressure balance line to 2500 psi, lost 80 psi in 15 min, showed greater than 5 psi/min loss. Rig down. Hung tags. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 9/8/2019 ***WELL S/I UPON ARRIVAL*** (p&a) PRE-STATE TAGGED TOP OF CEMENT W/ 3.0" SAMPLE BAILER @ 2,992' SLM (sample of cement) ***CONT WSR ON 9/9/19*** Daily Report of Well Operations PBU A-41 Daily Report of Well Operations PBU A-41 9/8/2019 T/I/O= 0/0/10 Temp= SI (LRS Unit 42: Assist SL - PLUG AND ABANDONMENT) Pre-AOGCC CMIT TxIA Target Pressure= 2500 psi Max Applied= 2750 psi Pumped 3.3 bbls of Diesel down TxIA to achieve test pressure ***WSR Continued on 09/09/2019*** 9/9/2019 ***CONT WSR FROM 9/8/19*** (p&a) TAGGED TOC @ 2,990' SLM, STATE WITNESSED (bob noble, sample of cement) LRS PERFORMED PASSING STATE WITNESSED CMIT-TxIA PER STATE CRITERIA TO 2500psi (see lrs log for details) DRIFT W 3.70" CENT, 2-1/2" DUMMY GUN, 3.70" CENT, TO 2,700' SLM TAG SVLN W/ 3.85" GAUGE RING @ 2,160' SLM / 2,182' MD (22' corr) RAN SLB EFIRE W/ 5' OF PERF GUNS (6 shots per foot). PERF FROM 2,495' MD- 2,500'MD (communication w/ ia only) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 9/9/2019 ***WSR Continued from 09/08/2019*** CMIT-TxIA **PASSED** to 2534/2538 psi. Target pressure=2500 psi, Max applied pressure=2750 psi. 1st 15 min T/IA lost 104/103 psi, 2nd 15 min T/IA lost 58/58 psi, 3rd 15 min T/IA lost 40/40 psi. Total loss of 202/201 psi in 45 min test. Passed per State Witness Bob Moble. Bled T/IA down to 17/21 psi. Bled back 1.7 bbls. AFE Sign hung on well. FWHP=16/19/9 Slickline still on well upon departure. 9/11/2019 T/I/O = SSV/300/0+. Temp = SI. PT C&B Lines to 2500 psi ***PASSED*** (pre P&A). ALP = 1770 psi, SI @ CV and blinded. Used hydraulic fluid to pressure up control line and PASSED to 2522 psi, lost 50 psi in 15 min. Used hydraulic fluid to pressure balance line and PASSED to 2532 psi, lost 73 psi in 15 min. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 9/27/2019 T/I/O= 164/66/3 Temp= SI OA thaw (Plug & Abandone) Road to location ***Job continued on 09/28/2019*** 9/28/2019 ***Job continued from 09/27/2019*** Thaw OA (Circ out well, P&A) Pumped 4 bbls neat meth down IA and OA to check for communication. Thaw OA w/ 5 bbls 60/40 meth spear down IA followed by 360 bbls 160* 1 % KCL down IA up TBG taking returns to A-10 FL. Circulate IA & OA w/ 190 bbls 9.8 brine down IA w/returns up OA ( 110 bbls going into open top, 80 bbls going down A-10 FL.) Circulate IA & TBG w/ 36 bbls 9.8 brine down IA w/ returns up TBG. Freeze Protect OA w/ 8 bbls 60/40 meth down OA w/returns up TBG. Freeze Protect Tubing & IA w/ 20 bbls 60/40 down IA w/returns up TBG, U-Tube T X IA for one hour for FP. Freeze Protect A-10's Flowline w/ 52 bbls crude. FP surface lines w/ 2 bbls 60/40 Well and choke skid shut in upon departure. FwHP's 13/15/239. Daily Report of Well Operations PBU A-41 10/16/2019 T/I/O= 0/0/194. LRS Unit 72 Circ-out freeze protect from OA (PLUG AND ABANDONMENT) Bled gas off the OA. Pumped 15 bbls of 60/40 Meoh, 50 bbls of hot freshwater + surfactant and 187 bbls of 9.8 Brine into the TBG wihile taking returns to OT tank. Pumped 40 bbls into the TBG before returns started coming from the OA. Pumped a total of 252 bbls into the TBG while getting 210 bbls of returns from the OA. Took sample of OA returns upon pump shut down. Freeze protected the surface equipment with 5 bbls of 60/40 Meoh. SV, SSV and WV are closed. MV is open. IA and OA are OTG. All 1/4 turns for cement lines and choke skid are closed. WFO notified of well status upon departure. Final T/I/O= 0/14/0 10/17/2019 SLB Fullbore pumping crew. (Objective: Plug and Abandon TxIAxOA from 2500' to surface) MI/RU/PT SLB pumpers. Pumped 18 bbls 60/40 down TBG taking returns from the IA and OA to verify flow paths/returns OTT. Pumped 10 bbls FW spacer and 165 bbls 15.8 ppg Class G cement down the TBG taking returns from the OA, ~ 85 bbls returns from the OA, but no cement. Notify town. Est TOC in OA @ 1,611' MD Pumped 102 bbls cement down the TBG taking returns from the IA, ~45 bbls returns from the IA, but no definitive cement. Possibly a trace of cement in OTT, tried to get sample from IA casing valve, IA on a vac. Notify town. Est TOC in IA @ 440" MD Pumped 7 bbls 9.8 ppg NaCl and 2 bbls 60/40 down the TBG taking returns from the IA to spot TOC in TBG @ ~600'MD. Wash up lines, call grease crew, hang tags, notify pad op. FWHP=vac/vac/0+ 15.8 ppg Class G Cement in TxIAxOA Est BOC TxIAxOA = 2500' MD / 2330' TVD Est TOC in TBG = 600' MD/ 600' TVD Est TOC in IA = 440' MD / 440' TVD Est TOC in OA = 1611' MD / 1550' TVD 12/31/2019 ***WELL S/I UPON ARRIVAL***(plug and abandonment) RAN 10' x 2,50" DUMMY GUN TO 377' SLM (unable to get deeper, no sample) RAN 2.25" CENT, 1-3/4" SAMPLE BAILER TO 836' SLM (sample of cement) RAN 10' x 2.00" DUMMY GUN W/ 1-3/4" SAMPLE BAILER TO 836' SLM, WORK TIGHT SPOTS FROM 380' SLM TO 387' SLM RAN 10' x 2.00" DUMMY GUN W/ 2.30" GAUGE RING, WORK TIGHT SPOTS (no improvement) RAN 2.30" GAUGE RING TO 400' SLM (no issues) MADE VARIOUS SIZE BRUSHES AND GAUGE RINGS IN ATTEMPT TO CLEAR UP RESTRICTION (see log) RAN 10' x 2.50" DUMMY GUN (2.79" max od) TO 380' SLM (sticky, unable to pass) RAN 10' x 2.00" DUMMY GUN (2.29" max od) TO 400' SLM (easily work by restriction) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** but no cement. Daily Report of Well Operations PBU A-41 2/21/2020 ***WELL SHUT IN ON ARRIVAL*** PERFORATE TUBING FROM 600' -610' W/ 2" BH HMX GUNS. CCL TO T.S. = 2.8'. CCL STOP @ 597.1'. CONFRIM COMMUNICATION TO OA FROM TUBING ***JOB COMPLETE*** DSO NOTIFIED*** 3/1/2020 T/I/O= 80/88/78 Temp= S/I Circ-out (PLUG AND ABANDONMENT) Arrive on location, Spot equipment, RU and PT surface lines, ***WSR Continued on 03-02- 20*** 3/2/2020 ***WSR Continued from 03-01-20*** Temp= S/I Verify flowpath pre surface cement (PLUG AND ABANDONMENT) Pumped 40 bbls of 9.8 ppg NaCl down TBG with OA returns to production via A-10 outlet FL. Swapped to take IA returns, pumped 25 bbls 9.8 ppg NaCl, 10 bbls 60/40 for surface FP. U-tube TxIxO for 30 min. TxIxO Wellbore fluid packed with 9.8 ppg NaCl with 60/40 FP from surface to 100'. Freeze protected outlet flowline with 5 bbls 60/40, 52 bbls crude, Pumped .1 bbl 60/40 down TBG to bring T/I/O up to 343/358/344, Monitored for 15 min FWHP= 27/39/31 3/8/2020 SLB Cementers - TxIxO Surface Cement Plug (PLUG AND ABANDONMENT) initial T/I/O = 0/0/0. LRS verified circulation flow path and verfied WV holding. SLB pumped 10 bbl freshwater spacer, 44 bbls 15.8 ppg class G cement down TBG with OA returns to OTT. SLB pumped 21 bbls 15.8 ppg class G cement down TBG with IA returns. Clean cement returns from both IA and OA. Flushed and freeze protected surface lines. All tree valves and casing valves shut in and flagged. Pad Op notified. FWHPS = 0/0/0 TOC in TxIxO at surface BOC in TxIxO at 600' MD 3/8/2020 T/I/O=-0/0/0 Temp= S/I LRS Unit 42-Assist Cement Pumping. (Plug And Abandonment) Pumped 3 bbls 60/40 to confirm communication down TBG and up IA/OA. Pumped 5 bbls 60/40 to FP surface lines. Pumped an additional 4 bbls to clear cement from reverse out skid. Valve Positions=SV,WV,SSV,IA,OA closed MV Open FWHP= 0/0/0 4/23/2020 *** A-41 P&A *** Excavated to a depth of 15.5'. Pad elevation @ 47.5'. Tundra elevation @ 38.5'. Bottom of excavation @ 32'. Set Shoring Box. ***JOB IN PROGRESS*** 4/24/2020 *** A-41 P&A Job continued *** Set Wach Saw 30" from bottom of excavation. Began cut @ 1100. Finished cut @ 1252. Removed WH. State scheduled for inspection. ***JOB IN PROGRESS*** 4/25/2020 ***A-41 P&A Job continued*** State inspector Brian Bixby signed off on cement and marker plate. Marker plate welded to cut casing. ***JOB IN PROGRESS*** 4/26/2020 ***A-41 P&A Job continued*** Removed Shoring Box and Rig Mats. Backfilled and deliniated excavation. ***JOB COMPLETE*** MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2e1 ( �S� �� DATE: April 25, 2020 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandonment Petroleum Inspector PBU A-41 BPXA , PTD 1941580; Sundry 319-211 04/25/2020: 1 met with the BP Well Site Leader Jon Arend and looked over all the paperwork for the P&A. I verified the correct information was on the marker plate including the correct PTD and API numbers. I then verified there was hard cement to surface on all strings using a 5 -foot bar to hit the cement in multiple locations on ALL stings of pipe. The marker plate was welded. There was also about a 2.5 -foot split in the conductor that had a strip of metal welded on it. Attachments: Photos (4) 2020-0425_Surface_Abandon_PBU_A-41 bb.docx Page 1 of 3 2020-0425_Surface_Abandon_PBU_A-41_bb.docx Page 3 of 3 STATE OF ALASKA ALASKA OIL AND OAS CONSERVATION COMMISSION eC� Q f ��g REPORT OF SUNDRY WELL OPEN RATIOS JC 1. Operations Performed 11 � pp�� Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operationg'ify(gp7�+ 0 ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 27 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 21 Exploratory ❑ 5. Permit to Drill Number. 194-158 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-22530-00-00 7. Property Designation (Lease Number): ADL 028286 8. Well Name and Number: PBU A-41 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10375 feet Plugs measured 2800, 9740 feet true vertical 9243 feet Junk measured None feet Effective Depth: measured 2800 feet Packer measured 9713 feet true vertical 2530 feet Packer true vertical 8581 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 38-118 38-118 1490 470 Surface 3464 10-3/4" 38-3502 38-3083 4560 1730 Intermediate 9882 7-5/8" 35-9917 35-8785 8180 5120 Production Liner 615 5-1/2' 9760-10375 8628-9243 7740 6280 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 32-9760 32-8628 Packers and SSSV (type, measured and 4-1/2 Baker SABL-3 Packer 9713 8581 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well. operation: Suspended Subsequent to operation: 14.Attachments: (reymred per20BAc25.o70.25.071.&25283) 15. Well Class after work: Daily Report of Well Operations E1 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Pnnted and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP R1 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authorized Name: Lastufka, Joseph N Contact Name: MontgomeryTravis J Authorized Title: f:NM Specl lis Contact Email: Tmvis.MontgomerV0bp.00m Authorized Signature: Date: A I1 1 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 A4 Y11q��-ify R BDMS±�iJSEP 1 12019 Submit Original Only Daily Report of Well Operations PBU A-41 T/I/O = SSV/30/0. Temp = SI. Pre suspended well inspection. ALP = 1810 psi, blinded @ CV. McEvoy well head and CIW tree (appears to be in good condition). Spray in liner installed in cellar, 1" of dark fluid @ 12 o'clock position (strong odor of hydrocarbons). Trash & debris removed from well house and cellar. Pits have several feet of water with no sheen. No puddles present on the pad. Signage installed on well house. Area surrounding the well house is dry, level gravel. 8/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:00 T/I/O = S6V/30/0. Temp = SI. Purge C&B / Chemical lines with hydraulic fluid. AL is blinded and SI @ CV. Control line pressure = 770 psi, Balance line = 860 psi. Unable to inject down balance & control lines, both lines took -1 gallon of fluid and locked up & would fall off at to high of rate for test. Cellar has spray in liner with -1" of dark fluid in it, measured at the 6 o'clock position, next to conductor. Flutes are full of fluid. Tags hung. 8/4/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 T/I/O = SSV/40/0. Temp = SI. WHPs (AOGCC Witnessed Suspended well inspection). State witnessed by Brian Bixby. Wellhouse clear of any trash and debris. Took pics. 8/17/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 10:15 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Y Well Name: A-41 Field/Pool: Prudhoe Bay/ Prudhoe Oil Permit # (PTD): 1941580 API Number: 50-029-22530-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 3/18/2011 Surface Location: Section: 31 Twsp: 11N Range: 13E Nearest active pad or road: A Pad Access road Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Pad or location surface-EQ P. Location cleanup needed: -�� Pits condition : ,q Surrounding area condition: —lea Water/fluids on pad: ftp Discoloration, Sheens on pad, pits or water: Samples taken: None Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Glen Cellar description, condition, Rat Hole: NZA Wellhouse or protective barr Well identification sign: Tubing Pressure (or casin( Annulus pressures: Wellhead Photos taken (# fluids: f t � r % Work Required: None Operator Rep (name and signature): Josh Prowant— AOGCC Inspector: _110 , 0t4LJ Other servers: None Inspection Date: 8/17/2019 0146V Other Notice Date: 8/16/2019 Time of arrival: 16 00 Time of Departure:�Q� Site access method: Access road D-'2f1APg1 t`.: 121g C_O_PA Y -01C "� Lt1f3. Goa$ Y -17B A 0.31 ,4 G }�,...: A-25 �. A-28 i A-44 A A -08I - A -25A 0.09 'V'17 Y-01 g A-29 I � C-348 _ A A-07 x 0.4-43 28 TA 2';, I M-02 r Y15 J A V A -213A �I -45 B-17 ''Y�21tPB1- Y -15A A-11 7 A-04 A-13 'f-0, A-2fLh .. .+L -45P81 t A -24A . I. A-2t�1PB1 G A -12A. - A -,ti V A-0-'� ' � A-35 P��yy f %D ^� f if �I 4 -?4 -- 2 _.__6-24 C A -33A A a4A A-10 .^ Y-2$ C .?x-33 ��jl'/p� �i A -a9 6 / 1 1 ( 1D - I A -09A " �. Y-07 .. ? A-23 4 W Y-34 A -27A A�01A A-08 R-ia* Bi A- Y -0, Y -10B %, A-19 A-32 Y-10BF'B2 - A-40 A -05A A -31 A. - Y-3 '- A-18 0 4---OA - Y-37APB4-' " A-1£1PB1 Y-05gP81 B-33 0 Y -35A l- _ Y-WAPB2 '�✓ Y -a58 I A PL4i'Fi Pot -D1 2 - 1 _. 1. Y -0$A '. �:� A -18A A30 Q A-37 J -y- ��-32LI A -17A A-30APB9'A-30Li y �✓ A-30APB-- a a P,. 4-1/16' CNV WELLHEAD = 11' 5M FMC UNIVERSAL ACTUATOR= BAKER OKB. ELEV = 81.5' BF. ELEV = 46-86 KOP = 757 Max Angle= 41'0264(r Datum MD = 10013' Datun TVD = 8800' SS SUSPENDED A-41 TOP OF CEMENT AGGED 0829/19 2800' tOJ/4" TBG, 45.5#, NAD BTC, D =10.050" 3602' 412" TBG PUNCH 0827/19 6126' - 6136' PRODUCTION CASING LEAK (03125/11) 6860' Minimum ID = 3.813" @ 2182' 4-112" HES SSSVN TEG, 12.61t, NSCT, 13 -CR -80, bpf, D = 3.958" BKR TACK SLV, D = 5.75" 1�m� D = 6.875' PERFORATION SUMMARY REFLOG: BHCS 01/05/95 ANGLEATTOP PERF: 1"@ 9920' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz I SHOT SOZ 3-3/8" 6 9920-9940 C 1228/00 OPEN 3-3/8" 6 10020 - 10060 C 1228/00 2-7/8" 6 10083 - 10100 C 1228/00 OPEN 2-7/8' 6 10107-10115 C 12/28/00 2-7/8" 6 10121-10127 C 1228/00 OPEN PBTD 10296' 5-12" NSCC LNR 17#. 13CRA0, 10375' .0232 bpf, ID = 4.892' C SAFETY NOTES: 4-1J2" 8 5-1/2' CHROME78G "' 2182' —t4-12' FES HXO SSSVN, D= GAS I FT MANMR C ST MD TVD OB/ TYPE VLV LATCH PORT DATE 7 3384 2988 38 KBMG OPEN BK -5 - 03/09/11 6 5912 4998 37 KBMG OPEN BKS - 03/09/11 5 7158 6048 21 KBMG BK -5 4 7918 6787 5 KBMG OPEN BK -5 - 03/09/11 3 8532 7400 1 KBMG BK -5 2 9024 7892 1 KBMG OPEN BK -5 - 03/09/11 1 1 9559 1 8427 1 1 KBMG I OPEN BK -5 - 03/09/11 HES X NP, ID = X 4-12' BKR S, 14-12" FES X NP, D=3.813" I 974W I { 9760' 9748'13MDTTLOGON??? 1 9773' 1 Ir-olio-x5-12"BKR LN2 PKR, D=4.813" 1 BKR LN2 URIC I ntv t1Y COMMENTS DATE REV BY COMMENTS PRUDHOE BAYUNIT WELL A-41 PERMIT No: "1941580 APINo: 50-029-22530-00 SEC. 35, 11 N, R1 3E, 137T FNL & 920' FEL NOTE BP Exploration (Alaska) 01/08/85 N28E ORIGINAL COMPLETION 03/13/14 TAWMD ADDED SAFETYNOTE 07/04/01 CHIKAK CORRECTIONS 02/11/16 TK/JMD REMOVED SAFETY NOTE 08/05/02 RLM GLV UPDATE 0829119 LLG/JMD TBG PUNCHES 0827/19 02/02/10 JLW/PJC CSG CORRECTIONS 09/09119 FaJMD TAGGED TOC (0829/19) 03/11/11 SWC/PJC PULL GLVS /CMT PLUG 03/09/1 09/09/19 JNUJMD ADDED BF ELEV & SUSPENDED 0326/11 RRW/PJC CEMENT TBG &[A(0323/11) 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Ip/ S� DATE: September 9, 2019 P.I. Supervisor l 6 SUBJECT: Well Bore Plug & Abandonment PBU A-41 FROM: Bob Noble BPXA _ Petroleum Inspector PTD 1941580; Sundry 319-211 Section: 35 - Township: 11N Range: 13E Drilling Rig: n/a Rig Elevation: n/a Total Depth: Operator Rep: Gery Boyles Suspend: Casing/Tubing Data (depths are MD) Conductor: 20" O.D. Shoe@ Surface: 10 3/4" 0, D. Shoe@ Intermediate: 7 5/8" 0. D. Shoe@ Production: Feet 0. D, Shoe@ Liner: 51/2" 0. D. Shoe@ Tubing: 41/2" - 0. D. Tail@ Plugging Data: Test Data: 118 Feet 3502 Feet 9917 Feet Feet 10375 Feet 9760 Feet Meridian: Umiat Lease No.: ADL 028286 Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Balanced 5131 ft MD 2990 ft MD Wireline tag 2538 - P OA 10 10 10 10 " Initial 15 min 30 min 45 min Result Tubing 2736 2632 2574 2534 IA 2739 _ 2636 2578 2538 - P OA 10 10 10 10 " Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Wireline bailer had what looked to be contaminated cement. Attachments: none rev. 11-28-18 2019-0909_Plug_Verification_PBU_A-41 _bn Suspended Well Inspection Review Report InspectNo: susBDB190817155439 Date Inspected: 8/17/2019 Inspector: Brian Bixby - Well Name: PRUDHOE BAY UNIT A-41 Permit Number: 1941580 Suspension Approval: Sundry 4 311-007 Suspension Date: 3/18/2011 Location Verified? W If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 8/16/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? ❑D Photos Taken? ❑D Well Pressures (psi): Tubing: Fluid in Cellar? V] IA: 40 BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Good, Flowlines are still attached. Condition of Cellar Oil in cellar, Josh mentioned he thinks there is a OA by surface leak. Needs cleaned and reinspected. Surrounding Surface Condition Good Comments Wellhead is Locked Out so we didn't get a tubing pressure. Location was verified by pad As -Built Map. Supervisor Comments Reinspection required (oil in cellar). Sundry 319-211 approved 5/3/2019 for P&A. Photos (3) attached. Wednesday, September 11, 2019 Suspended Well Inspection — PBU A-41 PTD 1941580 Photos by AOGCC Inspector B. Bixby 8/17/2019 2019-0817_Suspend_PBU_A-41_bb.docx Page 1 of 2 2019-0817_Suspend_PBU_A-41_bb.docx Page 2 of 2 10,000,000 1,000,000 L Y C C0 C CL 100,000 U U O N 10,000 N w O O S LL `0 1,000 u Z 3 u v m 100 N 3 O L F 10 1 Jan -1990 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT A-41 (194-158) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates p • r: 1111111111111111111111,111111,III■111111,IIIIIIII�III■IIII■111111,111111'11111.111111111111111111111111111■IIIIIIII� 't M ■■■■■■■■■W■ ■■■■ ■■mmm ■■ m�mm■ Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 -- Produced Gas (MCFM) a GOR . Produced Water (BOPM) —, Produced Oil (BOPM) 10,000,000 W d 1,000,000 O M O 100,000 0 O 3 S 10,000 O 1,000 N 0 f m m 100 m O 3 10 � 1 Jan -2020 5 P R EADSH E ET_1941580_P B U_A-41_P rod -I nject_Cu Nes-We I I_Oi I—V 120_20190424.x1sx 4/24/2019 11t:I4r Lw + LI STATE OF ALASKA IU'L 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMI, N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed {'^- c f`-�' Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ElPerforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well m 2. Operator Name. BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-158 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6 API Number: 50-029-22530-00-00 7. Property Designation(Lease Number): ADL 0028286 8. Well Name and Number: PBU A-41 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10375 feet Plugs measured 9740 feet true vertical 9243 feet Junk measured feet Effective Depth: measured 5331 feet Packer measured See Attachment feet true vertical 4533 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface Intermediate Production 9884 7-5/8"29.7#NT-95 33-9917 33-8785 8180 5120 Liner 615 5-1/2"17#13Cr80 9760-10375 8628-9243 7740 6280 Perforation Depth: Measured depth: 9920-9940 feet 10020-10060 feet 10083-10100 feet 10107-10115 feet 10121-10127 feet 10250-10280 True vertical depth. 8788-8808 feet 8888-8928 feet 8951-8968 feet 8975-8983 feet 8989-8995 feet 9030-9031 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 32-9758 32-8626 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): iCl'11 NNE 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: 0 8238 8394 1211 390 Subsequent to operation: 0 0 0 0 0 14 Attachments'(required per 20 AAC 25 070 25 071.a 25 2831 15 Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Il Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature d,tJ a,1 C 1/4-- Phone +1 907 564 4424 Date 7/31/15 It-r/ /3 I -, I „� a) co 0_ a) O• ctC w C O U• d -6 co• J (0 co 0• (I) J 43 a) Y Y (6 (0 Ca m 4"0 N N V � t V Q > � �ci N < w co C co a ca N oCO (.0 —NC2N- V rn rn ca a a, ww C.Y Y Q Q d E Z `r Q Q U) _ _ It / \ \ % .§ \ \ / \ < / _2 a q O▪ ct z e \ - If C \ § I ƒ $ 2 E as < co § b %• / E \ \§ H II -oS � . � \ + « /% ® n 3 U ¥ O co % » "t % ca II 2 .® E Q = e Ct �S8 />, kW g.CU = u a CI / 2 _ a ,• . E .g o b 0 \ .q 2 „ > / O c i--- -o $ z w \ ,_ y a \ \ co 0 6 < Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT A-41 Field/Pool: PRUDHOE BAY/ PRUDHOE OIL Permit#(PTD) 1941580 API Number: 50-029-22530-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended 3/18/2011 Surface Location: Section 35 Twsp: 11N Range: 13E Nearest active pad or road: A-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, clean Pad or location surface: Dry, flat gravel Location cleanup needed: Clean Pits condition Filled with Water Surrounding area condition: Clean Water/fluids on pad None Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition: Clean Photographs taken (#and description): 3: Wellhouse front, Wellhouse back, Pit Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings,where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC Wellhead, Cameron Tree, Flowline attached, AL line attached but blinded, Gauges (operational). Vales are in good working condition. Cellar description, condition, fluids: Clean water in cellar with no sheen Rat Hole: N/A Wellhouse or protective barriers: Wellhouse Well identification sign Attached to wellhouse Tubing Pressure (or casing if no tubing): SSV Annulus pressures: IA= 100 psi, OA=50 psi Wellhead Photos taken (#and description): 4: Wellhead/Tree, Wellhead right, Wellhead Left, Tree right Work Required None Operator Rep(name and signature) Kevin Parks ��'�^ ffJ '1 AOGCC Inspector: Bob Noble Other Observers: Matthew Do Inspection Date: 6/28/2015 AOGCC Notice Date: 6/26/2015 Time of arrival: 12:30 PM Time of Departure: 1:10 PM Site access method Truck • W 13r i 0 O ( O D D cr0 0W T 0 0 m 0 D m S P 3 F D D m ma o �N N fa N n0 0. • ` Illt4 c K to 2 3 n"E, m c� o f°3 I m d A m�. o m c m o c -o N m 0 d a v a c m o0 m m 1 5 0 c Fe v 'm m m 5 o D � iJ D N 0 A r' > > a > D D tiit D D D N NWJ A N N t11 N N N C O r wJ N A In a'• - CO aO a +W + + + D + + + oA D D D D D v W D 4NNNNND X D N w D W D y D D w w co COIn o DD 7 :0,L. 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TREE-=„. 4-1/16"CMV V1ELLFEAD= 11",5M FMC UNIVERSAL S, i'NOTES: 41/2"&5-1/2"CHROME TBG "' O IN WEATHER NSMITER ACTUATOR= BAKER Al-4 1 MONITORING SHACK4MUST BE TURNED OFF PRIOR TO OKB.ELEV= 81.5' BF BEV= 52.9WELL WORK INVOLVING NON RADIO SAFE KOP= 752' EXPLOSIVES CAN BEGIN-CONTACT PAD OPERATOR Max Angle= 41 @ 2640' _i [ Datum MD= 10013' 2182' 4-1/2GAS LFT"l HXMAO SSSVNDRELS N D=3.813" Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10-3/4"TBG,45.5#,N-80 BTC,D=10.050" -i 3502' 7 3384 2988 38 KBMG OFBd BK-5 - 03/09/11 6 5912 4998 37 KBMG OF '1 BK-5 - 03/09/11 5 7158 6048 21 KBMG BK-5 TOP OF CEJuEI•ET(TAGGED 03123111) H 5331'SLM •• k••4 l••• 4 7918 6787 5 KBMG OFEN BK-5 - 03/09111 PRODUCTION CASING LEAK(03/25/11) — 5850' 1,,•".•••41,j �,•4 ► 3 8532 7400 1 KBMG BK-5 i• ►•••♦ • .••�4►•�•�•�•�•�•� 2 9024 7892 1 KBMG OPEN BK-5 03/09/11 Minimum ID = 3.813" @ 2182' .••4•�•�•••�•�•• 1 9559 8427 1 KBMG OFEN BK-5 - 03/09/11 4-1/2" HES SSSVN •• i,•••••• .•4.••••••••• ••••••••( 9701' 41/2"I-ES X NP,ID=3.813" •• •••4, •�•�1,••••1040 t,•,► ��� 9713' -H 7-5/8"X 4-1/2"BKR SABL PKR,ID=3.875" ►�i�000 •••••••4 9737' --f 4-VT HES X NP,ID=3.813" •••• 1 00, 9740' - 33/8"BKR BP(SET 12/28/00) 4 1/2"TBG,12.6#,NSCT,13-CR-80, H 9758' I 9749' H41/2"HES XN�,D=3.725' .0152 bpf,D=3.958" TOP OF BKR TEBACK SLV,D=5.75" -f 9760' \\4I 9760' H41/T WLEG,IS=3.958" 9748' H 6J4)TT LOG ON??? 976T H7-5/8"X 5-1/2"BKR LNR PKR,ID=4.813" . , 9773' --17-5/T X 5-1/T BKR LNR HGF,D=4.875" 7-5/8"CSG,29.7#,NT-95-HS NSCC, —I 9917' .0459 bpf,ID=6.875" I PERFORATION SUMMARY REF LOG: BHCS 01/05/95 I ANGLE ATTOP FH F: 1`@ 9920' Note:Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 9920-9940 C 12/28/00 3-3/8" 6 10020-10060 C 12/28/00 I 2-7/8" 6 10083- 10100 C 12/28/00 2-7/8" 6 10107- 10115 C 12/28/00 I 2-7/8" 6 10121- 10127 C 12/28/00 PBTD 1 10295' 4.0..1 5-1/2"NSCC LNR, 17#,13-CR-80, --{10375' '�'.'.'.'.'.'., .0232 bpf,ID=4.892" DATE REV BY COMMENTS DATE REV BY COMEtsITS FRUDHOE BAY UNIT 01/08/95 N28E ORIGINAL COMPLETION 03/13/14 TAO/JMD ADDED SAFE]Y NOTE WELL: A-41 07/04/01 Ct-VKAK CORRECTIONS PERI No '1941580 08/05/02 RAM GLV UPDATE AR No: 50-029-22530-00 02/02/10 JLW/PJC CSG CORRECTIONS SEC.35, 11N,R13E, 1373'FM_&920'FEL 03/11/11 SWCJPJC PULL GLVS/CMT RUG(03/09/11) 03/26/11 RRW/PJC CE STET TBG&IA(03/23/11) 1 BP Exploration(Alaska) • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/29/15 Inspector: Bob Noble Operator: BPX • Well Name: PBU A-41 Oper.Rep: Matt Do PTD No.: 194-158 - Oper.Phone: _ 659-5102 Location Verified? Yes Oper.Email: If Verified, How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 03/18/11 Date AOGCC Notified: 06/26/15 Sundry No.: 311-007 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 100 OA 50 SCANNED AUG 1 4 2015, Condition of Wellhead: Location was verified with a pad map.SSV was closed so tubing psi was not obtained.NL line was attached but blinded.Flowline was attached.No signs of drips or leaks.Lood to be clean H2O in the cellar with no sheen. Condition of Surrounding Surface Location: Wellhed was protected with a wellhouse.Good clean gravel on the pad. Follow Up Actions Needed: none Comments: none Attachments: Photos(3) REVIEWED BY:AI5 Insp.Supry 6(36/15 Comm PLB 12/2014 2015-0629_Suspend_PBU_A-41_bn.xlsx w— V ° N zJ_ Q MIN W H Z , ,u. _v ¢ Elm 4 G W a J 1.1. v- m V I ICCIC • ,• 1 N • W fi 1 •=Ci) - Q 8 F M O > °g w 4 8 C N k U QI Q $ n o 'UO G C W C O Q r 1- GO G> Q C< W W z m 6a cr a • oa W ' = a a ic �ooa c I= U ao 00 °. -ooo Q cn a4 ,—, R"Q O N o — v, O Q� to a.) D H .c N on . •Titt t, \,„,i . ,, � t .Illi' 111 � tw ::•:,,.,„_ , •1 'jos ' i`s,. ' ' 1I 1 111 • �� .. :. .7. I mow.. v q� ' is iillt....: \. / � ti- t ' cil Y r -".ilf; v 1.--- ,,, , 4,„. $$4.4.4 ., . .., 0. is 44$ 4, 0 48 $.4.4 ., . . . .,,,ts .. 4. 4. . 0... .01 % %\ N N a 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. t~ C~ --I~ ~ 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 D~~ncent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/25/11 Inspector: John Crisp Operator: BPXA Well Name: PBU A -41 Oper. Rep: Jeremy Vanorder PTD No.: 194 -158 Oper. Phone: 659 -5766 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 03/18/11 Date AOGCC Notified: 06/21/11 Sundry No.: 311 -007 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 60 Photos Taken? Yes IA 30 - OA 30 Condition of Wellhead: Good. Surface casing mandrel hanger landed in conductor. Spray in liner in cellar around conductor. Slight oil residue in cellar. AL line to IA with blind installed. 800 psi on AL line. Flow line installed with 80 psi on line. Condition of • Surrounding Surface Same as the other wells on PBU A Pad. Well on the Pad in the well row with wellhouse installed. Location: Follow Up Actions none Needed: Attachments: Photos (11) REVIEWED BY: Insp. Supry 3 (( (( Comm or r 3 >)3'`: PLB 08/2010 201 1 -0625 Suspend_PBU_A- 41jc.xls • • Suspended Well Inspection — PBU A -41 PTD 1941580 Photos by AOGCC Inspector J. Crisp A IN Well Sign I WELL NAME A.41 POS OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50029- 22530.0040 SUR. LOCATION NE 1.4, Sec. 35. T11N, R138 - -- ORLLNG PERMIT 194 -158 alw „..1.10., ___________ Well house " „.„. -- PBU A -41 Suspended Well Inspection 6 -25 -11 jc 1 ' . • 0' ^sr aw - r Well pad adjacent , g t4 to PBU A -41 1 - ' -�0.tl. Flowlines i Fl owirosiliii Adjacent reserve pit _ . - - t . A ,.: RL , ° e A' ,..„ 4 1 . i PBU A -41 Suspended Well Inspection 6 -25 -11 jc 2 • p j Backside of wellhouse M._ . 4. ill :40 * . 116111116 •M Well cellar !t til R . i4....,„,..., �' t R . i T \ '$' e , �'- � � PBU A -41 S- riser; LPS insulation .a, j r : PBU A -41 Suspended Well Inspection 6 -25 -11 jc 3 • I �` - %ir It ,_ _ t. "'11 16 '' � ' PBU A -41 ��-- production tree IN . Plirr • l �ri a 1 I 4411 I` / Wellhead work platform 1: ' 141 IP, ''. • 644' ' ' ., ., „'.... , * 1 ' Ns ,.. ': .. '',,, itl lip it / ' • • .., , 'c , ' S � +t om♦ � OP L . 1 I MIA . i , . PBU A -41 SSV 44 14 . Y- r,i r tom .. z 4 PBU A -41 Suspended Well Inspection 6 -25 -11 jc STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ig REPORT OF Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IN Exploratory ❑ -- 194 -1580 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 ., 50- 029 - 22530 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028286 PBU A-41 10. Field /Pool(s): , PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10375 feet Plugs (measured) 9740, 5331 TOC feet true vertical 9243.08 feet Junk (measured) None feet Effective Depth measured 5331 feet Packer (measured) 9713 feet true vertical 4532.62 feet (true vertical) 8581 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 35 - 115 35 - 115 1490 470 Surface 3468' 10 -3/4" 45.5# N -80 34 - 3502 34 - 3083 5210 2480 Production 9884' 7 -5/8" 29.7# NT -95HS 33 - 9917 33 - 8785 8180 5120 Liner 615' 5 -1/2" 17# 13CR80 9760 - 10375 8628 - 9243 7740 6280 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ vl G Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 32 - 9758 32 - 8628 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SABL Permanent Packer 9713 8581 _�,, F. .' 12. Stimulation or cement squeeze summary: ,. i; ' ° ��(ti Intervals treated (measured): Mill#= 2,4.1411illSSIOf Treatment descriptions including volumes used and final pressure: { ; ' g; 'ate ?. 9t. ..., ra,,� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ p WAG❑ GINJ ❑ SUSPQ -' 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: NA Contact Joe Lastufka Printed Name e .L Lastu I Title Petrotechnical Data Technologist Signatur: • MIK Phone 564 -4091 Date 7/20/2011 NBDMS JUL 2 O WI Form 10 -404 Revised 10/2010 wit Submit Original Only A-41 194 -158 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base A-41 1/22/95 PER 10,020. 10,060. 8,888.1 8,928.1 A-41 7/8/97 APF 9,920. 9,940. 8,788.11 8,808.11 A-41 7/27/98 APF 10,083. 10,100. 8,951.1 8,968.1 A-41 7/27/98 APF 10,107. 10,115. 8,975.1 8,983.1 A-41 7/27/98 APF 10,121. 10,127. 8,989.1 8,995.1 A-41 11/26/00 BPS 9,740. 9,750. 8,608.12 8,618.12 A-41 11/28/00 BPP 9,740. 9,750. 8,608.12 8,618.12 A-41 12/28/00 BPS 9,740. 9,741. 8,608.12 8,609.12 A-41 3/18/11 SQZ 5,331. 9,740. 4,532.62 8,608.12 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 1 • • Prudhoe Bay Unit Well A -41 PTD 1941580 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU A -41 on 6/26/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector John Crisp witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 'A mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • PBU A -41 suspended on 3/18/2011 after unsuccessful attem.ts to regain operable status. ✓ • PBU A -41 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The producing formation is isolated by cement in the tubing. The cement in the casing also covers a production casing leak. • Future work will place additional cement plugs in the tubing and casing strings. AWO 7/8/2011 • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: A - -41 Field /Pool: Prudhoe Bay /PBU Permit # (PTD): 1941580 API Number: 500292253000 Operator: BPXA Date Suspended: 3/18/2011 Surface Location: Section: 35 Twsp: 11N Range: 13E Nearest active pad or road: A -Pad� Take to Location 'Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good _ �- Pad or location surface: Clean dry gravel Location cleanup needed: No Pits condition: Clean water Surrounding area condition: Good Water /fluids on pad: None _ Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 2 photos, Wellhouse front, Wellhouse back Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC wellhead, Cameron tree - Both in good condition Cellar description, condition, fluids: Spray in secondary containment liner, 3" water w/ very light sheen Rat Hole: None Wellhouse or protective barriers: Wellhouse Wet identification sign: Yes Tubing Pressure (or casing if no tubing): 60 psi Annulus pressure: IA - 30 psi, OA - 30 psi Wellhead Photos taken (# and description): 3 Photos - Wellhead #1, Wellhead #2, Tree Work Required: None Operator Rep (name and signature): Mehreen Vazir AOGCC Inspector: John Crisp Other Observers: Jon Arend Inspection Date: 6/26/2011 AOGCC Notice Date: 6/21/2011 Time of arrival: 11:15 Time of Departure: 12:15 Site access method: Truck ___ TREE = • 4- 1116" CW • SAFETY NO�4 -1/2" & 5 -1/2" CHROME TBG * ** WELLHEAD = 11 ",5M FMC UNIVERSAL KER A MONITORING SHACK MUST BE TURNED OFF IN WEATH ACTUATOR= BAKER PRIOR ACTU KB. ELEV = 81.5' WELL WORK INVOLVING EXPLOSIVES CAN BEGIN - BF. ELEV = 52.9' CONTACT PAD OPERATOR*** KOP = 752' Max Angle = 41 @ 2640' Datum MD = 10013' I 2182' 1-14 -112" HES HXO SSSVN, ID = 3.813" I Datum TVD = 8800' SS GAS LIFT MANDRELS • ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 -3/4" TBG, 45.5 #, N-80 BTC, ID = 10.050" H 3502' Ia i 7 3384 2988 38 KBMG OPEN BK -5 03/09/11 6 5912 4998 37 KBMG OPEN BK -5 03/09/11 min 7158 6048 21 KBMG BK -5 TOP OF CEMENT (TAGGED 03/23/11) 5331' SLM •�•� ∎ • �•♦•� • • ■ • 4 7918 6787 5 KBMG OPEN BK -5 — 03/09/11 • ♦ ►♦ PRODUCTION CASING LEAK (03/25/11) H 5850' I— 4+j ► ♦.*♦: ♦j ♦j,■j♦ 3 8532 7400 1 KBMG BK -5 •• •• ► ♦ ♦ ♦ ♦ ♦ ♦ 4.♦ ♦ 2 9024 7892 1 KBMG OPEN BK -5 -- 03/09/11 " 2182' i ♦ i � ► ♦ ► ♦ i Minimum ID = 3.813 1 9559 8427 1 KBMG OPEN BK -5 03/09/11 @ 2182 :• ■∎•� ••� 4-1/2" HES SSSVN ' � 9701' — 14 - 1/2" HES X NIP, ID = 3.813" • ♦ ♦� ► ♦ ♦ ♦ ♦� ► ♦ ♦ 1 •4 ♦♦♦♦4•♦ • :44 ► 000♦ ♦ 9713' —17 -5/8" X 4-1/2" BKR SABL PKR, ID = 3.875" ►Z� ► i ♦ i ♦ i ♦ i r •••• ■ 9737' 1-14 -112" HES X NIP, ID = 3.813" I i ♦ ♦ ♦ ♦ i ∎ • ♦ ♦ ♦ ♦ ♦ ♦ ' ♦•••• ∎ ∎•■•■■�♦' 9740' H3-3/8" BKR IBP (SET 12/28/00) 1 1 9749' H4-1/2" HES XN NIP, ID = 3.725" I 4 1/2" TBG, 12.6 #, NSCT, 13- CR -80, H 9758' .0152 bpf, ID = 3.958" 1TOP OF BKR TIEBACK SLV, ID = 5.75" 1 9760' 1 `� 9760' H4-1/2" WLEG, IS = 3.958" I 1 9748' H ELMD TT LOG ON ? ?? I 9767' 1-17-5/8" X 5-1/2" BKR LNR PKR, ID = 4.813" I ® 9773' I 7 -5/8" X 5-1/2" BKR LNR HGR, ID =4.8' 7-5/8" CSG, 29.7 #, NT -95 -HS NSCC, H 991 T I .0459 bpf, ID = 6.875" 1 PERFORATION SUMMARY REF LOG: BHCS 01/05/95 1 ANGLE AT TOP PERF: 1° @ 9920' Note: Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9920 - 9940 C 12/28/00 3 -3/8" 6 10020 - 10060 C 12/28/00 1 2 -7/8" 6 10083 - 10100 C 12/28/00 2 -7/8" 6 10107 - 10115 C 12;28/00 1 2 -7/8" 6 10121 - 10127 C 12/28/00 PBTD I 10295' WM 5 -1/2" NSCC LNR, 17 #, 13- CR -80, - �������������� .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/08/95 N28E ORIGINAL COMPLETION WELL: A -41 07/04/01 CH /KAK CORRECTIONS PERMIT No: 94 -1580 08/05/02 RL /tlh GLV UPDATE API No: 50- 029 - 22530 -00 02/02/10 JLW /PJC CSG CORRECTIONS SEC. 35, 11N, R13E, 1373' FNL & 920' FEL 03/11/11 SWC /PJC PULL GLVS / CMT PLUG (03/09/11) 03/26/11 RRW /PJC CEMENT TBG & IA (03/23/11) N BP Exploration (Alaska) -7-70.,:s9ic,,,R..:,,,,,ill:c:,i1=,,,,,,,,31,0;;,,t70,..‘,' --, ALP a d , , : -,, . .. - Q AZ110-111 1111 ,41: 1 ) Y prOx ,..•,„:.,,,. .0(,-.-..--,. ,(itli-411L .. ,.' . ., •-• ' k,' - .".......>',N,.., •--, ,..,.._ 0-1 9 Approx -•e. 411.1p'',:' ;lie", V *.k- "`:./4,,,t"tit;:••:,,.e;a0, ; ..'„,.VcV '..s.,', 4--..., '',1.,..•.,."1".',. .,,4‘‘ -• .'t.7r. f::47/ '''''" . ..;' t ."....•:....' -; '''''...' ...- .'-''''?;. 4,1t ioti-xf;i '''t, ---:.'',.., .•.-", ---. - . . . . ... _ ., .,,..:er,-: . .4. 1 -:: - , 4 . r - ,. , , ...v' v I .... , .1 '..` N, 1!"■.,'.', !:•:,„..?,,,,.. , 1 . 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' ',..', ' ' 1 r ,.... t STATE OF ALASKA ALASKA AIPAND GAS CONSERVATION COMMISSI WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned p Suspended la lb. Well Class: 20AAC 25.105 20AAC 25.110 Development IN Exploratory p GINJ ❑ WINJ ❑ WAG El WDSPL ❑ No. of Completions: _ ONE Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: BP EXPLORATION Aband.: 3/18/2011 194 -1580 311 -007 3. Address: 6. Date Spudded: 13. API Number: PO BOX 196612, ANCHORAGE, AK 99519 12/26/1994 50- 029 - 22530 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3907' FSL, 920' FEL, SEC. 35, T11N, R13E, UM 1/4/1995 PBU A-41 Top of Productive Horizon: 8. KB (ft above MSL): 81.5 15. Field /Pool(s): 2300' FNL, 4559' FEL, SEC. 35, T11N, R13E, UM GL (ft above MSL): 47.4 PRUDHOE BAY FIELD/ Total Depth: 9. Plug Back Depth(MD +TVD): PRUDHOE BAY POOL 2982' FSL, 4563 FEL, SEC. 35, T11N, R13E, UM 5331' 4533' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 654452.7 y- 5949075.81 Zone- 4 10375' 9243' ADL- 028286 TPI: x- 650834.86 y- 5948073.29 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 650830.78 y- 5948076.07 Zone- 4 NONE 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: DIFUBHCS /AC /GR, FMT /GR N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 91.5# H-40 SURFACE 115 SURFACE 115 30" 260 SX ARCTICSET ( Approx.) 10 -3/4" 45.5# NT -80 SURFACE 3502 SURFACE 3083 13 -1/2" 1125 SX AS iii /375 SX "G" 7 -5/8" 29.7# NT95HS SURFACE 9917 SURFACE 8785 9 -7/8" 265 SX CLASS "G" 5 -1/2" 17# 13CR80 9760 10375 8628 9243 6 -3/4" 110 SX CLASS "G" 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 -3/8" GUN DIAMETER, 6SPF 4 -1/2" 12.6# 13CR80 9758 9713/8581 9920 -9940 10020 -10060 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10083 -10100 F t ` " 10107 -10115 ,k 51; 4 L u t DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10121 -10127 9727 DUMPED 13' OF CEMENT 5331 SET 155 BBLS CLASS "G" CEMENT 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NOT ON PRODUCTION N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period ■.0. Flow Tubing Casing. Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 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. RECEIVED 'Pia - aVo..''`°MA* /.6-101 k Alive mil & fi t Com Commission Ancneriggo Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE S ubmit_gFigin n y 4 ' y / • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Li Yes U No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base SAG RIVER 9,916.00 8,702.00 SHUBLIK 9,940.00 8,726.00 SADLEROCHIT 10,017.00 8,803.00 Formation at total depth: 31. List of Attachments: SUMMARY OF OPERATIONS, WELLBORE SCHEMATIC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JOSH ALLELY, 564 -5732 Printed Name: Js LAS. F Title: PETROTECHNICAL DATA TECHNOLOGIST Signatu -: �� Phone: 564 -4091 Date: 5/13/2011 V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 13: 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 28. 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 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 corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 A-41 194 -158 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base A-41 1/22/95 PER 10,020. 10,060. 8,888.1 8,928.1 A-41 7/8/97 APF 9,920. 9,940. 8,788.11 8,808.11 A-41 7/27/98 APF 10,083. 10,100. 8,951.1 8,968.1 A-41 7/27/98 APF 10,107. 10,115. 8,975.1 8,983.1 A-41 7/27/98 APF 10,121. 10,127. 8,989.1 8,995.1 A-41 11/26/00 BPS 9,740. 9,750. 8,608.12 8,618.12 A-41 11/28/00 BPP 9,740. 9,750. 8,608.12 8,618.12 A-41 12/28/00 BPS 9,740. 9,741. 8,608.12 8,609.12 A-41 3/18/11 SQZ 5,331. 9,740. 4,532.62 8,608.12 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1 • • • A -41 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 'axia���„'„���� 3/8/2011:** *WELL SHUT IN ON ARRIVAL ** *(pre p /a) RIG UP SWCP 4518 CURRENTLY RIH W/ EMPTY 10'x3.50" DUMP BAILER W/ KJAR,3.50" LIB. * * *CONT WSR ON 3/9/11 * ** 3/9/2011 * * *CONT WSR FROM 3/8/11 ** *(pre p /a) ;DRIFT W/ 10'x3.50" DUMP BAILER,3.50" LIB TO 9704'SLM(no impression) DUMP BAILED 13' OF CEMENT AT 9,704'SLM W/ 3.50" DUMP BAILER. PULL SK -DGLV FROM STA# 1( 9 ,599'MD)STA #2(9,024'MD)STA#4(7, 918' MD) STA #6(5,912'MD)STA #7(3,384'MD). POCKETS LEFT OPEN DRIFT W/ 3.0" CENT,1- 1/4 "S- BAILER TO TOC AT9,691'SLM. * * *RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED * ** 3/9/2011 T /I /O = 200/140/0. Temp = SI. Assist S/L with cellar watch. (P &A). ALP = 1880 psi. ;AL SI @ casing valve. No visible signs of leaks from starting head or in conductor. *SLB S/L in control of well upon departure* 3/18/2011 ACT -8 1 3/4" Scope of Work: Cement off PC leak/P &A. On Location sign permit, MIRU, "ERD Drill of Flow back iron failure between WH & choke." MU Lubricator /injector /BOP stack. MU 1.75" x 9.165' ball drop cmt noz ;assembly. Cut 200' coil. M/U BD cementing BHA . RIH. Tag PBTD and correct depth. Pick up 10'. Perform injectivity test at 1 bpm. High injectivity to PC. PJSM. Bullhead 155 bbl, 15.8 ppg, G Cement to loss zone at 5850' while laying in cement at 0.8 bpm and 20 fpm, with well shut in. Lay in last 19 bbl cement 1 for 1 thru MM choke skid to open top tank. Well FP with 60/40 to 3000'. Estimated TOC — 5000'. « «Continued on WSR 3-19-11>>>>> 3/19/2011T/I/O= 130/110/130. Temp= SI. Bleed IA & OA to 0 psi (mitigate fluid in conductor). 'AL blinded at casing valve. On arrival, fluid overflowing conductor into cellar. Flow from conductor ceased within 30 minutes. Estimated 1 bbls fluid in cellar. IA FL @ I, :surface. OA FL near surface. Bled IAP from 110 psi to 30 psi (fluid) in 1 hour. :During IA bleed, OAP decreased to 60 psi & bubbling in conductor restarted for about `.15 mins (did not overflow conductor). Bled OAP from 60 psi to 30 psi in 15 mins `(fluid & gas). OAP & IAP maintained 30 psi for 1 hr 30 mins while bleeding OAP. Total fluid bled= 18.0 bbls. Monitored for 30 mins. During monitor, IAP & OAP unchanged at 30 psi. Final WHPs= 150/30/30. Job complete. SV & WV =C. SSV & MV =O. IA & OA =OTG. NOVP. 3/19/2011 ' Continued from WSR of 03 -18 -2011. CTU #8, 1 3/4" Coil, Scope of work: Cement off PC Leak/P &A. 'RD BHA & surface pressure equip. Weekly BOP test completed successfully. RD & MOL. «« «Job Complete » » » »> 3/21/2011 °T /I /O= SSV /60/90. Temp = SI. WHPs (Cellar eval). AL blinded at casing valve. IAP increased 30 psi & OAP increased 60 psi since 3/19/11. Cellar is clean & dry. Fluid visible in conductor flutes about 6" down. No bubbling visible. SLB S/L in control of well. • • 3/21/2011 ` ***WELL S/I ON ARRIVAL * ** (post P &A) DRIFTED TBG W/ 2.50" CENT & S.BAILER, TAGGED TOP OF CEMENT @ 5323' SLM, GOOD (SAMPLE OF WET CEMENT) ** *WELL S/I ON DEPARTURE * ** 3/23/2011 ** *WELL S/I ON ARRIVAL ** *(post p &a) DRIFTED TUBING WITH 2.50" CENT & 1.75" S- BAILER. TAGGED TOC @ 5331' SLM. (SAMPLE OF CEMENT) ;( AOGCC WITNESSED BY L. GRIMOLDI) :LRS ATTEMPT CMIT TxIA (FAILED) ' ** *WELL LEFT S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS * ** 3/23/2011 T /I /O = 200/60/130 Temp = SI Assist SL / DHD ( AOGCC State witnessed - L :Grimaldi) CMIT TxIA Failed to 2500 psi. Did not reach test pressure ( Possible IA ; ev ' I ;x OA communication with SC leak) Pumped 5.9 bbls of crude down the tubing with ; ''"�j' .} an open OA bleed. OA pressured up / tracked with IA. T /I /O= 450/200/200. SL RIH to tag cement. On 2nd attempt - at 6.4 bbl away got fluid to surface in flutes. T /I /O= 500/350/580 with OA bleed shut in. Bled back 9.2 bbls to Final WHP= 60/10/10. SL on well at departure 3/23/2011 T /I /O= 280/150/180. Temp= SI. Cellar Watch (AOGCC MIT). IA FL, OA FL near surface. Held open bleed on OA during 1st attempt @ pumping. OAP increased 100 ;psi. No signs of bubbling. SI bleed as per WIC and monitor during 2nd attempt @ 'pumping. OAP increased 140 psi with bubbling in flutes. Vac'ed out —2 bbls of fluid. Bled WHPs from 500/350/380 to 60/10/10. Monitor for 30 min. WHPs unchanged. No bubbling in flutes at this time. LRS pumped —12 bbls of fluid with 9 bbls returned. ;Job complete. Final WHPs= 60/10/10. ISlickline in control of valves. 4/3/2011 T/I/O= 140/70/80. Temp =S1. CMIT -TxIA to 2500 psi FAILED w /LLR of 10 gpm @ { 220 psi (P &A well). A/L SI @ casing valve. Vac out 6" of fluid in conductor. Bled OAP to 0 psi and maintain open bleed to slop (mostly gas returns). Pumped 188 gallons diesel to pressure IA to 320 psi, IAP fell suddenly to 220 psi and OAP ;suddenly rose to 200 psi and started falling off, OA returns went to solid fluid. Continued pumping @ 10 gpm for 10 minutes for a LLR for a total of 288 gallons ,diesel pumped. During LLR TP & IAP held stable @ 260 psi & 220 psi, OAP slowly fell from 150 psi to 130 psi while holding open bleed on OA. 20 minutes after LLRT, :WHPs decreased to 100/40/40, bled back an additional 54 gallons before OA returns went back to gas. Bled remaining OAP down to 0 psi (all gas). Pumped a total of 1 288 gallons down IA, bled back a total of 206 gallons from OA during open bleed. I No LELs or fluid back in conductor though process. Job complete. FWHP= 80/10/0. SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. 4/3/2011'T/1/0= 180/60/100. Temp= SI. T, IA, OA FL, strap depth of conductor (P &A well). =AL SI @ casing valve. ALP= 1980 psi. T, IA, OA FL near surface. Conductor has 7" - 20" of void (gravel bottom). `SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. 4/5/2011 T /I /O= 220/100/40. Temp= SI. Bleed WHPs to 0 psi (Suspended Well). AL SI @ casing valve. ALP= 600 psi. TBG FL near surface, IA FL @ surface, OA FL near surface. Bled TP to slop from 200 psi to 0+ psi. During bleed IAP went on a VAC. Bled OAP to slop tank from 40 psi to 0+ psi. Monitored for 30 min. TBG pressure, IAP, OAP remained unchanged. Job complete. Final WHPs= 0 +NAC /0 +. ISV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. 4/7/2011 T /I /O= SSV /0 +/0 +. Temp= SI. WHPs (Suspended well Post Bleed). AL SI @ casing valve. SV, WV & SSV =C. MV =O. IA & OA =OTG. NOVP. • • 4/17/2011: T/I/O= SSV /0 +/0 +. Temp =SI. WHPs. (suspeded well post bleed). AL SI & blinded @ casing valve. SV, WV, SSV =C. MV =O. IA &OA =OTG. NOVP. 4/25/20111T/I/O =SSV /25/20. Temp =SI. WHPs. (suspended well post bleed). AL SI & blinded @ casing valve. Appears to be crude in conductor from the 6 o'clock position to the 12 o'clock position. There is rapid bubbling © the 9 o'clock position. Small spot of crude in cellar @ 3 o'clock position, no evidence of leak from conductor. Cellar has 'spray in liner, liner is soft around the 3 o'clock area. Cleaned spot, no evidence that ; spot leaked through liner. SV, WV, SSV =C. MV =O. IA &OA =OTG. NOVP. 5/4/2011 T /I /O =SSV /50/40. Temp =Sl. WHPs. (suspended well post bleed). AL SI & blinded '@ casing valve. IAP increased 25 psi, OAP increased 20 psi from 4/25/11. No bubbling in conductor at this time. SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. TREE= } 4-1/16° CM/ SAFETY NO 4 -112" & 5 -112" CHROMETBG"* WELLHEAD = 11 ",5M FMC UNIVERSAL WARNING: 0 TRANSMITER IN WEATHER ACTUATOR= BAKER J.\4 1 MONITORING SHACK MUST BE TURNED OFF PRIOR KB. ELEV = 81.5' WELL WORK INVOLVING EXPLOSIVES CAN BEGIN - BF. ELEV = 52.9' CONTACT PAD OPERATOR'"" KOP = 752' Max Angle = 41 @ 2640' Datum MD = 10013' I 2182' H4 -1/2" HES HXO SSSVN, ID = 3.813" I Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 110-3/4" TBG, 45.5 #, N -80 BTC, ID = 10.050" H 3502' I, a 7 3384 2988 38 KBMG OPEN BK -5 - 03/09/11 6 5912 4998 37 KBMG OPEN BK -5 - 03/09/11 TOP OF CEMENT (TAGGED 03/23111) H 5331' SLM I . - ..! -1.. 5 7158 6048 21 KBMG BK -5 ∎ • • 4 r • . • . • . 4► • •• • 4 7918 6787 5 KBMG OPEN BK -5 - 03/09/11 I PRODUCTION CASING LEAK (03/25/11) H 5850' 1 — 4 j :j ► '.;j ; ..;j;w ..•• 3 8532 7400 1 KBMG BK -5 • •• ►•••♦ ♦ 9024 - Minimum ID = 3.813" @ 2182' :• •• ► ••• • ••• ••••� 1 _ 9559 8427 1 KBMG OPEN_ BK -5 - _03/09/11 4-1/2" HES SSSVN .•• • .• ...�. ♦ • •■ • • • 4* 9701' —14-1/2" HES X NIP, ID = 3.813" •�•' 1.44• : : : :: :rte •4 •�• 9713' —17 -5/8" X 4 -1/2" BKR SA BL PKR, ID = 3.875" l ►.'►1 /.v.♦ ■ •�• � •.- 1 9737' H4 -1/2" HES X NIP, ID = 3.813" I 3' (4' , ■∎ ..�. • 9740' 1 BKR IBP (SET 12/28/00) 1 ' n 1 9749' H4-1/2" HES XN NIP, ID = 3.725" I 4 1/2" TBG, 12.6 #, NSCT, 13- CR -80, 9758' .0152 bpf, ID = 3.958" ITOP OF BKR TIEBACK SLV, ID = 5.75" H 9760' 14 [ WLEG, IS = 3.958" I ( 9748' H ELMD TT LOG ON ? ?? I 9767' H7 -5/8" X 5 -1/2" BKR LNR PKR, ID = 4.813" I • 9773' H7-5/8" X 5 -1/2" BKR LNR HGR, ID = 4.875" I 7 -5/8" CSG, 29.7 #, NT -95 -HS NSCC, — 9917' 1 .0459 bpf, ID = 6.875" 1 PERFORATION SUMMARY REF LOG: BHCS 01/05/95 1 ANGLE AT TOP PERF: 1° @ 9920' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 1 3 -3/8" 6 9920 - 9940 C 12/28/00 3 -3/8" 6 10020 - 10060 C 12/28/00 1 2 -7/8" 6 10083 - 10100 C 12/28/00 2 -7/8" 6 10107 - 10115 C 12/28/00 1 2 -7/8" 6 10121 - 10127 C 12/28/00 1 PBTD 10295' •...... 5 -1/2" NSCC LNR, 17 #, 13-C R-80, - -110375 .0232 bpf, ID = 4.892" - DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01108/95 N28E ORIGINAL COMPLETION WELL: A -41 07/04/01 CH/KAK CORRECTIONS PERMIT No: 94 -1580 08/05/02 RL /tlh GLV UPDATE API No: 50- 029 - 22530 -00 02/02/10 JLW /PJC CSG CORRECTIONS SEC. 35, 11N, R13E, 1373' FNL & 920' FEL 03/11/11 SWC/PJC PULL GLVS / CMT PLUG (03/09/11) 03/26/11 RRW /PJC CEMENT TBG & IA (03/23/11) 1 BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 3/ DATE: March 24, 2011 P. I. Supervisor 11 FROM: Lou Grimaldi SUBJECT: Plug Tag Petroleum Inspector BP Exploration (Alaska) Inc. PBU, A -41 A E APR 0 4 2011 Prudhoe Bay Unit PTD #194 -158 Wednesday, March 23, 2011; I witnessed the tag of the cement plug in the tubing of BP's well A -41 in the Prudhoe Bay Unit. The well plan called for a tag and pressure test of this plug, I asked for the pressure test first to ascertain if we could move the plug as it had been tagged the previous day by a different wireline unit. As I read the well plan I observed that there had been, in the past, flow up the conductor. There was a vacuum truck on location for sucking out the conductor /cellar if needed. I requested that the OA be verified open by bleeding /pumping through which was accomplished. I also requested test gauges be installed on all strings. I observed the following pressures /conditions. The pump truck was lined up on the tubing for the test. String Initial Pressure Open Swab 5 Bbl's away IA 65 150 150 OA 90 180 200 Tubing Swab Closed 280 250 The pressure test was to be taken to 2500 psi. Very quickly during the initial pumping I observed the OA reacting to the pump. The company rep was consulted and I ordered the pumping to stop as I was concerned with broaching the casing at the 2500 psi test pressure if reached. It should be noted that during the pumping operation the OA was being bled to a bleed trailer. With 5 bbls away, the following pressures stabilized once the bleeding to the trailer was halted: Tubing =150, IA =40, OA =90. Only gas was bled to the trailer. BP's engineer was consulted and he wanted to shoot fluid levels in the IA/OA which I concurred with. During this time I had the wireline crew run in and tag the plug which was tagged the previous day by a different unit at 5323 ft (tubing head flange datum). This tag was at 5331 ft with a sample bailer and upon retrieval a small amount of clabbered cement was caught in the bailer bottom. 2011- 0324_P &A_PBU_A -41 _lg.doc 1 of 2 • • The echometer shots showed fluid level to be at approximately 50 ft from surface, again the engineer was consulted who wanted to pump another 5 bbls of diesel to see if they could fill the Annular spaces. I observed the following pressures /conditions. String Initial Pressure 3 Bbl's away 5 Bbl's away IA 40 230 300 OA 90 270 330 Tubing 150 320 410 At this point we observed fluid come up and bubbling in the Conductor. They started vacuuming the fluid from the flutes in the Conductor and the operation was shut -down. There seems to be a competent plug in the tubing but the whole well's integrity is questionable due to communication across all strings of pipe. A serious review of strategy is in order. Attachments: none Non - Confidential 2011 -03 24_P &A_PBU_A -41 _lg. doc 2 of 2 • • 51 ALA / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Josh Allely Petroleum Engineer BP Exploration (Alaska), Inc. '0 P.O. Box 196612 %AHED 3°I 2011 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A -41 Sund ry Number: 311 -007 Dear Mr. Allel : Y Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 12' day of January, 2011. Encl. STATE OF ALASKA 6" " i( /, // • ALASKA" AND GAS CONSERVATION COMMISSICO) ' 1 Z APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ‘ 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend • Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El Alter Casing ❑ Other: CEMENT • IS 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 • Exploratory ❑ 194 -1580 ' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22530 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No ❑ PBU A -41 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028286. PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10375 • 9242 ' 10295 9162 9740 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" SURFACE 149 SURFACE 149 Surface 3468' 10 -3/4" 45.5# N -80 SURFACE 3502 SURFACE 3035 5210 2480 Intermediate 9883' 7 -5/8" 29.7# NT -95HS SURFACE 9917 SURFACE 8738 8180 5120 Production Liner 9145' 5 -1/2" 17# 13CR -80 9760 10375 8581 9196 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13CR -80 IURFACI 9758 Packers and SSSV Tvoe: 7 -5/8" X 4 -1/2" BKR SABL PKR Packers and SSSV MD and TVD (ft): 9713 8581 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 151 a Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/20/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended . El 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Allely Printed Name Josh Allely Title PE Signature Phone Date !�'�.--. 564 -5732 1/6/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY /1��� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 i ' ` C0 1 Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ` Other: A ' _ 4.r ri. 1 / 4 `J 6 4 G �.xw,� � p �0 t o v t.X = 1 � ` tS. > r' /"1 a:�e. U � / I / I G Z 5. 110 (h) 10i 9 '{ Subsequent Form Required: /0 _. Q 7} Gil g fin of1 ry-;'smY$sion 7 ` L APPROVED BY Af1CfY ' t Approved by: i������ OMMISSIONER THE COMMISSION Date: 1 RBDI4 1 ., 3 i 1 Submit in Duplicate . IGiNAL Form 10-403 Revised 1/2010 G • , •,/, , • A-41 194 -158 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tor Tvd Depth Base A-41 1/22/95 PER 10,020. 10,060. 8,888.1 8,928.1 A-41 7/8/97 APF 9,920. 9,940. 8,788.11 8,808.11 A-41 7/27/98 APF 10,083. 10,100. 8,951.1 8,968.1 A-41 7/27/98 APF 10,107. 10,115. 8,975.1 8,983.1 A-41 7/27/98 APF 10,121. 10,127. 8,989.1 8,995.1 A-41 11/26/00 BPS 9,740. 9,750. 8,608.12 8,618.12 A-41 11/28/00 BPP 9,740. 9,750. 8,608.12 8,618.12 A-41 12/28/00 BPS 9,740. 9,741. 8,608.12 8,609.12 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER II BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • To: Alaska Oil & Gas Conservation Commission From Josh Allely 0 bp Welts Group Engineer BP Alaska Date: January 5 2011 Re: PBU A -41 Sundry Approval Sundry approval to suspend well A -41 is requested. A -41 is a well that is exhibiting TxIAxOA communication with a starting head leak and a production casing leak at 5500' MD. The Ivashak is currently secured with an IBP in the tubing tail at 9740'. A leak detect log performed on 11/27/2010 determined the location of the holes in the tubing, the location of the PC leak, and confirmed the IBP is holding. It is our desire to secure the well with a more permanent cement plug. Due to the nature of the communication, removing the IBP to place cement across the perforations has been deemed too risky. The current plan is to punch holes above the packer and lay in —174 bbls (4240' MD) of cement in both the 4 -1/2" tubing and the 4 -1/2" x 7 -5/8" annulus above the packer [figure 2]. This will permanently secure the Ivishak and also cover the PC leak. The production packer is 201' MD (201'TVD) above the top of hydrocarbon bearing sands (TSAG) and 207' MD (207' TVD) above the top perf. We are requesting approval of a sundry to proceed with work as we feel the planned action is sufficient to isolate the Ivishak formation, complies with AOGCC zonal isolation requirements, and offers the least amount of exposure. Well Information Status: Non Operable Artificial Lift Producer Last Well Test 07/09/2000 (last representative test) Typical Production Rate: 1700 bfpd, 0.8 mmscfpd, 85% WC at 270 psi WHP and 126F WHT. Max Deviation: 40.6deg at 2640' and Perf Deviation: 1 deg at 9920' md. Min. ID: 3.725 HES XN Nipple at 9749 MD Last TD tag: 9902' elmd: tag TD with 2.9" cent and s- bailer at 9902 elmd. Last Downhole Ops: 11/27/10: LDL and TD tag. SIBHP /SIBHT No survey since 1995. Assuming 3200 psi. Latest H2S level: N /A; No sample recorded. Ann Comm Status: TxI�_x SH leak with a PC leak; Not Operable 1 cenCdr h od ceetrl To 4/4'7/(44/6 2cz 4111° 4 y°„/ o 66 0. ,, g. c�eSG S b et b 5 ,' -1,, t>i N&'PAUfe,- 2000 4. , ,�, 4 1.''te re5er r ; s 1 � h �' 6/v. 1e 10ij 4 1 ' 64( 6 i / (o,cli`T,4 or i4 £vl // /4s ", Inc/ s S oSP ��' "� c '�f� ap(eer 5 to be AP fild& -d coo -F act a t• -7. • • The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed cement plug is attached for reference. Planned Work: 1. S — Dump bail cement on IBP to secure. Pull all DGLVs. 2. E — Punch TBG above packer 9700 -9705 MD. 3. C — Lay in 174 BBLS of 15.8 ppg class G cement, filling up IA and TBG to 5500' MD (350' above PC leak) 4. S — Drift and tag to confirm TOC. Ca .,AJ Sk ive °'" L. :'- ''Less 5. F — Pressure test cement and casing to 2500 psi. Josh Allely Wells Group Engineer 564 -5732 (w) 350 -7362 (c) Dan Kara Wells Group Engineering Team Lead 564 -5667 (w) 240 -8047 (c) _ - • • TREE= 4 - 1/16" CIW SAFETY NOTES: 4-1/2" & 5-1/2" CHROt E TBG * ** WELLHEAD = 11 ",5M FMC UNIVERSAL I;UQ I Fv\k 1 J� - bF / � 1 WARNING: RADIO TRANSMITER IN WEATHER Sc1ne�+a� , R. ACTUATOR= BAKER j M MONITORING SHACK MUST BE TURNED OFF KB. ELEV = 81.5' PRIOR WELL WORK INVOLVING EXPLOSIVES CAN BF. ELEV = 52.9' A 4- IZ+ISI7 c BEGIN- CONTACT PAD OPERATOR*** KOP = 752' Max Angle = 41 @ 2640' Datum MD = 10013' I 2182' H 4-1/2" HES HXO SSSVN, ID = 3.813" I Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 -3/4" TBG, 45.54, N -80 BTC, ID = 10.050" H 3502' IA 7 3384 2988 38 KBMG BK -5 6 5912 4998 37 KBMG DMY BK -5 08/04/02 5 7158 6048 21 KBMG BK -5 PL 1..ea..K (4.v. , I-o Ll "-- 14-44;1 "" ' 4 7918 6787 5 KBMG DMY BK -5 08/04/02 . -_. -, 3 8532 7400 1 KBMG BK -5 2 9024 7892 1 KBMG DMY BK -5 08/04/02 Minimum ID = 3.725" @ 9749' 1 _ 9559 8427 _ 1 KBMG DMY_ BK -5 08/04/02 HES XN NIPPLE i 9701' H4 -1/2" HES X NIP, ID = 3.813" 1 PTA I 9713' H7 -5/8" X 4 -1/2" BKR SABL PKR, O = 3.875" 9737' H4 -1 /2" HES X NIP, ID = 3.813" 9740' — 13 - 3/8" BKR IBP (SET 12/28/00) I 9749' 1-1_ 4-1/2" HES XN NP, ID = 3.725" I 4 1/2" TBG, 12.64, NSCT, 13- CR -80, — I 9758' .0152 bpf, ID = 3.958" TOP OF BKR TIEBACK SLV, ID = 5.75" H 9760' 1 ( 9760' H 4 -1/2" WLEG, IS = 3.958" I 9748' I — IELMD TT LOG ON ? ?? I 9767' I—(7 -5/8" X 5 -1/2" BKR LNR PKR, ID = 4.813" I 7 -5/8" CSG, 29.7 #, NT -95 -HS NSCC, — 9917' I L 9773' H 7 -5/8" X 5 -1/2" BKR LNR HGR, O = 4.875" I .0459 bpf, ID = 6.875" PERFORATION SUMMARY REF LOG: BHCS 01/05/95 , ANGLE AT TOP PERF: 1° @ 9920' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn/Sqz DATE 3 -3/8" 6 9920 - 9940 C 12/28/00 3 -3/8" 6 10020 - 10060 C 12/28/00 ' 2 -7/8" 6 10083 - 10100 C 12/28/00 2 -7/8" 6 10107 - 10115 C 12/28/00 ' 2 -7/8" 6 10121 - 10127 C 12/28/00 1 MID 1-1 10295' I •••••1/ •�•�•�•�•�•�t 5 -1/2" NSCC LNR, 17 #, 13 -CR 80, — 110375' MAtti At .0232 bpf, O = 4.892" DATE REV BY COMMENTS DATE REV BY COI 4814TS PRUDHOE BAY UNIT 01/08/95 N28E ORIGINAL COMPLETION WELL: A -41 07/04/01 CWKAK CORRECTIONS PERMIT No: 94-1580 08/05/02 R./tlh GLV UPDATE API No: 50- 029 - 22530 -00 02/02/10 JLW /PJC CSG CORRECTIONS FEL, SEC. 35, 11N, R13E, 1373' FNL & 920' FEL BP Exploration (Alaska) Figure 1: Current wellbore schematic as of 01/05/2011 • • TREE= 4 -1/16" CIW _ SAFETY NOTES: 4 - 1/2" & 5 -1/2" CHROME TBG * ** WELLHEAD = 11 ",5M FMC IJMVERSAL 1 P r pD y, +� WARNING: RADIO TRANSMITER IN WEATHER ACTUATOR= BAKER j �A MONITORING SHACK MUST BE TURNED OFF KB. ELEV = 81.5' PRIOR WELL WORK INVOLVING EXPLOSIVES CAN BF. ELEV = 52.9' BEGIN- CONTACT PAD OPERATOR*** KOP = 752' Max Angle = 41 @ 2640' , Datum MD = 10013' 2182 N4 -1/2" HES HXO SSSVN, ID = 3.813" 1 Datum 'ND = 8800' SS GAS LIFT MANDRELS Qlannr: TOG /' S5 0a , ST MD TVD DEV TYPE VLV LATCH PORT DATE 110 -3/4" TBG, 45.5 #, N-80 BTC, 0 = 10.050" H I 3502' I 7 3384 2988 38 KBMG BK -5 6 5912 4998 37 KBMG .DART" BK -5 08/04/02 5 7158 6048 21 KBMG BK -5 4 PG Ltwtc, 4rte *1 4to LA 691= 4 7918 6787 5 KBMG Y BK -5 08/04/02 4 3 8532 7400 1 KBMG BK -5 2 9024 7892 1 KBMG 13MY BK -5 08/04/02 Minimum ID = 3.725" @ 9749' 1 9559 8427 1 KBMG,pM BK -5 08/04/02 HES XN NIPPLE P, 11161 , 4 4 9701' —14 -1/2" HES X NIP, ND = 3.813" I " obty Pg.ct -, No1« 1 -- ------ .1 .1 t� f 01 7 41 I 1. . 1°1 9713' -17-5/8" X 4 -1/2" BKR SA BL PKR, ID = 3.875" Al ir 1 973T — j4 -1/2" HES X NP, ID = 3.813" 1 1P 4...1 1 6 1 = 9740' — 13 -3/8" BKR BP (SET 12/28/00) 9749' 1 1 4-1/2" HES XN NIP, ID = 3.725" 1 4 1/2" TBG, 12.6 #, NSCT, 13- CR -80, —I 9758' .0152 bpf, ID = 3.958" I TOP OF BKR TIEBACK SLV, ID = 5.75" H I 9760' , 9760' -141 /2" WLEG, IS = 3.958" I I 9748' I-1 ELMD TT LOG ON ? ?? I i 9767' H7-5/8" X 5 -1/2" BKR LNR PKR, ID = 4.813" I 9773' H7-5/8" X 5-1/2" BKR LNR HGR, ID = 4.875" I 7 -5/8" CSG, 29.7 #, NT -95 -HS NSCC, H 9917' .0459 bpf, ID = 6.875" ' PERFORATION SUMFARY REF LOG: BHCS 01/05/95 t ANGLE AT TOP PERF: 1° @ 9920' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL OpnlSgz DATE 3 -3/8" 6 9920 - 9940 C 12/28/00 3.3/8" 6 10020 - 10060 C 12/28/00 ' 2 -7/8" 6 10083 - 10100 C 12/28/00 2 -7/8" 6 10107 - 10115 C 12/28/00 ' 2 -7/8" 6 10121 - 10127 C 12/28/00 PBTD 1 10295' 4444W1 5 -1/2" NSCC LNR, 17#, 13-CR-80, -110375' #.0.0.0, .0232 bpf, ID = 4.892" DATE REV BY COMYvENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/08/95 N28E ORIGINAL COMPLETION WELL: A - 41 07/04/01 CWKAK CORRECTIONS PERMIT No: 94 -1580 08/05 /02 RUM GLV UPDATE API No: 50- 029 - 22530 -00 02/02/10 JLW /PJC CSG CORRECTIONS Fa, SEC. 35, 11N, R13E, 1373' FNL & 920' FEL BP Exploration (Alaska) Figure 2: Proposed wellbore schematic after placing cement plug in tubing and annulus. 12/30/10 rger NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 25335(1 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 /,- 6 Anchorage, AK 99501 W Job # Log Description Date BL Color CD E -05 BL65 -00011 MEM DDL 12/18 /10 1 1 - 3B AY1M-00056 PROD PROFILE ,9`nc / 11/27/10 1 . CRP 1 11-12 BCZ2-00033 PROD PROFILE - , ` — • 12/06/10 1 ♦ "T 1 01-25 BG4H -00022 INJECTION PROFILE • _ 4 �f B r►�Z 1 04 -24 AY1M -00058 PROD PROFILE 1 t - ♦ / 12/02110 1 1 P2 -16 B5JN -00077 SBHPS t J 4 - '� 11/26/10 1 1 A-41 BCZ2 -00030 LDL - - 10 11/26/10 1 MI • 'LZ' 1 04 -08 BCRJ - 000566 02IXNIW � I ► 1 1 O1.24A BBSK -00043 IQRI4AI114L7a sralMrigfY _ ` riRVA 1 04-10 AVIH -00051 `J e Is -- u • 12107110 1 J 1 • 15 -268 BD88-00080 MEM PROD PROFILE _ • — 12/12/10 1 ti. 1 2- 28810 -19 BCRJ -00055 PROD PROFILE — • • •r, 11/30/10 1 _ rye' 1 07 -23B AY1M -00056 SCMT d — 11/28/10 a - £ 1 1 Al 02 -21A BBSK -00042 SCMT a — a1 - 11/23/10 • " t 1 1 I 02 -228 BL65 -00006 SCMT ?, — 12/11/10 • ' 1 1 18 -12B BBUO -00029 SCMT / . j 08 /30 /10 ♦ • ' 1 1 ( )) P2 -16 B5JN -00077 USIT 11/28/10 1 1 05 -278 BAUJ -00049 MCNL " Q , — J �� 09/18/10 1 , g0 , 1 18 -068 BBSK -00037 RST _ • - -- . 11/15/10 1 1i 1 G -09B BGZ7 -00005 RST O to 09/20/10 • 1 • 1 E -34L1 BD88 -00050 MCNL b - Jb 09/28/10 1 1 W -219 BGZ7 -00012 CH EDIT PDC -GB USIT _ — • --- 11/22/10 IS • ,/ 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 4 201 ~-~', STATE OF ALASKA ~" ALASK,. ,.)IL AND GAS CONSERVATION C~JMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Ann-Oomm 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3907' NSL, 920' WEL, Sec 35, T11N, R13E At top of productive interval 2978' NSL, 721' EWL, Sec 35, T11 N, R13E At effective depth 2298' NSL, 4562' EWL, Sec 35, T11 N, R13E At total depth 2977' NSL, 717' EWL, Sec 35, T11N, R13E 5. Type of well: [:x:] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE: 81.55 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-41 9. Permit Number / Approval No. 94-158 / 10. APl Number 50- 029-22530 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10375 feet BKB 9242 feet 10295 feet BKB9162 feet Bridge Plug set @ 9740' (11/26/2000) Plugs (measured) Junk (measured) Length Size Cemented M D TVD Structural BKB Conductor 115' 20" 260 sx Arcticset 149' 149' Surface 3468' 10-3/4" 1125 sx AS III / 375 sx 3502' 3035' Intermediate 9883' 7-5/8" 265 sx Class 'G' 9917' 8738' Production Liner 9145' 5-1/2" 110 sx Class 'G' 9760' - 10375' 8581' - 9196' Perforation depth: measured Open Perfs 9920' - 9940', 10020' - 10060', 10083' - 10100', 10107' - 10115', 10121' - 10127' true vertical Open Perfs 8788' - 8808', 8888' - 8928', 8951' - 8968', 8975' - 8983', 8989' - 8995' Tubing (size, grade, and measured depth) 4-1/2" 13CR to 9713' with 4-1/2" tailpipe to 9760' Packers and SSSV (type and measured depth) 7-5/8" Baker "SABL" PKR @ 9713', 4.5" HES "HXO" SSSVN @ 2182' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure ' UEIV D MAY 0 2 ~001 Alaska Oil & Gas Cons Anchor' C°n~'ssion 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water- Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby c/~lify ~at thc forelC/r~g is true..a, nj~correct to the best of my knowledge S ig ned~,~~/~,,.,~/~ ~/~~..-,--z.-~ Title Technical Assistant Form 10-404 Rev. 06/15/88 Service ¢'~ t ~. , ~?r?pared By Name/Number: Date ~'/)~ / ~' DeWayne Schnorr 564-5174 ~ Submit In Duplicatu~t-' A-41 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/12/2001 ANN-COMM: MONITOR WHP'S POST IBP 02/19/2001 ANN-COMM: TIFL, POT-lC, OA BLEED SUMMARY 02/12/01 TIO = 200/1300/1300. POSSIBLE IA X OA COMM TO CRETACEOUS. PLAN TO BLEED OA AND MONITOR. 02/19/01 TIFL FAILED POT-lC PASSED. Fluids Pumped BBLS. 0 0 TOTAL Description No Fluids Pumped ON OR BEFORE c:~Om,~m~a.poc ': ALASKA OIL AND GAS cONSERvATION COMMISSION¢,_. REPORT Oi-' UNDRY WELL OPEl:,.' 'TIONS ,. Operations performed: Operation shutdown Stimulate ~ Plugging__ Perforate Pull tubing__ Alter casing __ Repair well Other__ 2. Name of Operator BP £x~)loration (Alaska)/nc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 3907' NSL, 920' WEL, SEC. 35, T11N, R13E At top of productive interval 2978' NSL, 721' EWL, SEC. 35, T11N, R13E At effective depth 2298' NSL, 4562' EWL, SEC. 35, T11N, R13E At total depth 2977' NSL, 717 EWL, SEC. 35, T11N, R13E 5. Type of Well: DevelopmenlX Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB = ~1,¢5' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number A-41 (12-35-11-13) 9. Permit number/approval number 94-158 / 10. APl number 50-029-22530 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10375' feet Plugs (measured) 9242' feet 10295' feet Junk (measured) 9162' feet Casing Length Size Structural _. Conductor 115' 20" Surface 3468' 10-3/4" Intermediate 9883' 7-5/8" Production -- Liner 9145' Perforation depth: measured 10020'-10060' true vertica§ubsea 8888'-8928' Cemented 260 SX Arcticset 1125 sx AS 111/375 sx 265 sx Class "G" 5-1/2" 110 sx Class "G" Tubing (size, grade, and measured depth)4-1/2", 13CR80 to 9760' Packers and SSSV (type and measured depth)Packer @ 9713' SSSV @ 2182' Measured depth 149 3502 9917 9760-10375 True vertical depth BKB 149 3035 8738 8581-9196 13. Stimulation or cement squeeze summan~See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 2887 1170 0 329 Subsequent to operation 312 2529 1113 0 331 15. Attachments ! 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Oper/~tions I OilX Gas Suspended 17. I hereby.qertify th?t the,f/¢egoing is tr. ue,a"fld,correct to the best of my knowledge. Si ,4 .... _ Title Form l'0-404~Rev 06/15~88 Service Date ,//,~//~ SUBMIT IN DUPLICATE A-41 ADDPERF O7/O8/97 SUMMARY The following additional interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60° phasing. 9920'-9940' MD 94 .... 94 -- 158 AOG;3,2, Ind'i'v')'dLia] Wei I Ge,::)Jog:J'caJ Mater'-)'ais Inver~'t:..oi-'"y DATA T DATA.__PL L!'S ~ l~l~-~ 637a- ~a/~9300 ..... 1036'? B,r.,~ M~9900 10539 r ,., i k~,~ R "- ~ 94--i5.8 DIFL GR/'SP 94-- I .58 FMT/"G R 94 ..... I 58 DZFL/AC/GR ~ 97~00-'10967 9924-" 'i 093z~- PFC/F'ERF ~9490-i 02.59 P L. S i 'F'qi~A L/,4 ~./t ,t) ~q.:.'t~80 "' 9850 Ar'e dry d~'tch samples r'equ~'red? yes ~ And r"ece'i'vect'? Was '-hhe weii cor'ed? y e s ~___ A n a 'i y s i: s & d e s c r' i' p-t: 'i o n r" e c e "1 v e d ? Ar'e we i i tests r'equ'i' red? yes ~e'i' ved? ~~ w e i i 5 s ~' n c orr, p i i' a n c e ~-O I r, i' t ~' a 'i ..... STATE OF ALASKA AL, .A OIL AND GAS CONSERVATION COMMIS¢. jN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Pull tubing __ Alter casing Repair well __ Perforate__ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3907' NSL, 920' WEL, SEC. 35, T11N, R13E At top of productive interval 2978' NSL, 721' EWL, SEC. 35, T11N, R13E At effective depth 2298' NSL, 4562' EWL, SEC. 35, T11N, R13E At total depth 2977' NSL, 717 EWL, SEC. 35, T11N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KB = 81.55' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-41 (12-35-11-13) 9. Permitnumbe#approvalnumber 94-158 / 10. APInumber 50- 029-22530 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 10375' feet Plugs (measured) 9242' feet Effective depth: measured - 10295' feet Junk (measured) true vertical 9162' feet Casing Length Size Cemented Structural -- Conductor 115' 20" 260 SX Arcticset S u trace 3468' 10-3/4" 1125 sx A S 111/375 sx Intermediate 9883' 7-5/8" 265 sx Class "G" Production -- Liner 9145' 5-1/2" 110 sx Class "G" Perforation depth: measured 10020'- 10060' true vertical subsea 8888'-8928' Measured depth 149 3502 9917 9760-10375 True verticaldepth BKB 149 3035 8738 8581-9196 Tubing (size, grade, and measured depth) 4-1/2", 13CR80 to 9760' Packers and SSSV (type and measured depth) Packer @ 9713' SSSV @ 2182' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Op,¢?ations __ Oil X Gas__ Suspended I17' I her'~by/ce~rtify 'that/~I~reg°ing ''ldtr'u~::~d c°rrect t° the best °f my kn°wledge'sign2c,//~'~j.~~'.',~//~ ,~../.~A,~~ Title Form 10-4~4 Rev 06~r~'5/88 Service Date //~~. SUBMIT IN DUPLICATE WELL A-41(12-35-11-13) Hydraulic Fracture Operation 3/24/95 Performed a Hydraulic Fracture(IVISHAK) using the following fluids: FLUIDS PUMPED DOWNHOLE BBLS 70 8O 150 1040 DESCRIPTION Diesel to IA, tubing, or GC Diesel Recovered (not downhole) Total Diesel PETREDAT WINDOW bbls TOTAL FLUDS PUMPED DOWN HOLE LOAD VOLUME FLUID ADDITIVES --. BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. FEB 0 1 RECEIVED MAR 9 1995 Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 March 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL - M-34 N-34 DESCRIPTION 1 GR/CCL FINAL BL+RF 1 CCL FINAL BL+RF 1 PDK FINAL BL+RF 1 C/O FINAL BL+RF 1 PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5801.06 5813.01 6295.03 6295.04 6339.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return Petrotechnieal Data Cente~ BP Exoloratlon (Al~.ska) 900 East Benson Boulevard I.~.eceived by Da. ,,~ .......... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] /'~E~CI~ ~ 7. Permit Number 2. Name of Operator BP Exploration " 94- 158 3. Address ~.8.; APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22530 4. Location of well at surface 9. Unit or Lease Name ' .... ' ....... ,',,, "-:'L~-i ~:'!,'~'~,'~'I~; Prudhoe Bay Unit 3907' NSL, 920' WEL, SEC. 35, T11N, R13E 10. Well Number At Top Producing Interval i ~.~,'~ A~ A-41 (12-35-11-13) ~!i~ i; ,. ; ..... 11. Field and Pool At Total Depth ¢ , ~.?~~J Prudhoe Bay rie/d/Prudhoe Bay Pool 2977' NSL, 717' EWL, SEC. 35, T11N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 81.5' ADL 28286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/26/94 1/4/95 1/22/95I N/A feet MSL One :17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10375' MD/9242' TVD 10295' MD/9162' TVD YES [] NO []I 2182' feet MD 1900 (Approx.) 22. Type Electdc or Other Logs Run DIFL/BHCS/AC/GR, FMT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIFF CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 .35' 115' 30" 260 SX Arcticset (Approx.) 10-3/4" 45.5# NT-80 34' 3502' 13-1/2" 1125 sx AS 111/375 sx "G" 7-5/8" 29. 7# NT95-HS 31' 9917' 9-7/8" 265 sx Class "G" 5-1/2" 17# 13CR80 9760' 10375' 6-3/4" 110 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and :25. TUBING RECORD interval, size and number) " SIZE DEPTH SET(MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 4-1/2", 130R80 9760' 9713' MD TVD 10020'- 10060' 8888'-8928' 26. ACID, FRACTURE, CEMENT SQUEF--/F. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 1/25/95 Gas Lift Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I Flow Tu~ing Casing Pressure CALCULATED DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 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. REEEIVED FiB -? lsd§ t4aska Oil & Oa, Con~, Commi~,lon Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 30, J GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 9916' 8702' ! Shublik 9940' 8726' Sadlerochit 10017' 8803' RECEIVED FEB - ? 1995 Alaska 0il & Gas Cons. Commission 31. LIST OF ATTACHMENTS ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drilling Engineer Suz)ervisor Date ~ ~"'9~' , 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~r/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: A-41 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/25/94 04:30 SPUD: RELEASE: 01/08/95 05:00 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: 12/24/94 ( 1) TD: 0'( 0) 12/25/94 ( 2) TD: 320' ( 320) 12/26/94 (3) TD: 1222' ( 902) 12/27/94 ( 4) TD: 3510'(2288) 12/28/94 (5) TD: 3510' ( 0) MOVING RIG MW: 0.0 VIS: 0 BLOW DOWN LINES, RAISE UPPER WIND WALL, SKID FLOOR, LD DERRICK, LD "A" LEG AND WIND WALL, MOVE MOTOR OFF WELL, RIASE FEET ON SUBSTRUCTURE. MOVE OFF DS 7-32 TO A-41. TAKE ON DRILL WATER MW: 0.0 VIS: 0 TURNKEY RIG MOVE F/ DS 7-32. RIG ACCEPTED @ 0430 HRS ON 12/25/94. NIPPLE UP 20" HYDRILL AND DIVERTER LINES, TAKE ON DRILL WATER. DRILLING MW: 0.0 VIS: 0 CONTINUE NIPPLE UP 20" HYDRILL AND DIVERTER LINES. TAKE ON H20 AND MIX SPUD MUD. FUNCTION TEST DIVERTER AND ACCUMULATOR. TEST MUD LINES. MADE UP BHA #1 AND TAG @ 100'. DRILLING AND SURVEYS W/ MWD F/ 100 - 1222' CBU MW: 0.0 VIS: 0 DRILLING TO 2534'. CIRCULATED AT 2534'. OBTAINED BOTTOMS UP. POH TO 825'. RIH TO BOTTOM, NO FILL. DRILLED TO 3510' CIRCULATED. OBTAINED BOTTOMS UP. POH TO 825' -- POH T© BHA. RIH TO 3510, NO FILL. CBU PRIOR TO RUN 10 3/4" SURFACE CASING. MADE UP BHA %2 MW: 0.0 VIS: 0 CIRCULATED @ 3510'. OBTAINED BOTTOMS UP. POH TO 825'. STRAP OUT HOLE, NO CORRECTION. TIGHT HOLE @ 2080' BHA LAID OUT. RUN CASING 10 3/4" TO 3502'. RAN A TOTAL OF 86 JTS, 10 3/4" 45.5# NT80 BTC CSG, W/ FLOAT EQ, M/U AND LAND 10 3/4" FMC FLUTED HGR ON 9 5/8" LJ, FS @ 3502' AND FC @ 3420'. CIRCULATED @ 3502' MIX AND PUMP SLURRY. TEST CMT LINES DROP BTM PLUG AND PUMP 77 BBLS/375 SX, DROP TOP PLUG AND PUMP 5 BBLS H20.DISPLACED SLURRY. BUMP PLUG, FLOAT HELD. NIPPLE DOWN RISER AND DIVERTOR. NIPPLE UP BOP STACK. RIGGED UP BOP STACK. WORK COMPLETED, BOP STACK IN POSITION. RIGGED UP WELL CONTROL. INSTALL BOWL PROTECTOR. MADE UP BHA 92. FEB -7 1995 Al~s~ Oil & Gas Cons. Commi~6ion ,AJlchom.c~ : A-41 ~,FERATION: RIG : NABORS 28E PAGE: 2 12/29/94 (6) TD: 5432' (1922) 12/30/94 ( 7) TD: 7060' (1628) 12/31/94 ( 8) TD: 8347' (1287) 01/01/95 (9) TD: 9160' ( 813) 01/02/95 (10) TD: 9933'( 773) 01/03/95 (11) TD: 9933' ( 0) DRILLING MW: 0.0 VIS: 0 MADE UP BHA #2. RUN #2 BHA TO 825'. RIH TO 3410'. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. TESTED CASING. DRILLED FLOAT EQUIPMENT AND CMT + 15' NEW HOLE TO 3525'. CIRCULATED. OBTAINED CLEAN RETURNS. MWD TOOL NOT WORKING. POH TO 825'. POH TO 0.0'. PULLED BHA AND FOUND PIECE OF METAL ON PROBE ON MWD. 3 1/2" X 1/4" X 1/4", LOOKS LIKE PART OF HEAVY DUTY SCREWDRIVER. TIH TO 3525'. DRILLED TO 4993'. STARTED SCHEDULED WIPER TRIP; DUE TO FOOTAGE DRILLED. POH TO 3502'. RIH TO 4993'. DRILLED TO 5432' DRILLING MW: 0.0 VIS: 0 DRILLED TO 6420'. HAD CHANGE IN TORQUE FROM 14000 FT/LB TO 16000 FT/LB. CIT QUIT. CIRCULATED AT 6420'. HOLE SWEPT WITH SLUG. POH TO 0.0'. TIGHT F/ 5268 - 5077'. MADE UP BHA #3. P/U TANDUM MOTOR, CHANGE MWD PROBE, P/U BIT AND ORIENT. INSTALLED WEAR BUSHING. RIH TO 6330' REAMED TO 6420'. DRILLED TO 7060'. PUMP DRY JOB MW: 0.0 VIS: 0 DRILLED TO 7614'_ CIRCUALTED. HOLE SWEPT WITH SLUG. FINSIHED CIRC SwEEp. POH TO 6350' RIH TO 7614' NO HOLE PROBLEMS IN ANGLE DROP PORTION OF HOLE. DRILLED TO 8347'. -ROP DROPPED, BIT QUIT. OBSERVED DROP ON MOTOR TORQUE. CIRCULATED AT 8347'. HOLE SWEPT WITH SLUG. FINISHED CIRC SWEEPS. PUMP DRY JOB. DRILLING MW: 0.0 VIS: 0 POH TO 0.0'. MADE UP BHA #4. L/D TANDEM MOTOR AND P/U SINGLE STAGE MOTOR. ADJUST BENT HOUSING TO 3/4 DEGREE. ORIENT. RIH TO 3500'. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 8257'. REAMED TO 8347'. DRILLED TO 9160' HI-LO VISC SWEEP MW: 0.0 VIS: 0 DRILLED TO 9477' CIRCULATED. HOLE SWEPT WITH SLUG. POH TO 8225'. HOLE TIGHT AND SWABBING. WORK PIPE. RIH TO 9477'. NO PROBLEMS, RIH. DRILLED TO 9933'. DRILLED 3' OF SAG RIVER SAND. CIRCUALTED. PUMPED HI/LO VISC SWEEP PRIOR TO SHORT TRIP. RECIPROCATE PIPE MW: 0.0 VIS: 0 POH TO 7794'. HOLE PULLED SLICK OFF BTM. LAID DOWN DP TO 825'. PULLED BHA. BHA LAID OUT. NIPPLE UP BOP STACK. INSTALLED 7 5/8" PIPE RAMS AND TESTED DOORS. PULLED WEAR BUSHING. RUN CASING. RIGGED UP CASING HANDLING EQUIPMENT. RAN CASING TO 9917'. BROKE CIRC @ 10 3/4" SHOE. FC @ 9831'_ FS @ 9916~'. HOLE TAKING MUD @ 6850'. CIRCULATED AT 9917'. RECIPROCATE PIPE WHILE BREAKING CIRCULATION. ~6 -7 ~995 sas (:o~s. Gommtssion Anchom~'~ : A-41 oPERATION: RIG : NABORS 28E PAGE: 3 01/04/95 (12) TD: 9933' ( 0) 01/05/95 (13) TD:10375' ( 442) 01/06/95 (14) TD:10375' ( 0) DRILLING CEMENT @9926 MW: 0.0 VIS: 0 CIRCULATED AT 9917' CONT'D TO CIRC WITH DECREASING RETURNS. NO RETURNS. UNABLE TO RECIPROCATE PIPE. MIX AND PUMP 20 BBL LOST CIRC PILL. LOST 230 BBLS MUD WHILE CIRCULATING. TEST LINES. DROP BTM PLUG. MIS AND PUMP 54 BBLS CMT. HAD PARTIAL RETURNS WHILE DISPLACING. BUT FULL RETURNS AFTER CEMENT LEFT CSG SHOE. BUMPED PLUG @ CALC'D STROKES. FLOATS HELD. LOSS ZONE FLOWING MUD INTO CSG ANNULUS. SI TO LET STABILIZE. ROTARY ASSEMBLY FOR DRILLING 6 3/4 PRODUCTION HOLE. STRAP BHA AND PREPARE TOOLS TO P/U BHA. BLED MUD OFF ANNULUS. L/D LANDING JT AND INSTALLED 7 5/8" PACKOFF. RILDS. PACKOFF INSTALLED AND TESTED. CHANGE OUT KELLY TO 3 1/2" INSTALLED VBR IN BOP. TESTED PIPE RAMS, BLIND RAMS, CHOKE AND KILL LINE VALVES, FLOOR SAFETY VALVES AND CHOKE MANIFOLD. TESTED ANNULAR. FUNCTION TESTED ACCUMULATOR. GAS DETECTOR AT SHAKER NEEDS CALIBRATED. MADE UP BHA #5. SINGLED IN DP TO 9841'_ TAGGED PLUGS ON TOP FLOAT COLLAR @ 9841'. DRILLED CEMENT TO 9926'. PULLED BHA MW: 0.0 VIS: 0 DRILLED TO 10375'. CIRCULATED. HOLE SWEPT WITH SLUG. PMP HIGH VISC SWEEP. POH TO 9911' RIH TO 10375' CIRCULATED. OBTAINED BOTTOMS UP. POH TO 310' DROPPED EMS. DROPPED RABBIT. PULLED BHA. RIH W/ LINER ON 3 1/2" DP MW: 0.0 VIS: 0 PULLED BHA. RIGGED UP LOGGING/BRAIDED CABLE EQUIPMENT. LOGGING RUN #1. DIFL/BHCS/AC/GR FROM CSG SHOE TO 10370'. COMPLETED LOGGING RUN WITH DIFL-AC-GR FROM 9911 TO 10370' NO HOLE PROBLEMS. P/U TOOLS FOR FMT/GR FORMATION TESTER. RAN ELECTRIC LOGS. RAN 22 RFT'S AND TOOK 1 FORMATION FLUID SAMPLE. COMPLETED LOGGING RUN WITH FMT F/ 9924 - 10334'. NO HOLE PROBLEMS. RIGGED DOWN WIRELINE UNITS. RIH TO 734'. PULLED BHA. BHA LAID OUT. RUN CASING, 5 1/2" O.D. RAN CASING TO 625' RAN 5 1/2" 13CR80 LINER, FLOAT EQ, AND BLAKER LINER HANGE~ PACKER. STOPPED TO CHANGE HANDLING EQUIPMENT. RAN CASING ON LANDING STRING TO 1500' RIH W/ LINER ON 3 1/2" DP. Gas Cons. Commission Anchorar'~ : A-41 oPERATION: RIG : NABORS 28E PAGE: 4 01/07/95 (15) TD:10375' ( 0) 01/08/95 (16) TD: 10375' ( 0) 01/09/95 (17) TD: 10375' ( 0) CIRCULATING MW: 0.0 VIS: 0 RAN.CASING ON LANDING STRING TO 1500'. CIRCUALTED AT 10375'. OBTAINED CLEAN RETURNS. RECIPROCATE WHILE CIRC. MIXED AND PUMPED SLURRY. TEST LINES. SET LINER HANGER AND PACKER. RELEASED FROM LINER HANGER. RECIPROCATED WITH FULL RETURNS THRU ENTIRE JOB. REVERSE CIRCULATED CMT OFF TOP OF LINER. PULL DRILLPIPE IN STANDS TO 0.0' PULL 10 STANDS. PUMP PILL. BREAK OUT CMT HEAD. INSTALLED WEAR BUSHING. CLEAR FLOOR. MAKE UP BHA #6. RIH TO 3000'. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 10295'. CIRCULATED. OBTAINED BOTTOMS UP. TESTED CASING. TESTED LINER AND LINER LAP, OK. PMP HIGH VISC SWEEP + 65 BBLS H20. DISPLACE HOLE TO FILTERED SEAWATER COMPLETION FLUID. NIPPLE DOWN BOP STACK MW: 0.0 VIS: 0 CIRCULATED AT 10295'. FINISHED DISPLACE WELL TO COMPLETION FLUID. CLEAN SEAWATER W/ CORROSION INHIBITOR. LAID DOWN DRILL PIPE. L/D 3 1/2" DP AND COLLARS. REMOVED WEAR BUSHING. RUN SINGLE COMPLETION. RIGGED UP TUBING HANDLING EQUIPMENT. RAN TUBING TO 7577' TESTED DUAL CONTROL LINE. INSTALLED WR SSSV NIPPLE AND TESTED CONTROL LINES. FINISHED RUN COMPLETION. SPACED OUT. HANGER ASSEMBLY INSTALLED. TESTED DUAL CONTROL LINE. HANGER LANDED. RILDS. NIPPLE DOWN BOP STACK. RIGGED DOWN BOP STACK. RELEASE RIG MW: 0.0 VIS: 0 RIGGED DOWN BOP STACK. EQUIPMENT WORK COMPLETED. INSTALLED XMAS TREE. INSTALLED 4 1/16" 5K TUBING HEAD ADAPTER AND 4" CHROME TREE. TESTED ADAPTER FLANGE, TESTED TREE. RUN SINGLE COMPLETION 4 1/2" O.D. RETRIEVED HANGER PLUG. R/U LUBRICATOR AND PULLED TWO WAY CHECK VALVE. SETTING PACKER @ 9713'. PRESSURE TBG TO 4000 PSI TO SET PACKER. TUBING TEST. R/U AND PRESSURE TEST PACKER. SHEAR OUT RP VALVE. PACKER SET AND TESTED. FREEZE PROTECT WELL. FREEZE PROTECTED TBG ANG TBG ANNULUS BY U-TUBING 80 BBLS 50/50 DIESEL CRUDE INTO TUBING. FINISHED FREEZE PROTECT SURFACE CASING ANNULUS W/ 100 BBLS TOTAL DIESEL CRUDE MIX. COMPLETED OPERATIONS. INSTALLED HANGER PLUG. INSTALLED BPV. RELEASE RIG @ 1700 HRS ON 01/08/95. SIGNATURE: (drilling superintendent) DATE: Gas Cons. Commission SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU/A-41 . 500292253000 FEE) -'7 1995 NORTH SLOPE COMPUTATI ON DATE: 1 / 17~%~(~ 0i| & GaS C0ng. TRUE SUB- SEA COl/RS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES PAGE DATE OF SURVEY: 010295 MWD SURVEY JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 FT. OPERATOR: BP EXPLORATION DLS TOTAL RECTANGULAR COORDINATES VERT. DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -81.55 0 0 N .00 E .00 119 119.37 37.82 0 30 N 87.40 E .42 214 214.38 132.83 0 6 S 85.10 W .63 305 305.07 223.52 0 36 N 47.10 W .59 392 392.67 311.12 1 36 N 77.20 W 1.28 .00N .00E .00 .02N .52E -.51 .04N .85E -.83 .35N .43E -.50 .94N 1.10W .84 482 482.43 400.88 3 12 S 83.20 W 1.98 570 570.45 488.90 5 35 S 79.80 W 2.73 662 661.17 579.62 7 35 S 73.30 W 2.33 751 749.62 668.07 10 6 S 74.00 W 2.79 845 841.59 760.04 12 48 S 72.80 W 2.89 2 6 11 .92N 4.82W 4.44 .14S ll.50W 11.18 .66S 21.68W 21.66 .53S 34.89W 35.42 .87S 52.74W 54.04 940 933.69 852.14 14 53 S 72.70 W 2.21 1031 1021.53 939.98 17 36 S 76.50 W 3.17 1126 1111.52 1029.97 18 23 S 77.30 W .88 1221 1201.08 1119.53 18 42 S 76.20 W .49 1315 1289.72 1208.17 20 12 S 75.00 W 1.65 18.61S 74.42W 76.71 25.34S 99.11W 102.30 31.96S 127.59W 131.53 38.85S 156.84W 161.58 46.65S 187.16W 192.88 1409 1377.83 1296.28 22 23 S 74.10 W 2.35 1502 1462.61 1381.06 24 42 S 73.40 W 2.50 1596 1548.05 1466.50 26 23 S 73.40 W 1.79 1689 1631.20 1549.65 26 47 S 74.10 W .55 1783 1714.84 1633.29 27 17 S 72.90 W .79 55.81S 220.26W 227.22 66.16S 255.73W 264.15 77.83S 294.87W 304.96 89.48S 334.85W 346.58 101.61S 375.80W 389.25 1882 1801.14 1719.59 31 12 S 71.10 W 4.04 1976 1879.35 1797.80 35 24 S 71.00 W 4.49 2071 1956.68 1875.13 35 54 S 71.60 W .64 2167 2034.72 1953.17 36 5 S 72.00 W .32 2259 2108.73 2027.18 36 42 S 72.50 W .73 116.59S 421.74W 437.47 133.27S 470.33W 488.68 151.05S 522.87W 543.98 168.76S 576.73W 600.55 185.39S 628.70W 655.02 2355 2185.11 2103.56 36 30 S 73.80 W .84 2449 2260.21 2178.66 38 5 S 74.80 W 1.81 2545 2335.01 2253.46 39 30 S 75.50 W 1.53 2639 2407.04 2325.49 40 35 S 74.60 W 1.32 2732 2477.44 2395.89 40 17 S 71.70 W 2.06 2826 2550.31 2468.76 38 47 S 71.00 W 1.66 2920 2623.33 2541.78 38 30 S 71.70 W .57 3014 2697.36 2615.81 38 24 S 73.20 W .99 3107 2769.97 2688.42 38 5 S 73.20 W .33 3202 2845.26 2763.71 38 0 S 73.80 W .40 201.84S 682.99W 711.69 217.31S 738.06W 768.88 232.72S 796.19W 829.01 248.34S 854.69W 889.55 265.73S 912.12W 949.50 284.97S 969.13W 1009.50 303.64S 1024.46W 1067.73 321.37S 1080.50W 1126.41 337.91S 1135.30W 1183.60 354.65S 1191.80W 1242.49 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 500292253000' NORTH SLOPE COMPUTATION DATE: 1/17/95 DATE OF SURVEY: 010295 MWD SURVEY JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3297 2920.52 2838.97 3392 2995.64 2914.09 3424 3020.49 2938.94 3589 3153.07 3071.52 3682 3227.00 3145.45 37 42 S 75.50 W 1.14 370.13S 1248.19W 37 30 S 75.20 W .29 384.76S 1304.16W 37 17 S 74.80 W 1.01 389.68S 1322.51W 36 24 S 76.00 W .70 414.74S 1418.66W 38 42 S 76.30 W 2.47 428.34S 1473.84W 1300.95 1358.80 1377.80 1477.16 1533.99 3776 3299.90 3218.35 3870 3372.98 3291.43 3965 3447.05 3365.50 4060 3522.29 3440.74 4155 3597.04 3515.49 39 0 S 76.00 W .38 442.39S 1530.84W 38 47 S 76.40 W .34 456.46S 1588.11W 38. 30 S 76.20 W .34 470.49S 1645.66W 37 42 S 76.40 W .85 484.46S 1702.98W 37 42 S 76.40 W .00 498.05S 1759.13W 1592.70 1651.67 1710.90 1769.89 1827.66 4249 3671.26 3589.71 4344 3746.77 3665.22 4439 3822.86 3741.31 4535 3899.51 3817.96 4630 3975.68 3894.13 37 24 S 75.50 W .67 511.90S 1814.48W 37 24 S 75.70 W .13 526.25S 1870.40W 37 5 S 76.90 W .82 539.96S 1926.61W 36 24 S 74.60 W 1.61 554.03S 1982.07W 38 0 S 75.50 W 1.77 568.94S 2037.94W 1884.71 1942.44 2000.30 2057.52 2115.33 4726 4051.10 3969.55 4822 4126.39 4044.84 4916 4201.54 4119.99 5012 4277.41 4195.86 5107 4353.77 4272.22 38 0 S 78.50 W 1.93 582.19S 2095.33W 37 47 S 77.60 W .62 594.33S 2152.67W 37 17 S 77.80 W .54 606.63S 2209.11W 36 54 S 78.30 W .53 618.52S 2265.25W 37 0 S 76.90 W .89 630.85S 2321.34W 2174.22 2232.78 2290.51 2347.85 2405.24 5203 4430.85 4349.30 5297 4505.99 4424.44 5393 4582.29 4500.74 5488 4659.24 4577.69 5584 4736.14 4654.59 36 42 S 77.80 W .64 643.50S 2377.70W 37 5 S 77.50 W .47 655.57S 2432.81W 36 35 S 78.20 W .68 667.61S 2488.72W 36 24 S 77.60 W .43 679.54S 2544.39W 36 35 S 78.50 W .60 691.32S 2600.06W 2462.99 2519.37 2576.51 2633.41 2690.26 5679 4812.30 4730.75 5775 4888.70 4807.15 5868 4963.13 4881.58 5963 5039.03 4957.48 6058 5114.77 5033.22 36 54 S 78.50 W .32 702.66S 2655.79W 37 17 S 81.00 W 1.63 712.93S 2712.64W 37 12 S 79.60 W .91 722.47S 2768.42W 36 35 S 81.00 W 1.09 732.07S 2824.59W 37 35 S 78.70 W 1.80 742.18S 2880.96W 2747.07 2804.69 2861.09 2917.90 2975.01 6153 5189 . 75 5108 · 20 6249 5264.76 5183 .21 6340 5337.01 5255.46 6440 5417.89 5336.34 6532 5493 .75 5412.20 38 24 S 77.10 W 1.33 754.46S 2938.23W 38 0 S 76.00 W .83 768.19S 2995.63W 36 54 S 75.50 W 1.25 781.81S 3049.28W 35 5 S 73.10 W 2.29 797.68S 3105.84W 34 12 S 75.50 W 1.77 811.8~,.~,%1-6~6~.~ Kl:t i V 3033 .54 3092 .56 3147. 90 3206 .63 3259 . 04 FEB - 7 1995 Alaska Oil & Gas Cons, Commisslon Anchora.~.3 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 500292253000 NORTH SLOPE COMPUTAT I ON DATE: 1 / 17 / 95 DATE OF SURVEY: 010295 MWD SURVEY JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6630 5575.61 5494.06 6726 5656.30 5574.75 6822 5739.57 5658.02 6917 5825.71 5744.16 7013 5912.91 5831.36 33 0 S 74.10 W 1.45 826.13S 3208.78W 3313.42 31 36 S 72.40 W 1.75 840.81S 3257.62W 3364.37 27 23 S 74.50 W 4.52 854.28S 3302.76W 3411.44 24 0 S 75.40 W 3.58 865.07S 3342.79W 3452.89 23 36 S 74.80 W .49 874.96S 3379.96W 3491.35 7108 6001.34 5919.79 7204 6090.82 6009.27 7300 6181.69 6100.14 7394 6272.51 6190.96 7491 6365.52 6283.97 21 47 S 73.90 W 1.91 884.92S 3415.58W 3528.33 19 23 S 75.70 W 2.60 893.77S 3448.02W 3561.95 17 17 S 78.20 W 2.34 900.61S 3477.37W 3592.08 15 36 S 78.30 W 1.80 906.07S 3503.62W 3618.87 13 23 S 76.90 W 2.32 911.21S 3527.12W 3642.91 7586 6458.35 6376.80 7684 6554.68 6473.13 7780 6649.85 6568.30 7876 6745.02 6663.47 7970 6839.04 6757.49 11 30 S 77.60 W 2.00 915.75S 3547.11W 3663.40 9 36 S 81.20 W 2.05 919.09S 3564.72W 3681.29 7 35 S 83.40 W 2.11 921.05S 3578.98W 3695.59 5 48 S 80.80 W 1.90 922.56S 3590.06W 3706.69 4 41 S 80.80 W 1.16 923.94S 3598.58W 3715.30 8066 6934.83 6853.28 8162 7030.80 6949.25 8252 7120.62 7039.07 8352 7220.18 7138.63 8445 7313.80 7232.25 3 17 S 84.30 W 1.48 924.84S 3605.22W 3721.95 1 30 S 82.20 W 1.88 925.29S 3609.22W 3725.93 1 47 S 78.30 W .36 925.73S 3611.76W 3728.51 1 47 S 83.60 W .17 926.22S 3614.85W 3731.62 0 54 N 80.20 W 1.03 926.26S 3617.04W 3733.75 8541 7409.60 7328.05 8637 7505.03 7423.48 8733 7601.38 7519.83 8827 7695.11 7613.56 8922 7790.09 7708.54 1 0 N 85.30 W .14 926.07S 3618.61W 3735.23 1 0 N 76.40 W .16 925.80S 3620.25W 3736.75 1 0 N 84.60 W .15 925.53S 3621.90W 3738.29 0 48 N 85.80 W .21 925.40S 3623.37W 3739.68 0 48 N 77.00 W .13 925.20S 3624.68W 3740.90 9017' 7885.65 7804.10 9113 7981.01 7899.46 9208 8076.83 7995.28 9304 8172.23 8090.68 9401 8269.71 8188.16 1 0 N 89.20 W .29 925.04S 3626.16W 3742.29 0 54 N 83.90 W .14 924.95S 3627.74W 3743.80 0 48 .S 80.60 W .26 924.98S 3629.15W 3745.17 0 36 S 89.20 W .24 925.09S 3630.30W 3746.32 0 48 S 65.20 W .36 925.39S 3631.43W 3747.49 9495 8362.92 8281.3.7 9590 8458.05 8376.50 9685 8553.52 8471.97 9780 8648.71 8567.16 9851 8719.48 8637.93 0 48 S 55.70 W .14 926.03S 3632.56W 3748.74 0 48 S 53.90 W .02 926.79S 3633.65W 3749.98 0 48 S 68.80 W .22 927.43S 3634.81W 3751.26 0 42 S 66.90 W .11 927.90S 3635.96W 3752.49 0 48 S 76.00 W .22 928.18S 3636.84W 3753.41 THE THREE-DIMENSION MINIMUM CURVATURE METHOD. CALCULATION PROCEDURES ARE BASED ON THE USE OF RECEIVED HORIZONTAL DISPLACEMENT = 3753.41 FEET FEB - 7 1995 Alaska Oil & Gas Cons. Comml~lon Anrhnro~n A~ SOU~H 75 DEG. 40 MIN. WEST AT MD = 9851 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 255.68 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 500292253000 NORTH SLOPE COMPUTATION DATE: 1/17/95 DATE OF SURVEY: 010295 JOB NIIMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -81.55 .00 N .00 E .00 1000 991.01 909.46 23.05 S 89.99 W 8.99 2000 1898.69 1817.14 137.75 S 483.33 W 101.31 3000 2685.95 2604.40 318.75 S 1071.84 W 314.05 4000 3474.17 3392.62 475.63 S 1666.61 W 525.83 8.99 92.32 212.74 211.78 5000 4267.79 4186.24 617.05 S 2258.18 W 732.21 6000 5068.04 4986.49 735.44 S 2845.87 W 931.96 7000 5900.99 5819.44 873.59 S 3374.93 W 1099.01 8000 6868.30 6786.75 924.32 S 3600.96 W 1131.70 9000 7867.87 7786.32 925.05 S 3625.85 W 1132.13 206.38 199.75 167.05 32.69 .43 9851 8719.48 8637.93 928.18 S 3636.84 W 1132.21 .O8 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 · 500292253000 NORTH SLOPE COMPUTATION DATE: 1/17/95 DATE OF SURVEY: 010295 JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 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 DIFFERENCE VERTICAL CORRECTION 0 .00 -81.55 81 81.55 .00 181 181.55 100.00 281 281.55 200.00 381 381.55 300.00 .00 N .00 E .00 .01 N .19 E .00 .00 .04 N .91 E .00 .00 .18 N .61 E .01 .00 .87 N .80 W .02 .02 481 481.55 400.00 581 581.55 500.00 682 681.55 600.00 784 781.55 700.00 886 881.55 800.00 3 8 14 .92 N 4.77 W .33 S 12.58 W .45 S 24.28 W .20 S 40.63 W .58 S 61.49 W .11 .45 .19 .65 .01 .O9 .33 .75 1.46 2.36 990 981.55 900.00 1094 1081.55 1000.00 1200 1181.55 1100.00 1306 1281.55 1200.00 1413 1381.55 1300.00 22 29 37 45 56 · 33 S 87.31 W .77 S 117.86 W .27 S 150.42 W .87 S 184.25 W .23 S 221.74 W 8.60 13.43 18.86 24.79 32.11 3 .58 4.83 5.43 5.93 7.32 1522 1481.55 1400.00 1634 1581.55 1500.00 1746 1681.55 1600.00 1859 1781.55 1700.00 1978 1881.55 1800.00 68 82 96 112 133 .65 S 264.08 W .58 S 310.81 W .56 S 359.38 W .85 S 410.71 W .78 S 471.82 W 41 52 64 78 97 .43 .70 .74 .34 .43 9 11 12 13 19 .33 .26 .04 .60 .09 2102 1981.55 1900.00 2225 2081.55 2000.00 2350 2181.55 2100.00 2476 2281.55 2200.00 2605 2381.55 2300.00 156 179 201 221 242 · 74 S 539.95 W 120 .30 S 609.38 W 144 .10 S 680.45 W 169 .70 S 754.21 W 194 .54 S 833.62 W 224 .59 .41 .02 .98 .38 23 23 24 25 29 .16 .81 .61 .96 .40 2737 2481.55 2400.00 2866 2581.55 2500.00 2994 2681.55 2600.00 3121 2781.55 2700.00 3248 2881.55 2800.0.0 266 293 317 340 362 .83 S 915.42 W .13 S 992.87 W .75 S 1068.50 W .54 S 1143.99 W .48 S 1219.02 W 255.85 285.05 312.83 340.18 367.11 31.47 29.20 27.78 27.35 26.93 3374 2981.55 2900.00 3500 3081.55 3000.00 3625 3181.55 3100.00 3752 3281.55 3200.00 3881 3381.55 3300.00 382.00 401.87 419.82 438.80 458.08 S 1293.70 W S 1367.39 W S 1439.08 W S 1516.43 W S 1594.81 W 393.44 419.23 443.58 471.43 499.94 26.33 25.79 24.35 27.85 28.51 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 · 500292253000 NORTH SLOPE COMPUTATION DATE: 1/17/95 DATE OF SURVEY: 010295 JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 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 DIFFERENCE VERTICAL CORRECTION 4009 3481.55 3400.00 4135 3581.55 3500.00 4261 3681.55 3600.00 4387 3781.55 3700.00 4513 3881.55 3800.00 477.01 S 1672.26 W 495.23 S 1747.50 W 513.86 S 1822.09 W 532.78 S 1896.15 W 550.52 S 1969.31 W 527.84 554.30 580.45 606.31 631.49 27.89 26.46 26 .15 25.87 25.17 4638 3981.55 3900.00 4765 4081.55 4000.00 4891 4181.55 4100.00 5017 4281.55 4200.00 5142 4381.55 4300.00 570.09 S 2042.37 W 586.95 S 2118.63 W 603.42 S 2194.23 W 619.15 S 2268.29 W 635.59 S 2341.73 W 656 683 710 735 760 .89 .78 .22 .65 .81 25 26 26 25 25 .40 .90 .44 .43 .16 5267 4481.55 4400.00 5392 4581.55 4500.00 5516 4681.55 4600.00 5641 4781.55 4700.00 5766 4881.55 4800.00 651.57 S 2414.77 W 667.49 S 2488.18 W 683.07 S 2560.45 W 698.06 S 2633.16 W 712.08 S 2707.25 W 785 810 835 859 884 .67 .74 .11 .65 .91 24 25 24 24 25 .86 .07 .37 .54 .25 5892 4981.55 4900.00 6016 5081.55 5000.00 6143 5181.55 5100.00 6270 5281.55 5200.00 6395 5381.55 5300.00 724.99 S 2782.17 W 737.22 S 2855.90 W 753.01 S 2931.89 W 771.36 S 3008.36 W 790.29 S 3081.31 W 910 935 961 989 1014 .53 .37 .97 .19 .42 25 24 26 27 25 .62 .85 .59 .22 .23 6517 5481.55 5400.00 6638 5581.55 5500.00 6755 5681.55 5600.00 6869 5781.55 5700.00 6978 5881.55 5800.00 809.80 S 3148.27 W 827.18 S 3212.49 W 845.30 S 3272.06 W 859.81 S 3322.98 W 871.36 S 3366.73 W 1036 1056 1074 1087 1097 .35 .47 .28 .47 .24 21 20 17 13 9 .93 .12 .81 .19 .77 7087 5981.55 5900.00 7194 6081.55 6000.00 7300 6181.55 6100.00 7404 6281.55 6200.00 7507 6381.55 6300.00 882.73 S 3407.97 W 892.96 S 3444.86 W 900.60 S 3477.33 W 906.58 S 3506.10 W 912.08 S 3530.84 W 1106 1113 1118 1122 1125 .02 .11 .55 .79 .97 8.78 7.10 5.43 4.24 3.18 7609 6481.55 6400.00 7711 6581.55 6500.00 7812 6681.55 6600.00 7912 6781.55 6700.00 8013 6881.55 6800.00 916.76 S 3551.72 W 919.79 S 3569.22 W 921.54 S 3583.18 W 923.15 S 3593.72 W 924.49 S 3602.01 W 1128.25 1129.82 1130.82 1131.39 1131.74 2.27 1.58 1.00 .57 .35 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/A-41 500292253000- NORTH SLOPE COMPUTATION DATE: 1/17/95 DATE OF SURVEY: 010295 JOB NUMBER: AK-MW-40098 KELLY BUSHING ELEV. = 81.55 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 8113 6981.55 6900.00 925.10 S 3607.79 W 1131.92 8213 7081.55 7000.00 925.49 S 3610.57 W 1131.96 8313 7181.55 7100.00 926.09 S 3613.64 W 1132.01 8413 7281.55 7200.00 926.35 S 3616.54 W 1132.05 8513 7381.55 7300.00 926.11 S 3618.12 W 1132.06 .17 .04 .05 .04 .01 8613 7481.55 7400.00 925.90 S 3619.85 W 1132.08 8713 7581.55 7500.00 925.56 S 3621.56 W 1132.09 8813 7681.55 7600.00 925.41 S 3623.18 W 1132.11 8913 7781.55 7700.00 925.23 S 3624.56 W 1132.12 9013 7881.55 7800.00 925.04 S 3626.09 W 1132.13 .02 .01 .01 .01 .01 9113 7981.55 7900.00 924.95 S 3627.75 W 1132.14 9213 8081.55 8000.00 924.99 S 3629.21 W 1132.15 9313 8181.55 8100.00 925.10 S 3630.40 W 1132.16 9413 8281.55 8200.00 925.46 S 3631.58 W 1132.17 9513 8381.55 8300.00 926.17 S 3632.78 W 1132.18 .02 .01 .01 .01 .01 ~z~ 8~8~.55 8~00.00 ~.~ s ~6~.~ ~ ~.~ 9713 8581.55 8500.00 927.57 S 3635.17 W 1132.20 ~8~ 8~8~.~ 8~00.00 ~8.0~ s ~.~ w ~.~ ~8~87~ ~8 8~7.~ ~8.~8 s ~.8~ w ~.~ .. :~-~ ............ ~ .~: ...... CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS .01 .01 .01 .00 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 30 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 7 ?"-'.~'-0 J-06 (04-11-13) DESCRIPTION CN/GR FINAL BL+RF CN/GR FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF ECC No. Run # 1 493.03 Run ~ 1 5604.04 Run # 1 6031.04 Run # 1 6339.01 Run # 1 6349.01 Run ~ 1 6353.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: ~.-..,~-~ ~ ~. ~ _~,~.~:~ ~o~ R E CE IV E D ii &~chorageGaS Cons. Commission RECEIVED' JAN £ ~ 1995 Alaska Oil & G~s I:;ons. Commiss. iOn A~orage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 DIFL/GR/SP FNL BL+RF 1 BHC/AC-GR FNL BL+RF 1 FMT-GR FINAL BL+RF 1 DLL/GR/SP FNL BL+RF 1 BHC/AC-GR FNL BL+RF 1 CN/GR FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6339.00 6340.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 11 January 1995 Transmittal of Data ECC #: 6339.00 ANCHORAGE Sent by: MAIL AK, 99501. Data: LDWG Dear Sir/Madam, ~/t~~ Reference: BP ~' PRUDHOE BAY G NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Run # 1 Attn. Rodney D. Paulson Atlas Wireline Services 5600 B_Str~ ~horage, ~ 99518 Or F~o (907) 563-7803 Received by: ~/~~~ ~, _/~~~ Date:% MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Co'mmission TO: THRU: David Joh~n, Chairma~ Blair Wondzell, ~ P. I. Supervisor ~/f°/'~-r FROlVI: Doug Amos, ~u.aj ~ SUBJECT: Petroleum Inspector DATE: FILE NO: January 3, 1995 ajrhaccd.doc BOPE Test Nabors 28E BPX PBU A-41 Prudhoe Oil Pool PTD No. 94-158 Tuesday, January 3, 1995: I traveled to BPX PBU A-41 well to witness the BOPE test on Nabors 28E. As the attached BOPE test form indicates, there were 3 failures on the Methane Gas Detection System. The Rig Floor, Pipeshed and Pump Room detectors were out of calibration. All detectors were calibrated and retested on 114195. SUMMARY: Witnessed BOPE Test at BPX PBU A-41 well on Nabors 28E 4 test hours 24 valves tested 3 failures Attachment: AJRHACCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Drlg Contractor: Nabors Drilling Rig No. Operator: BP Exploration Well Name: PBUA-41 Casing Size: 10 3/4" Set @ 3,505 Test: Initial Weekly X Other 28E PTD # Rep.: Rig Rep.: Location: Sec. DATE: 1/'3/95 94-158 Rig Ph.# 659-4863 John Rail Dave Rhodes 35 T. 11N R. 13E Meridian Umiat MISC. INSPECTIONS: Location Gen.' OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes ,, , Test Quan. Pressure P/F I 500/5,000 P Well Sign OK Dri. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP I 500/5,000 P I 500/5,000 P 1 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 300/3,000 P I 500/5,000 P I 500/5,000 P I 500/5..000 P 1 500/5,000 P 2 500/5,000 P I 500/5,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector See Remarks H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes Hydraulic Chokes 1 Test Pressure P/F 500/5,000 P 48 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 ~ 2,200 3,000 I P 1,350 P minutes 22 sec. minutes 49 sec. Yes Remote: Yes Psig. Number of Failures: 3 ,Test Time: 4.0 Hours. Number of valves tested 24 Repair or Replacement'of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The following Methane Gas Detectors were not in compliance: Rig Floor, Pipe Shed and Pump Room. 1/4/1995 i was contacted by Dave Rhodes and informed that the failed gas detectors had been repaired. Distribution: orig-Well File c - Oper.IRig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: Doug Amos FI-O21L (Rev. 12/94) AJRHACCD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION December 14, 1994 TONY KNOWLES, GOVERNOR 3001 I'OR(?UI'INE DRIVE ANCIIORAGE, AI.ASKA 99501-3192 PIIONE: (907)279-1433 TELECOPY: (907)276-7542 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit A-41 BP Exploration (Alaska), Inc. Permit No: 94-158 Sur. Loc. 1371'SNL, 921'WEL, Sec. 35, TllN, R13E, UM Btmhole Loc. 2347'SNL, 761'EWL, Sec. 35, TllN, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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 (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Bllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 83.2' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28286 4. Location of well at surface 7. Unit or property Name 11. Type Bond(r~e 20 AAC 25.025) 1371' SNL, 921' WEL, SEC. 35, T11MN, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2347' SNL, 757' EWL, SEC. 35, T11N, R13E A-41 (12-35-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 2347' SNL, 761' EWL, SEC. 35, T11N, R13E 12/18/94 $200,000.00 12. Distance to nearest 113. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDand'rVD) property line ADL 47472-3709 feet No close approach feet 2560 10389'MD/9240' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~e 2o ^^c 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 3. o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30' 20" 91.5# H-40 Weld 80' 35' 35' 115' 115' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT-80 BTC 3463' 34' 34' 3497' 3083' 1125sxCSIII/375sx"G"/250sxCSII 9- 7/8" 7-5/8" 29. 7# L-80 NS CC 9919' 33' 33' 9952' 8803' 265 sx Class "G" 6-3/4" 5-1/2" 17# 13CR80 NSCC 587' 9802' 8653' 10389' 9240' 110 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 Measured depth True Vertical depth Structural RE£EIVED Conductor Surface Intermediate DEC - 8 1994 Production Alaska 0il & Gas Cons. Commission Liner Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[71 Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl'-'] 21. I hereby certifythat,the foregoing is true and correct to the best of my knowledge SignedgJJ,4E ¢ ~j~,~/,,., Title Drillin~l En~lineer Supervisor Date ' I (,.,J .... Commission Use Only Permit Number IAPI number Approval date ISee cover letter ~z7'-,,,,5'q 15o- o .z.?-. ::z. 2..5",~ /~. _.~/.~/- _ ~,;,~/> Ifor other requirements Conditions of approval Samples required [] Yes .[~No Mud Io~ reqdire%l I-I Y~s [] No Hydrogen sulfide measures [] Yes 1~/ No Directional survey requ~rea J~_ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 1~5M; I-ll0M; I-]15M; Other: Original Signed By by order of Approved by n.~.,,irt W .Inhn.qfnn Commissioner ,ne comm,ssion ~Dat, e/¢¢2 ' :orm 10-401 Rev. 12-1-85 Submit ]Well Name: IA-41 Well Plan [Type of Well (producer or injector): I Producer Summary I Surface Location: Target Location: Bottom Hole Location: 1,371' FNL 921' FEL Sec 35 TllN R13E 2,347' FNL 757' FWL Sec 35 TI 1N R13E 2,347' FNL 761' FWL Sec 35 T11N R13E I AFE Number: 14P0633 IEstimated Start Date: [ 12-18-94 IMD: 110,389' I Well Design (conventional,slimhole,etc.) I Rig: I Nabors 28-E Operating days to complete: ITVD: 19,240' I 16 I RT'GL I 35.2' I KBE: 83.2' Slimhole I Formation Markers: Formation Tops MD TVD (BKB) Base Permafrost 2159' 2028' Ugnu 4A (K-15) 4875' 4168' Top Ugnu Injection 5347' 4540' Top of Cretaceous Injection Interval Base Ugnu Injection 6438' 5400' Btm of Cretaceous Injection Interval Top S eabee/K- 10 7104' 5983' LCU/Top King/ak 8882' 7733' Sag River 9952' 8803' Oil/Gas - 7-5/8" Casing Point Top Shublik 9977' 8828' Top Sadlerochit 10047' 8898' POWC 10129' 8980' ~, ~ C E HO/I' 10202' 9053' OOWC 10239' 9090' ,.,,.,~ Zone 3 10247' 9098' t~c~ - Zone 2/2C 10332' 9183' ~aska 0il & Gas Total Depth 10,389' 9240' 150' md below OOWC VED 8 1994 ~ons. Commission )raGe casing/ umn rro ram: Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.5# H-40 Weld 80' 35'/35' 1157115' 13-1/2" 10-3/4" 45.5# NT80 BTC 3463' 34'/34' 349773083' 9-7/8" 7-5/8" 29.7# L-80 NSCC 9919' 33'/33' 9952'/8803' 6-3/4" 5-1/2" 17# 13Cr-80 NSCC 587' 9802'/8653' 10389'/9240' Tubing 4-1/2" 12.6# 13Cr-80 NSCT 9718' 32'/32' 9750'/8601' Logging Pro I Open Hole Logs: 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole ICased Hole Logs: None None BHC Sonic/DIFL/SP/GR None VHH A-41 Well Plan Page 2 Date Revised' 12/6/94 Mud Program'. Special design considerations Have APl flUid loss below 6 cc by the Kingiak Section. Surface Mud Properties: [ 13-1/2" hole section: SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss At surface 8.5 + 300 40-60 30-60 60-80 9-10 15-25 At casing pt 9.5 < 100 20-40 15-20 20- 30 9-10 15- 25 Intermediate Mud Properties: [ 9-7/8" hole section to top of Sag: LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 '] 10 tO tO tO tO tO tO tO 9.8 50 15 10 20 10 <6 Production Mud Properties: I 6-3/4" hole section: LSND Density Marsh Yield 10 sec-_ 10 min pH- Fluid (PPG) Viscosity Point gel gel Loss 8.8 20 8 2 4 9.5 <6 to to to to to to to 9.2 40 12 10 20 10 <6 Directional: I KOP: 13oo' I Maximum Hole Angle: Angle Through Target Close Approach Well' 38 degrees 0~ None The above listed wells will be secured during the close approach. 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: Cuttings Handling: CC2A Flui'd Handling: Annular injection. Annular Injection: Use the following table as a reference for permitted wells. DO NOT EXCEED 35,000 BBLS IN THE ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) ~ A-39 2875 35,000 1/1/94-12/31/94 VCQA A-40 3930 35,000 1/1/94- 1 2/31/94 VCQA, A-41 0 35,000 1/1/94-12/31/94 VHH A-41 Well Plan Page 3 Date Revised' 12/6/94 _~loe ~ udhoe A-PAD A-41 ~ av Bay Unit , . . o o , o . 10. 11. PROPOSED DRILLING AND COMPLETION PROGRAM WELL A-41 MIRU. NU diverter and function test same. Drill 13-1/2" hole to + 3,497' md/3,083' tvd. Run and cement 10-3/4" 45.5//NT-80 BTC casing to surface. Install blowout prevention equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer. Function test BOPE to 5,000/250 psi. Test 10-3/4" casing to 3,000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill 9-7/8" hole to the top of the Sag River @ + 9,952' md/8,803' tvd. Run %5/8" 29.7# L-80 NSCC casing string and cement with Class G cement to 1,000' md above the casing shoe. Test casing to 3,500 psi. Drill a 6-3/4" hole 10' outside of 7-5/8" casing and test the formation to a minimum of 0.5 ppg over the mud weight to be used to drill the hole section. Drill the 6-3/4" hole to the target of Zone 4 at + 10,047' md/8,898' TVD and TD the well at + 10,389' md/9,240' tvd. Run DIL/BHCS/SP/GR wireline logs across open hole. Run 5-1/2" 174/13CR80 NSCT liner with liner hanger & liner top packer. Liner will be set at TD and lapped +150' inside 7-5/8" casing shoe. Make a cleanout run to the 5-1/2" landing collar and test the casing and liner to 3,500 psi. Displace well with filtered seawater and corrosion inhibitor. Run 4-1/2" 13CR80 tubing with SSSV, GLM's, and 7-5/8" packer assembly. Set packer and test tubing annulus w/3,500 psi. Set BPV. ND BOPE. Freeze protect well to 2100' TVD through shear valve in top GLM station. Release rig. Drilling Hazards · No hydrocarbon-beating zones above the Sag River formation based on A Pad logs. · Losses have been encountered drilling the Kingiak, Sag River, and Sadlerochit formations on A pad. · A minimum of 9.8 ppg mud weight will be used to drill the Cretaceous injection interval. This will allow a 100 psi trip margin over the expected 9.3 ppg EMW @ 4455' sswd. Well Plan Summary RECEIV£D DEC -' 7 1994 0i~ & Gas Con~. Commi~lon m "~_-- ~ ~--- ~ 3728 ~I._J_72Ef_~ __ i : , HD / T 9240 I ~ ~ -~ ~'¥2B ~ --' C -500 0 500 1000 1500 2000 2500 3000 3500 4000 VERTICAL SECTION PLANE: 256.00 Ta~ NS EW Geid X Na~e TV~ TARGET 8898 903 ~ 3622 ~ 650850 5948100 PROPOSED BHLl TVD 9240.20 MD 10389.03 VS 3727.72 N/S 901.82 E/W 861~.99 WELLPLAN FEASIBILITY STUDY This plan is for feasibility proposes only, it has not yet been certified. WELL PERMIT CHECKLIST FIE .D, POO,. INIT CLASS UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE ~ ADMINISTRATION ENGINEERING 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 drilling 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 administrative approval.. 13. Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 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 ............. x~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... Y~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate . N 25. BOPEs adequate ..................... --~_ N 26. BOPE press rating adequate; test to ~%~ psig. N 27. Choke manifold complies w/~PI RP-53 (M~y 84) ....... 28. Work will occur without operation shutdown ....... ~ 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ / Y N 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z HOW/jo - A:~FORMS%cheklist rev 03/94 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. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6339.00 K. RICHARDS D. BOYER REMARKS: OPEN HOLE A- 41 500292253000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES il-JAN-94 RUN 2 RUN 3 35 liN 13E 1373 920 81.55 80.00 47.40 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 9917.0 6.750 10375.0 DIFL/AC/GR. CIRCULATION STOPPED AT 0200, 05-JAN-95. DUE TO COMPUTER LOCK-UP, THE RECORDED DATA FOR THE REPEAT PASS WAS CORRUPTED & IS UNAVAILABLE. THE CASED HOLE GAMMA RAY PASS WAS RECORDED USING THE FMT TOOL STRING. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (6.75"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9900.0 BCS 9900.0 DIL 9900.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA GR STOP DEPTH 10320.0 10339.0 10367.0 all runs merged; (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH LL8 9904.5 9908.5 9909.5 9911.0 9911.5 9921.5 9926.5 9927.5 9928.0 9943.0 9960.0 10000.5 10002.0 10025.5 10042.5 9931.0 9935.0 9937.0 9938.0 9938.5 9939.0 9943.0 9943.5 9947.0 9947.5 9949.0 9960.0 9975.5 9976.0 9985.5 9986.5 9993.5 9999.0 10001.0 10002.5 10006.5 10010.5 10013.5 10018.0 10021.0 10025.5 10026.0 10034.5 10041.0 10043.0 10045.5 10048.0 ILD DT 9904.5 9908.0 9908.5 9910.0 9911.0 9922.0 9925.5 9926.0 9927.0 9930.0 9934.5 9936.0 9937.0 9938.0 9938.5 9947.5 9948.0 9974.5 9976.0 9985.5 9986.0 10005.0 10010.5 10014.0 10017.5 10026.5 10034.0 9943.5 9949.0 9960.0 9994.0 9999.5 10021.0 10025.5 10045.0 10041.0 10048.0 no case 10048.5 10048.5 10057.5 10058.0 10058.0 10058.0 10075.5 10075.5 10079.0 10081.5 10081.5 10086.0 10095.5 10097.5 10096.0 10103.0 10105.0 10104.0 10105.5 10105.0 10118.5 10118.5 10118.5 10121.5 10122.5 10129.5 10129.5 10137.0 10144.5 10144.5 10147.0 10153.5 10153.0 10159.0 10158.0 10166.5 10165.5 10170.0 10170.0 10170.5 10170.5 10171.5 10177.5 10182.5 10208.5 10208.5 10258.0 10263.5 10263.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 3 BCS 1 3 DIL 1 3 $ REMARKS: 10079.0 10085.5 10095.0 10103.0 10118.0 10129.0 10136.5 10143.5 10146.5 10171.5 10177.5 10182.0 10208.0 10258.0 MERGE TOP 9900.0 9900.0 9900.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. MERGE BASE 10320.0 10339.0 10367.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3. OUT $ CN : BP EXPLORATION WN : A - 41 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL8 DIL 68 1 OHMM 4 6 ILM DIL 68 1 OHI~M 4 7 ILD DIL 68 I OHMM 4 8 RT DIL 68 1 OHMM 4 9 DI DIL 68 1 IN 4 10 SP DIL 68 1 MV 4 11 MTEM DIL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 48 Tape File Start Depth = 10400.000000 Tape File End Depth = 9900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12013 datums Tape Subfile: 2 215 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: .5000 START DEPTH 9295.0 STOP DEPTH 9900.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE GAMMA RAY PASS. CN : BP EXPLORATION WN : A- 41 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 990 60 6 4 4 10 579 41 1 4 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) Total Data Records: 20 1014 BYTES * Tape File Start Depth = 9900.000000 Tape File End Depth = 9292.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4869 datums Tape Subfile: 3 47 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9813.0 10343.0 AC 9831.0 10361.0 DIFL 9854.0 10390.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMARAY BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 05-JAN-95 FSYS JlV2 BETA RELEASE 4 200 05-JAN-95 1059 05-JAN-95 10375.0 10370.0 9300.0 10367.0 2100.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 6.750 9917.0 9900.0 LSND 9.00 47.0 9.5 6.0 195.0 3.100 .750 2.980 42.0 195.0 42.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : A - 41 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA .000 .0 2.320 42.0 .000 .0 .00 .000 1.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 SPD AC 68 1 F/MN 4 11 RFOC DIFL 68 1 OHMM 4 12 RILM DIFL 68 1 OHMM 4 13 RILD DIFL 68 1 OHMM 4 14 CILD DIFL 68 1 MMHO 4 15 VILD DIFL 68 1 MV 4 16 VILM DIFL 68 1 MV 4 17 RT DIFL 68 1 OHMM 4 18 DI DIFL 68 1 IN 4 19 SP DIFL 68 1 MV 4 20 TEMP DIFL 68 1 DEGF 4 4 06 969 49 4 48 852 89 4 81 285 47 4 81 285 47 4 81 285 47 4 81 285 47 4 81 285 47 4 95 558 30 4 95 558 30 4 61 094 30 4 27 515 24 4 06 213 78 4 04 903 06 4 34 704 23 4 04 522 10 4 04 522 10 4 04 903 06 4 06 213 78 4 53 419 67 4 40 467 34 6 1 0 0 0 0 0 1 1 1 6 0 0 6 6 6 0 0 0 0 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 203 Tape File Start Depth = 10400.000000 Tape File End Depth = 9792.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63107 datums Tape Subfile: 4 280 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 34 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9293.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9912.0 05-JAN-95 FSYS JlV2 BETA RELEASE 4 200 05-JAN-95 2212 05-JAN-95 10375.0 10370.0 9300.0 10367.0 2100.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BYPS BYPASS SUB CHT CABLEHEAD TENSION GR GAMMA RAY FMT FORM. MULTI-TESTER $ TOOL NUMBER 1950XA 3974XA 1309XA 1966EA/1966MB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 9917.0 9900.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: LSND 9.00 47.0 9.5 6.0 210.0 3.100 .750 2.980 .000 2.320 .000 42.0 195.0 42.0 .0 42.0 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): . 0 REMARKS: CASED HOLE GAMMA RAY PASS. THIS PASS WAS RECORDED USING THE FMT TOOL STRING. $ CN : BP EXPLORATION WN : A - 41 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GR GR 68 1 GAPI 4 2 CHT GR 68 1 LB 4 3 TTEN GR 68 1 LB 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) Total Data Records: 41 1014 BYTES * Tape File Start Depth = 9933.000000 Tape File End Depth = 9292.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15130 datums Tape Subfile: 5 108 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 95/ 1/11 01 **** REEL TRAILER **** 95/ 1/11 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 11 JAN 95 3:55p Elapsed execution time = 6.37 seconds. SYSTEM RETURN CODE = 0
