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Home My WebLink About199-0821a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 918'FNL, 1205' FEL, Sec 29, T11N, R15E, UM 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 28 BF: surface Total Depth: 637'FNL, 1091'FEL, Sec 29, T11N, R15E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 n/a (ft MSL) 22.Logs Obtained: MWD, CCL/GR, Mem Induction/GR/RST, Mem GR/CCL 23. BOTTOM 20" H-40 112 13-3/8" L-80 2673 9-5/8" L-80 6661 7" L-80 8388 2-3/8" L-80 8746 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: not on production Method of Operation (Flowing, gas lift, etc.): n/a Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Prudhoe Bay, Prudhoe Oil none Oil-Bbl: Water-Bbl: Oil-Bbl: 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 Flow Tubing Gas-Oil Ratio:Choke Size: see attachment Water-Bbl: PRODUCTION TEST Date of Test: Per 20 AAC 25.283 (i)(2) attach electronic information 47 6430 surface 11582 94 72 112 surface 9642 CASING WT. PER FT.GRADE 29 700941 701046 TOP SETTING DEPTH MD surface 9307 TOP 12-1/4" 3" surface 17-1/2" 260 Sx PF surface 707282 5952287 2200 Sx Foundu& 400 SX PFII 9/13/199 CEMENTING RECORD 5955909 approx 1900 SETTING DEPTH TVD 5956193 70-054 9/6/1999 12401 / 8870 surface / surface 58 HOLE SIZE AMOUNT PULLED ADL 028326 & 028325 PBU 11-25A 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 11/1/2020 199-082 / 319-339 50-029-20488-02-00 4708'FNL,250'FEL, Sec 28, T11N, R15E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 8988 11578 / 8384 32" 4.6 12 bbls 15.6 ppg Class G BOTTOM 114205-1/2" 17# L-80 SIZE DEPTH SET (MD) 11335 / 8145 PACKER SET (MD/TVD) 3-1/2" 9.2# N-80 TUBING RECORD 15.5 bbls 15.8ppg LARC &6215 500Sx Class G 12363 surface 3034 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 550Sx Class G8-1/2" Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 5:29 pm, Dec 02, 2020 RBDMS HEW 12/3/2020 Abandonment Date 11/1/2020 HEW xGDSR-12/3/2020 11,582 12,363 SFD 12/3/2020 6,216 6,431 8,845 DLB 12/03/2020 MGR24DEC2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 12035 8680 11442 8251 11481 8289 11539 8346 12035 8680 12178 8751 12279 8800 12279 8800 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Bo York Contact Name: Aras Worthington Operations Manager Contact Email:Aras.Worthington@hilcorp.com Authorized Contact Phone:(907) 564-4763 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Base of Sadlerochit The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled 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. 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. 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. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Zone 2A Sag River Sand Zone 1B Signature w/Date: Shublik Top of Sadlerochit If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.02 14:26:26 -09'00' Bo York ALL STRINGS CUT 4' 3" BELOW TUNDRA ELEV. ALL STRINGS CEMENTED TO SURFACE & MARKER PLATE INSTALLED. 11/01/2020 ABANDONED ACTIVITYDATE SUMMARY 11/16/2019 ***WELL S/I ON ARRIVAL***(P&A) TAGGED FILL (formation sand) W/ 2-1/2" DUMMY GUN & S. BAILER @ 8992' SLM DRIFT TO 8988' SLM W/ MAXFIRE PRESS/TEMP DRIFT & 2.85" CENT. ***CONT. ON 11/17/19 WSR*** 11/17/2019 ***CONT. FROM 11/16/19 WSR*** (P&A) PUNCH TBG W/ HES MAXFIRE & 5' TUBING PUNCH (4 SPF, 0 PHASE) FROM 8907'-8912' SLM. ATTEMPT TO CIRC TBG X IA W/ TRIPLEX. HELD 1000 PSI / 15 MINS. NO CIRC PATH. ***JOB INCOMPLETE, WELL LEFT S/I*** 1/15/2020 T/I/O=400/90/105 (LRS unit 76 Circ out) Pumped a total of 7.4 bbls amb diesel down IA and OA tracked 1 to 1 psi. PT'd IA/OA to 2200 psi per WSL Jerry Lau for 15 min. IA/OA lost ~ 48/48 psi in 15 min. See log for details. Bled IAP and OA tracked 1 to 1. Bled back ~ 5 bbls. Pumped a total of 20 bbls diesel down the TBG and established a LLR ~ 2230 psi @ 2.5 bpm. FWHP=700/100/110 SV,WV,SSV shut MV,IA,OA Open 1/17/2020 T/I/O = 440/100/120. Temp = SI. Injectivity Test / Cement C&B Lines (pre P&A). AL spool removed. Control line = 380 psi. Balance line = 380 psi. Pumped hydraulic fluid down both C&B lines, both pressured up instantly and bleed off slowly. Job postponed til after circ out. Final WHPs = 440/100/120. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 09:00 1/20/2020 Heat Upright (PLUG AND ABANDONMENT) Heat Brine to 140* 1/30/2020 heat Upright tank to 140*. 2/10/2020 LRS Unit 42 Heat UR 077 with 9.8 brine to 135* 2/20/2020 LRS Unit 46 Heat Upright of Brine (PLUG AND ABANDONMENT) Heat upright of 9.8 ppg brine to 140*. 4/26/2020 T/I/O= 454/98/107 LRS UNIT 72 (INJECTIVITY TEST - P&A) Pump 3 bbls 60/40, 58 bbls diesel, 353 bbls 1% kcl down tbg for injection test. See log for details. Pump 58 bbls 160* diesel down tbg for freeze protect FWHPs=550/745/740 ***Job Complete*** 4/26/2020 Job Scope: Cement Control & Balance lines (Plug & Abandon). RU immediately after LRS injectivity test. Pumped 2.5 gallons of D-163 ultra fine squeeze @ 14 PPG down control line. Pumped 2.5 gallons of D-163 ultra fine squeeze @ 14 PPG down balance line. 5/11/2020 T/I/O=365/100/111 Assist Cement Pump 1 bbls 50/50 through hardline to tank to clear water from SLB PT. Pump 5 bbls 50/50 followed by 157 bbls 9.8# brine down tbg to spot cement. FWHPs=1090/357/355 5/11/2020 SLB Cementers - Reservoir Cement Plug (PLUG AND ABANDONMENT) ***LRS in control of well upon arrival. See LRS WSR 05-11-20 for more details*** LRS pumped 50/50 down tubing to verify injectivity. SLB Pumper the following down the tubing: 10 bbls fresh water spacer, 122.5 bbls 15.8 ppg Class G Cement, 2.5 bbls fresh water, Dropped 7" foam ball, 2.6 bbls fresh water. LRS displaced with 157 bbls 9.8 ppg NaCl. ***LRS in control of well upon departure*** Est. TOC in TBG @ ~7000' MD Est. TOC in IA @ ~7720' MD Est. BOC in T/IA @ ~8912;' MD 5/12/2020 Cost placeholder for foam wiper balls Daily Report of Well Operations PBU 11-25A Daily Report of Well Operations PBU 11-25A 5/16/2020 T/I/O=0/50/50 temp=SI Assist S-line (PLUG AND ABANDONMENT) Road unit to location, Spotted equipment,PJSM *** WSR continued on 05/17/20*** 5/17/2020 ****WELL S/I ON ARRIVAL****(P&A) MIT-T TO 2500 psi (pass) DRIFT TO TOC WITH 2' 2-1/8" STEM, 3" S-BAILER @ 6637' SLM (sample of cement) LRS PERFORM CMIT-IA x OA TO 2500 psi (PASS) RAN 2' x 2-1/8" WB, 3.00" SAMPLE BAILER, TAGGED TOC @ 6637' SLM(aogcc witnessed/Brian Bixby) LRS PERFORMED PASSING MIT-T TO 2631psi.(aogcc witnessed/Brian Bixby) PUNCH TUBING 3175' MD - 3180' MD. ATTEMPT TO GET COMMUNICATION TO VERIFY HOLES IN TUBING ****CONT WSR ON 5-18-20**** 5/17/2020 *** WSR continued from 05/16/20*** Pre-AOGCC MIT-T*** PASSED*** to 2552 psi Max Applied Pressure= 2700 spi Target Pressure=2500 psi. Pressured TBG to 2687 psi with 1 bbls of 50/50 meth. MIT- T lost 60 psi in the 1st 15 minutes , 33 psi in the 2nd 15 minutes, 24 psi in the 3rd 15 minutes and 18 psi in the 4th 15 min. for a total loss of 135 psi during a 60 minute test. Bleed TBG pressure to 100 psi recovering ~ 1.6 bbls. CMIT-IA/OA *** PASSED*** to 2565/2571 psi. Max Applied Pressure=2700 psi Target Pressure= 2500 psi. Pressured IA/OA to 2649/2657 psi with 8.3 bbls 50/50. CMIT- IA/OA lost 41/42 psi in the first 15 minutes , 24/25 psi in the 2nd 15 minutes and 19/19 psi in the 3rd 15 min for a total loss of 84/86 psi during a 45 minute test. Bled IA/OA to 0/75 psi rcovering ~ 8 bbls. AOGCC MIT-T to 2631 psi ***PASSED*** Took Tbg to 2741 psi w/ 2.4 bbls 50/50 meth. Tbg lost 77 psi in 1st 15 mins and 33 psi in 2nd 15 mins for a total loss of 110 psi in 30 min test. Bled Tbg to 16 psi and got back 1.7 bbls. Witnessed by State Rep Bixby and WSL Boyles. Pumped 10.4 bbls of 50/50 meth down TBG for TBG punch (SEE LOG FOR DETAILS) *** WSR continued on 05/18/20*** 5/18/2020 *** WSR continued from 05/17/20*** Pumped a total of 16.65 bbls 50/50 down TBG and IA in an attempt to clear TBG punch (SEE LOG FOR DETAILS).Held pressure on Tbg while Slickline perfed Tbg. SLine in control of well per LRS departure. FWHP's=vac/280/290 IA,OA=OTG 5/18/2020 ***CONT WSR FROM 5-17-20***(p&a) LRS CONFIRMED NO TBG/IA COMMUNICATION. RAN SLB E-FIRE W/ 5' x 1.56" TBG PUNCH/MPD/SPD, PUNCHED TBG @ 3170'- 3175' MD.(tbg/ia communication) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 5/19/2020 T/I/O=20/320/320 Circ Out Well (PLUG AND ABANDONMENT) Circ Out well w/ 5 bbls 60/40, 75 bbls Surfactant and 220 bbls 9.8.Brine. pumping down Tbg. taking returns up IA to tanks. Pump 47 bbls 9.8 Brine down Tbg. taking returns up OA to tanks to establihs LLR of 400/300/180 @ 5 BPM. FWHP=3/16/7 SV,WV,SSV shut MV,IA,OA Open. CMIT-IA/OA *** PASSED*** to 2565/2571 psi. Daily Report of Well Operations PBU 11-25A 5/21/2020 SLB Cementers - TxIAxOA Surface Cement PLug (PLUG AND ABANDONMENT) SLB Took control of the well upon arrival ***LRS on location as standby for contingency displacement, See AWGRS 5/21/20*** SLB pumped 5 bbls 60/40 dow tubing to verify flowpath. SLB Pumped the following down the tubing taking returns out the OA to OTT: 10 bbls Fresh water, 227.3 bbls, 15.8 ppg Class G Cement SLB Pumped the following down the tubing taking returns out the IA to OTT: 57.8 bbls 15.8 ppg Class G Cement SLB Pumped the following down the tubing taking returns out the OA to OTT: 7.2 bbls, 15.8 ppg Class G Cement *** SWAB, SSV, IA & OA CSG Valves shut in upon departure*** Est. TOC in TBG @ ~0' MD Est. TOC in IA @ ~0' MD Est. TOC in OA @ ~0' MD Est. BOC in TBG & IA @ 3175' MD Est. BOC in OA @ ~ 974' MD 5/21/2020 Assist Cementers (PLUG AND ABANDONMENT) Contingency pump for cement job 5/25/2020 T/I/O = 0/0/0. Temp = SI. WHPs (post cement job). AL spool dropped. No wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 5/30/2020 RD Upper tree, RU Tree cap w/ lifting eye to MV. RD IA and OA, RU intergal and 1502 cap. RDMO. ***Job Complete***. 10/26/2020 Permanent Plug and Abandon *** Excavate around wellhead down to 14.5' below pad grade. Pad elevation @ 28.5'. Tundra elevation @ 20'. Covered excavation with rig mats and put up barriers. Will return to install shoring box. Job In progress. 10/27/2020 **P&A continued** Finished excavation and installed shoring box. Excavation Depth is 14.5'. Covered excavation rig mats and barriers. Prepped saw and tools for the next day. Job In progress. 10/28/2020 ***P&A continued*** Pad elevation is 28.5' and Tundra elevation is 20'. Excavation is 14.5' below pad grade. Cut all strings and wellhead off 4' 3" below tundra elevation. Whitnessed by AOGCC Rep Lou Laubenstein. TBG cement top is 15' 3 " below surface, IA cement is at surface, OA cement is at surface, Surface casing x conductor is 21' 4" to hard bottom. Pictures taken to document. Job In progress. 10/30/2020 *** P&A Continued*** Top off TBG and Conductor with AS-1 cement. TBG=16 gallons os AS-1 cement used to top off. Conductor= 160 gallons of AS-1 cement used to top off. Allow cement to cure fro 24 hours. Job In progress 11/1/2020 ***P&A continued*** AOGCC Rep. Bob Noble whitnessed the cement top and marker plate. Welded marker plate to conductor, pulled shoring box and back filled excavation. Final depths are Pad elevation =28.5'. Tundra elevation=20' all strings and well head cut 4' 3" below tundra elevation, marker plate welded onto conductor. Pictures taken to document cement top and marker plate. Job Complete. @ Est. BOC in OA @ ~ 974' MD bbls, 1 OA to OTT: 7.2 WELL NAME: 11-25A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8938 Pull Plug 8907-8912 Tubing Punch 122.5 bbls 15.8 ppg Class G Cement 3175 - 3180 Tubing / Casing Punch 292.3 bbls 15.8ppg Class G Cement surface 16 gallons Arictic Set 1 Cement 6637 surface Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well 11-25 (PTD 199-082)Sundry #:319-339Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCCby the rig workover (RWO) “first call” engineer.AOGCC written approval of the change is required before implementing the change. SecPageDateProcedure ChangeNew 403 Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC Written Approval Received (Person and Date)N/AN/A04/23/2020Combined reservoir cement plug and intermediate cement plug into one cement job to plug reservoir and PC leak at the same timesince reservoir was already pluggedwith creataceous sand.NAJWAJWMel Rixse 04/23/2020N/AN/A04/23/2020Added tubing punch @ ~3200’MD to circulate the final cement job to surface and adjusted cement volumes accordingly.NAJWAJWMel Rixse 04/23/2020N/AN/A04/23/2020Added circulating cement up the OA on the final cement job since the OA was not already cemented fully.NAJWAJWMel Rixse 04/23/2020Approval: Bo YorkAsset Team Operations Manager DatePrepared: Aras WorthingtonFirst Call Operations Engineer DateDigitally signed by ArasWorthington (4643)DN: cn=Aras Worthington (4643),ou=UsersDate: 2020.11.25 12:18:11 -09'00'ArasWorthington(4643)Digitally signed by Bo YorkDN: cn=Bo York, c=US, o=HIlcorpAlaska LLC, ou=Alaska NorthSlope, email=byork@hilcorp.comDate: 2020.11.25 12:21:33 -09'00'Bo YorkNote, these changes were conducted un-der BP operational control. Therefore,digital signature "approving" thesechanges by York is not an approval butan acknowledgment that the changeswere made. Comment by York on 25 Nov2020. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� fO��' DATE: 11/1/2020 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment - Final Petroleum Inspector PBU 11-25A - Hilcorp North Slope PTD 1990820; Sundry 319-339 11-1-2020: 1 traveled to Hilcorp's PBU 11-25A and met with Hilcorp representative Jaycen Sala. We talked about what they had done to get cement to surface. He said Lou had been out to inspect it before they topped it off (10/28/2020). inspected the cut off which was at 4.25 feet below tundra grade. The marker plate was found to have the proper information as required in regulation, except the field (PBU) f was included in the well name. I asked them to weld "PBU" in front of 11-25A which they did. The 3/8 -inch thick marker plate was sized correctly to be welded onto the outermost pipe (20 -inch conductor). I gave to ok to weld the maker plate to the well and backfill the excavation. Attachments: Photos (2) ' 2020-1101_Surface_Abandon_Final_PBU_11-25A_ bn.docx Page I of 2 Surface Abandonment (Final) — PBU 11-25A (PTD 1990820) Photos by AOGCC Inspector B. Noble 11/1/2020 2020-1101_Surface_Abandon_Final_PBU_11-25A_ bn.docx Page 2 of 2 Marker Plate Missing Field Name "PBU") Marker Plate — Corrected; Installed MEMORANDUM TO: FROM: Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission 11 1 IV ( W& DATE: 10/29/2020 Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector PBU 11-25A - Hilcorp North Slope LLC PTD 1990820; Sundry 319-339 10/28/2020: 1 arrived on location and met with Jaycen Sala (Hilcorp) for the wellhead cut off inspection. The tubing had a void of 182 inches to the top of cement and the sealed conductor had a void of 259 inches to top of cement. There was good cement in the IA and OA. Hilcorp will top off the conductor and tubing with cement and call for a follow-up inspection when completed. Attachments: Photos (3) 2020-1028_Surface_Abandon_PBU_ 11-25 A_11.docx Pagel of 3 0 U 0 �O �Qo d -c o ON 000 `C O N 3 O N 0- T_ I 00 N Cl 00 N O MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l\� SIZ7{zvz� P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Section: 28 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Jerry Boyles Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 13 3/8" O.D. Shoe@ Intermediate: 9 5/8" O.D. Shoe@ Production: 7" O.D. Shoe@ Liner: 2 3/8" _ O.D. Shoe@ Tubing: 5.5' x 3.5' . O.D. Tail@ Plugging Data: Test Data: DATE: May 7, 2020 SUBJECT: Well Bore Plug & Abandonment PBU 11-25A - BPXA PTD 199820; Sundry 319-339 11N Range: 15E Meridian: Umiat n/a Total Depth: 12401 ft MD Lease No.: ADL 028325 Suspend: P&A: X 111 - Feet 3036 Feet 9642 Feet 11578 Feet 12363 Feet 11420 Feet 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 Fill 8907 ft MD 6637 ft MD 9.8 ppg brine Wireline tag initini 15 min 30 min 45 min Result Tubing 2741 - 2664 2631 IA 54 - 55 55 P OA 83 84 84 Initial 15 min 30 min 45 min Kesurt Tubing IA OA Remarks: Witnessed SL tag. From BPXA P&A procedure 4.1, best estimate is plug is founded on fill at 8907 ft MD where tubing punch is located. Witnessed good cement from bailer. String weight 390 pounds and set down with bailer numerous times with 250 pounds. Pretest pressures T/1/0 were 0/47/77 psi. Bbls IN = 2.4, Bbls OUT = 1.7 Attachments: none rev. 11-28-18 2020-0517_Plug_Verification_PBU_11-25A_bb March 19, 2019 VbpAlaska Oil &Gas Conservation Commission 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 f Reference: MAR 19 -019 API# 50-029-20488-00 / -01 / -02 A O G C C PTD # 180-073 / 187-011 / 199-082 Mr. Steve Davies, The operator respectfully requests that the following wells within the Prudhoe Bay Unit be re -named as follows. r'nrrent Names NPw Namp Permit To Drill API # 11-25 11-14 180-073 50-029-20488-00-00 11-25A 11-25 187-011 50-029-20488-01-00 11-25B 11-25A 199-082 50-029-20488-02-00 This request reverses our naming change from 2012. This reversal will preserve the association to both the historical data and the originally submitted state documents. If you have any questions or need additional information, please don't hesitate to let me know. Sincerely, o l� o" - Joe Lastufka Sim Specialist — BP Exploration 564-4091 Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Request naming change July 16, 2019 To Whom it May Concern: The operator respectfully requests that the following wells within the Prudhoe Bay Unit be re -named as follows: Current Name New Name Permit # API # PBU 11-25 PBU 11-14 180-073 50-029-20488-00-00 PBU 11-25A PBU 11-25 187-011 50-029-20488-01-00 PBU 11-25B PBU 11-25A r 199-082 50-029-20488-02-00 The wells were renamed per operator's request in 2012. Due to an impending Abandonment we request to maintain the historical naming. Please let me know if you have any questions or concerns. Sincerely, Joe Lastufka BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 THE STATE °fALASKA. GOVERNOR MIKE DUNLE.AVY Aras Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 11-25A Permit to Drill Number: 199-082 Sundry Number: 319-339 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �L Je'Ssie L. Chmielowski Commissioner DATED this Z6 day of July, 2019. RBDMSLw"JUL 2 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 07'5 7 /Z-sh i JUL rig 1. Type of Request. Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0, 5. Permit to Drill Number: 199-082 • 3_ Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-20486-02-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 11-25A • 9. Property Designation (Lease Number). 10, Field/Pools: ADL 028325'& 028328 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12401 8870 8938 6162 8938 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 -111 31 -111 1530 520 Surface 3005 13-3/8" 31 -3036 31 -2674 5380 2670 Intermediate 9613 9-5/8" 29 - 9642 29-6661 9-6661 6870 4760 Liner 2271 7" 9307 - 11578 6430 - 8384 8160 7020 Liner 3375 2-3/8" 8988-12363 6215 -8846 Perforation Depth MD (ft): Pertpretion Depth ND (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 12094 - 12278 8709-8798 5-1/2" 17# x 3-1/2" 9.2# L-80 / N-80 27-11420 Packers and SSSV Type: 3-1/2• Baker FB -1 Packer Packers and SSSV MD (ft) and ND (ft): 11334 / 8145 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Straagraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: October 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Aivano, Mike be deviated from without prior written approval. Contact Email: Mike Aivano@bp.com Authorized Name: Worthington, Area Contact Phone: +1 907 564-5475 Authorized Title: Interventigpefi Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approv iL Notify Commission so that a representative may witness Sundry Number: 35101 Plug Integnryr�//A BOP Test ❑ Mechanical IntegrityTest❑ Location Clearan 1ce Other: •C aloeo ww#1 III LsrNGw t(SJ'zl¢'e a-r-Q� vh.o.��-✓ e ill Post Initial Injection MIT Req'd? Yes ❑ No ❑ /. R BDMS 1 Spacing Exception Required? Yes 13 No tjd Subsequent Form Required:/D„ tJnl7 �U� 2 6 2019 7" ✓ ` APPROVED YTHE Approved by: COMMISSIONER COMMISSIONDate. J ORIGINAL Form 10-003 Revised 04/2017 Approved application is valid for 12 months from the date of approval. rn 62t�k1� Submit Form and Attachments in Duplicate 11-25a P&A Sundry Intervention Engineer Mike Aivano (907) 564-5475 / (907) 885-9190 Reviewed by Aras Worthington (907) 564-4102 Production Engineer Travis Alalato (907) 564-5351 Expected Start Date October 2019 History: The well was originally drilled as PBU 11-14 (PTD# 180-073) in 1980 but was never produced, i was side tracked through the 9-5/8" production casing at -9628' and re -completed in 1987 as PBU 11-25 (PTD# 187-011). In 1999, the well was side tracked again with coil tubing and completed with 2-3/8" liner as well PBU 11-25a (PTD# 199-082). The 5-1/2" tubing has a patch at 7679' MD with an IBP below it that when last tested in 2011, was holding. There is a known PC leak at -7740' MD. The leak rate through the PC Leak is unknown due to leaks between the 9-5/8" casing and the 13-3/8" casing. Last operation on the well was to perform an OA down squeeze that was ruled a success. With the OA cemented the well still has multiple issues to be addressed and would not be economic to produce, as such, placed on the P&A list for 2019. Last Pressure Test: MIT -T to 2500 psi passed, CMIT-TxIA failed, 7/8/2011. Objective: Perform a full P&A on the well placing cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker plate. This P&A was designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviation captured in eMOC 10439. DPZ 1: From 1991' MD - 9623' MD DPZ 3: Top at 11435' MD - 12327' MD Procedural Steps: Note recording requirements in RP. Through Tubing Abandonments (section 5.9) that must be documented in A WGRS and the Wellfile. AOGCC Witness: All AOGCC witnessed operations require a minimum of 24 hour notice to AOGCC inspectors of the timing of the operation so they can be available. 11-25a P&A Sundry 1) Special Projects A. Injectivity test into control and balance lines. B. Cement control and balance lines with -2.1 gallons for Squeezecrete or Finecem. Reference small volume cement RP. If pump pressures allow (<5K psi), fill the entire control line with cement. Goal is to cement the lines to at least 1300 ft (-1.2 gallons each line). 2) DHD A. Wait on cement 3 days. B. Pressure test control and balance lines to 2500 psi as per Small Volume MIT Criteria in ✓ MIT RP. 3) Fullbore A. MIT -T to 2500 psi. Establish LLR if MIT does not pass. B. Based on MIT results, will look at options of completing P&A as follows or re -writing program for use of CT. 4) Slickline A. Drift and tag to the top of the IBP at 8938' MD. B. Bail till clean top of IBP, Pull IBP, attempt to fish any IBP rubber/ band elements left in hole. ➢ The well will likely go on a vac once IBP is released due to the PC leak above C. Drift and tag to as deep as possible inside 2-3/8" liner to confirm wellbore clean down to perforations. ➢ Based on if the IBP can be pulled, the amount of debris left from IBP and or the drift through the 2-3/8" could greatly change the plan forward for the P&A. 5) Fullbore A. Rig up fullbore to bullhead down the tubing with a ball launcher. Rig up to bleed off IA / OA pressures to a tank as necessary. B. Pump the following to confirm injectivity into wellbore. Pump down the tubing bullheading into the reservoir. • 30 bbls 60/40 • 225 bbls of 1 % KCL or SW. (75-100 deg F) • 38 bbls of freeze protect as required. • Max pressure while pumping 2500 psi. C. Bullhead down the tubing the following cement program to abandon the reservoir. • 5 bbls McOH (as required) • 10 bbls fresh water • 6 bbls Class G Cement as per design • 5 bbls fresh water • Foam Ball • 210 bbls of diesel • Max pressure while pumping 2500 psi. • Objective is to place a cement plug inside the 2-3/8" liner from 12220' MD to ✓ 11334' MD with -2.5 bbls squeezed behind pipe. • Estimated temperature @12220' MD = 197 deg F. Based on Static BHP data from July 2006, 3762 psi & 161 deg F at 7882' TVDss / 7940' TVD / 11 123'MD. The validity of this data is in question due to the PC leak above it. 11-25a P&A Sundry Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 20-100cc/30 min Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours 6) Fullbore A. MIT -T to 2500psi. - AOGCC Witnessed 7) Slick Line A. D&T top of cement inside the 2-3/8" liner. - AOGCC Witnessed B. Perforate the 2-3/8" tubing and 3-1/2" tubing -50 ft above top of cement tag (-11284' MD if cement tag is on depth). • Perforate - 10 ft of charges, 4-6 shots per foot, 60 -degree phasing, centralized. Perforations still need to be modeled so to not best punch through the 7" liner. • Top perforation -50 ft above TOC, use tubing tally to tie in as required. • Use S -Line or E -Line as required. 8) Fullbore A. Rig up to be able to pump down the tubing and take returns from the IA. No ball launcher required. B. Pump the following wellbore displacement with surfactant wash. • 5 bbls McOH • 75 bbls of hot fresh water (-160 deg F) + surfactant (2 gal/mgal F103 and 2 gal/mgal UO67) • 680 bbls of 9.8 ppg brine • Freeze protect wellbore as required with 50/50 or 60/40. • Max pressure while pumping 2500 psi. C. Pump the following cement plug to abandon the wellbore. • 5 bbls McOH (as required) • 10 bbls fresh water • 775 bbls Class G cement as per design (-100 bbls over calculated volume). ➢Uncertain how PC leak will behave, 100 bbls over is excessive but want to be sure to get cement to surface in the IA. • Max pressure while pumping 2500 psi. • Confirm cement at surface in IA. • Top of cement will be at surface in the tubing and IA. • Estimated temperature @ 11284' MD = 168 deg F. Based on Static BHP data from July 2006, 3762 psi & 161 deg F at 7882' TVDss / 7940' TVD / 11 123'MD. The validity of this data is in question due to the PC leak above it. 11-25a P&A Sundry Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 20-100cc/30 min Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 9 hours 9) DHD A. Assist Fullbore with cement job and pump N2 across the wellhead to remove excess cement from the valves. This will allow valves to be opened prior to the wellhead removal to check for pressure. B. Bleed all wellhead pressures to 0 psi. C. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. 10) Special Projects A. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the conductor x 13-3/8" annulus, all other annuli and tubing with cement as needed. Photo document cement in all tubing and all casing strings. B. AOGCC witness cement tops in all annuli and installation of marker cap on outhermost casing string. Provide 24 hour notice to AOGCC Inspector of the timing of the welding of the marker Dlate onto the casing string. Photo document welded marker plate. C. Bead weld marker cap on outermost casing string (Conductor Pipe) to read as follows BP Exploration Alaska, Inc. 11-25a PTD # 199-082 API # 50-029-20488-02 11-25a P&A Sundry Original Wellbore WELLHEAD- GPAy ACIUATGR• A)B.SON OKB. ELEV = 56 R3: E -SV= 56 BF. 8" - 29.24' KOP= t000 Max Arg1e - 62' Q 122M DaOanWO 12375' D1Wn TVD = 6600 SS (10(: A RTI, OA 00w %v(59/19)—SURFACE- r`3!-CSG. 121. r en. D - 1: WL Minimum ID = 1.92" @ 8994' 3-112" X 2-=" LNR XO ^7740' MD, hole in 9-5/8" Csg 10 SAFETYNOTES: •^ POSSIBLE sPDrs THdI 2LNR ILM1;(CNM THIS INTERVAL MILLEDOUTTOXYO=. I O PERFORATION SIMMRT REF LOG: SVS RST ON 092699 ANGREATTOPFES 60421X)94' Wle: Refer b Pradmboo OB tar 1 Iomal pert data SIZE SPF MB&AL OPNSA2 DATE 1-9116 612094 - 12120 O 1(913!00 1-9016' 2 12127 - 12132 S 0771500 1-91/6 2 12215-12220 S 02115100 1.9116, 4 12220 - 12240 O 03AHM 1-9116' 4 12240- 12250 O 0310191 Y9116 4 12252-12276 O 0310400 SAFETYNOTES: •^ POSSIBLE sPDrs THdI 2LNR ILM1;(CNM THIS INTERVAL MILLEDOUTTOXYO=. I O GAS LET MANDRELS ST BO TVD DEV TYPE VLV LATCH FORT DAT: 1 7627 3028 56 BMC OW R< 0 1V16/01 2 6515 4635 51 BMD OMI RK 0 02!2&87 3 7267 5113 50 MAG DMI R( 0 IIIIr01 4 8090 56M 50 BTC DMe R( 0 11716/01 5 8872 6140 50 BMC OBM R( 0 022&87 6 %W 6607 46 Wir-2 -OMY R( 0 022687 7 10302 7189 31 Wr-2 TTY R( 0 072&87 8 10700 7543 24 M-2 -OMY R( 0 072&87 9 11224 8039 13 W434 VM R( 0 OM87 NOTE • GLA1S N 6,7,88 9 ARE 89" 2.38' SUTR( LNR 9310' MD Hole in 3-1/2" Tbg (behind pipe) 11338' 7'X 3.12- SKR FBI Pot D=4.00• (BBON7 LNI 11/ NI. cc. D-2P12-IOBRDLNR r LNR B91OUT VW4M 11578' - 11590' (OFF CAR RAW 2-39' LW 4. ft. L-8()..0038 W. 0=1.885' — 12363' PRUDHOE my UNR WELL 11-25A PERNRNa: 192-0020 APIM'. 504y19-201804)2 OP E.,IaraeoP (AInb1 Ct 11-25a P&A Sundry 5 Proposed P&A Diagram TREE GPAY VVELUILAD= GRAY AGt3ATOR= AXELSON OLB. ELEV - 56 REFEUV LATC1f BF. B."= Cmt Plug Circ from 2921' 8 AOP= roar Surface to 11284' MD Lax Angie = 629Q 12109' in Tbg and IA. D9Wn AO= 12375' D91unTVD= sear SS roc6Noc GADO O>ISv191_ SURFACE 303/" 51 ua4r-csc,>v.rae.0-1z O+r '� 90]x• Minimum ID = 1.92"@ 8994' 3412" X 2-318" LNR XO -'7740' MD, hole in 9-5/8" Csg Do .. 14 FM NOTES. — POSSIBLE nCM SPOTS THW CMT 11-25A 2Mq,,LAL rLL1®O TO t� tp103(oltmTIQ. TNS 9-5WCSG,47F,SO0-95.0.6.661• 1 9310' MD Hole in 3-1/2" Tbg (behind Perforate 2-3/8" & 3-1/2" Tbg, 50' pipe) above TOC tag("11284'MD) 11334'r X 3.1(• SM P61 N0L K) -4,W JIJBBBNDLNFO Reservoir Cmt Plug (-11334'MD-12220MD) w/ 2.5 bbls sgz'd behind pipe. 11/09' if1Y XN M,MLL®Toz.e6 ev cTo P9EDRATUNSUWMRY GAS LIFT MAPL'483.S FU LOO SAS FIST ON OW26M ST M ND DEV TYPE VLV LATC1f PORT DATE 1 3627 3029 56 MOIG CTM 1M 0 1111601 2 6515 4635 51 M.G DAN RX 0 BMW 3 7267 5113 50 AMC OW 18( 0 1V1601 4 8090 5638 50 AMC CIW IB( 0 11/1601 5 8872 6140 50 AMG O89' W 0 02M87 6 9563 6607 46 WAG -2 MMY fM 0 078687 7 10302 7189 31 WAC -2 'CMY Po( 0 01(687 B 10700 7543 24 MMG2 'CMY fM 0 02(687 9 11224 9039 13 MdG2'MURL 13( 0 0212687 TOTE' G1M506.7.8 8 9 ARE IOM 2-316 SWW LNR 9-5WCSG,47F,SO0-95.0.6.661• 1 9310' MD Hole in 3-1/2" Tbg (behind Perforate 2-3/8" & 3-1/2" Tbg, 50' pipe) above TOC tag("11284'MD) 11334'r X 3.1(• SM P61 N0L K) -4,W JIJBBBNDLNFO Reservoir Cmt Plug (-11334'MD-12220MD) w/ 2.5 bbls sgz'd behind pipe. 11/09' if1Y XN M,MLL®Toz.e6 ev cTo 1 I r - Y M.D-2.007(OEHfOL O r L W WLOM VWD M 11578 - 11590' (OFE GMT MAP) 2-3t8' LNR 4.W. L-80..0039 W. 0. 1.995' — 12363' PRUONOE BAYUNR WELL: 11-2m PERMRNo: 1990920 APIW 50029-2046902 G u 11-25a P&A Sundry 6 P9EDRATUNSUWMRY FU LOO SAS FIST ON OW26M AWLEATTOPPBB': 60®12091' Ml: Mf9r to Pmdwhon 05 fn hwteaetl pelf dM" SIZE SPF DATE 1-9116' 6 12094-1210 0 161360 1-9116 2 132 S 0711500 1.9116 2 10 rM2760 S OVIS 0 1-9116 4 10 0 aMM 1-9116 4 150 0 010300 i-9116 4 176 O 010 1 I r - Y M.D-2.007(OEHfOL O r L W WLOM VWD M 11578 - 11590' (OFE GMT MAP) 2-3t8' LNR 4.W. L-80..0039 W. 0. 1.995' — 12363' PRUONOE BAYUNR WELL: 11-2m PERMRNo: 1990920 APIW 50029-2046902 G u 11-25a P&A Sundry 6 10,000,000 1,000,000 t Y C cO C a 100,000 LL V o Y wt Vu 10,000 O W O N d 1,000 V 3 V 4 r�o 100 3 O L F 10 BP Exploration (Alaska) Inc., PRUDHOE BAY UNIT 11-25A (199-082) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates Cum. Prod Oil (bbls): 283,241 Cum. Prod Water (bbls): 273,806 Cum. Prod Gas (mcf): 4,568,286 I I I I I IRI � I• I I I I I I I I I � � I I 1 1 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) . GOR Produced Water (BOPM) --e— Produced Oil (aOPM) 10,000,000 W m 1,000,000 O M O 100,000 VIDz 3 0 3 10,000 S O 1 d 1 1,000 O CM G d M A 100 a rD t 0 O 3 30 s 1 Jan -2020 SPREADSHEET 1990820 PBU 11-25A Prod Curves Well oil V120 20190718.xlsx - - - - - - - - - 7/18/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ' i i 9(110 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown f," ye'D Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Progr"Fe "❑ Plug for Reddil ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 199-082 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20488-02-00 7. Property Designation (Lease Number): ADL 028325 & 028326 8, Well Name and Number: PBU 11-25A 9. Logs (List logs and submit electronic and pointed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11, Present Well Condition Summary: Total Depth: measured 12401 feet Plugs measured 8938 feet true verlical 8870 feet Junk measured None feet Effective Depth: measured 8938 feet Packer measured 11334 feet true vertical 5182 feet Packer true vertical 8145 fret Casing: Length: Size: MD: TVD: Burst. Collapse: Structural Conductor 80 20" 31 - 111 31 - 111 1530 520 Surface 3005 13-3/8" 31 -3036 31-2674 5380 2670 Intermediate 9613 9-5/8" 29-9642 29-6661 6870 4760 Liner 2271 7" 9307-11578 6430-8384 8160 7020 Liner 3375 2-3/8" 8988-12363 6215-8845 11200 11780 Perforation Depth: Measured depth: 12084 - 12276 feet True vertical depth: 8709-8798 feet Tubing (size, grace, measured and true vedical depth) 5-1/2" 17# x 3-1/2" 9.2#, L-80 /N-80 27-11420 6405-8229 Packers and SSSV (type, measured and 3-1/2" Baker FBA Packer 11334 8145 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: SLB Bullheaded the following down OA taking retums to formation: 10 BBLS 60/40, 50 BBLS Surfactant w/4 2 GAL of each F103& U067 (2 GPT), 10 BBLS 13.5 PPG Mud Push spacer, 30 BBLS 15.8 PPG Class G CMT, 60 BBLS 15.8 PPG Class G CMT w/ 15 PPB Aggregate, 87 BBLS 15.8 PPG Class G CMT. Pumped 50 bbls of Contaminate Gel into the IA. Spotted it to cover the IAxOA leak at 1925'. Intervals treated (measured): TOC in OA at surface. BOC in OA at 3034' MD/ 2672' TVD Treatment descriptions including volumes used and final pressure: 30 BBLS 15.8 PPG Class G CMT, 60 BBLS 15.8 PPG Class G CMT w/ 15 PPB Aggregate, Final Pressures: OA = 106 psi, IA = 82 psi, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In 499 0 Subsequent to operation: Shut In 82 0 14. Attachments: (reyundper20MCz5.070.25.071,&25.253) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 16. Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-142 Authorized Name: Smith, Travis T Contact Name: Smith, Travis T Authorized Title: Engine Contact Email: travis.smithl0bp.com Authorized Signature: Date:Z9 Contact Phone: +1 907 564-5412 Forth 10.404 Revised 04/20 �� M(TP-MM RBDMS✓MAY 3 0 2019 Submit Original Only Daily Report of Well Operations PBU 11-25A ACTIVITYDATE RI IMMARY T/1/0=355/505/500 Temp=Sl (CEMENT SQUEEZE (OA/IA DWNSQZ) Pump 65 bbls of crude down OA for injectivity test. Pumped 65 bbls with injectivity of 5 BPM @ 625 psi . (Refer to log for details) 4/23/2019 ***WSR continued on 04-24-2019**' ***WSR Continued from 04-23-2019' Pressure tested OA flange to 2500 psi. DSO notified of well status upon departure. Valve Positions=SV,WV, SSV closed MV open CV's OTG 4/24/2019 FWHP=355/505/500 Hung AFE sign on MV **'FLUID PACKED WELL*** 5/5/2019 T/1/0=325/500/500 LTT Master Valve PASSED Intitial TWO = 678/494/449 (SLB Cementing - OA Downsqueeze) ***Refer to LRS AWGRS for LRS specific details*** SLB Bullheaded the following down OA taking returns to formation: 10 BBLS 60/40, 50 BBLS Surfactant w/ 4.2 GAL of each F103 & U067 (2 GPT), 10 BBLS 13.5 PPG Mud Push spacer, 30 BBLS 15.8 PPG Class G CMT, 60 BBLS 15.8 PPG Class G CMT w/ 15 PPB Aggregate, 87 BBLS 15.8 PPG Class G CMT. S/I OA CSG Valve. r in control of well upondeparture' FWHPS = 449A/ac/Vac TOC in OA at surface 5/9/2019 BOC in OA at 3034' MD/ 2672' TVD T/I/0= 260/500/480. LRS unit 72, Assist SLB with CEMENT SQUEEZE (OA/IA DWNSQZ). Heated UR tank with 230 bbls of KCI from 48* F to 100* F. Pumped 50 bbls of Contaminate Gel into the IA. Spotted it to cover the IAxOA leak at 1925' with 35 bbls of 100' F SW. Monitored WHP's while SLB pumped OA downsqueeze. Pumped 197 bbls 100* SW followed with 110 bbls diesel down IA, Tags hung on well, Valve position at departure- SV, SSV, WV= Closed MV= Open IA= OTG OA= S/I as 5/9/2019 per WSL FWHP= 1570/1144/S/I TREE= GRAY WELLHEAD= GRAY ACTUATOR= AXE -SON OKB. E -EV = 56' RE= E EV _ _. 58' BE rLEV = 29.24' KOP= 1000' Max Angie = 62' @ 12209' Datum MJ = 12375' Datum TVD= 8800'SS TOC & BOC OA DOVMISOZ (510/19) SURFACE - 13-3/8- CSG, 72#,. LAO, D =-1-2-3-47-] Minimum ID = 1.92" @ 8994' 3-1120'X 2-W LNR XO TOP OF 2-3/8" LNR (MEM GW CCL DATED 03/02/001 5-1/2" TBG,17#, L-80, .0232 bpf, D = 4.892" 1-1 9271' TOP OF 7" LNR - 9307' 9-5/8" CSG, 47#, SOO-95, D = 8.681" 3.12" TBG, 92#, N-80_0087 bpf, ID = 2.992- 1--1 11420' 17- LNR 29#, L-80..0371 bpf, D = 6.184" 1 SAFETY NOTES:'"" POSSIBLE TIGHT SPOTS TFRU 2-318" LNR M 11900'- 1230tr 1 1-2 5A INTERVAL MILLED OUT TO 1.85" (CMT ON 03101100. SHBkTH). THIS tY O 2251' 5-12"CAMCOBAL-OSSSVN,ID=4.562" GAS LRT MANDRELS ST PERFORATION SUAMMRY I TVD DLV I TYPE REF LOG: SWS RST ON 09126/99 I LATCH PORT ANGLE AT TOP PELF: 60 Q 12094' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 1-9/16' 6 12094- 12120 O 10/13/00 1-9116" 2 12127- 12132 S 02/15/00 1-9116- 2 12215 - 12220 S 02115/00 1-9116" 4 12220 - 12240 0 03/04100 1-9tl6" 4 12240-12250 0 ON03100 1-9/16' 4 12252 - 12276 O 03/04/00 17- LNR 29#, L-80..0371 bpf, D = 6.184" 1 SAFETY NOTES:'"" POSSIBLE TIGHT SPOTS TFRU 2-318" LNR M 11900'- 1230tr 1 1-2 5A INTERVAL MILLED OUT TO 1.85" (CMT ON 03101100. SHBkTH). THIS tY O 2251' 5-12"CAMCOBAL-OSSSVN,ID=4.562" GAS LRT MANDRELS ST MO I TVD DLV I TYPE VLV I LATCH PORT DATE 1 3627 3028 56 M4G DMP RK 0 11/16/01 2 6515 4635 51 AMIG DW RK 0 0228/87 3 7267 5113 50 MUG DAM RK 0 11/16/01 4 8090 5638 50 MVIG DAM RK 0 11/16/01 5 8872 6140 50 MrIG DAM RK 0 02128/87 6 9563 6607 46 AM G-2 '0MY RK 0 02/28187 7 10302 7189 31 M4MG-2 *MY RK 0 02/28/87 8 10700 7543 24 MUG -2 *MY RK 0 02128/87 9 1 11224 8039 13 MIAG-2 RK 1 0 0228/87 wnM-C-ucwe7000 Ax0v.0 ovo"crvtvi L. 7679' 7' TBG PATCH, D = 2.992" (0317 5/02) 8989' CtM 5-12" X 2-3/8- TMJ LT PKR ID = 2.25" (11-: 8968' '89W -1-13785- 4.365" SOOUP HEAD GUDE, D = 3.700" BKR DEPLOY SLV, D = 3.000- 2-3/8" 9272' j—j 5-12- X 3-12" XO, D = 2.992" 9310' 1-1 HOLE N 3-12" TBG 11334' 7"X 3-12" BKR FB -1 PKR ID = 4.00" (BEHIND LNR) 7" LNR MLLOUT WINDOW 1157V - 11590' (OFF CMT RAMS DATE REV BY COMMENTS DATE REV BY COMMENTS 03107197 JORIGINAL COMPLETION 05/15/19 JJUJMD OA DOWNSOUEEZE(05109119) 09M7109 CTO SIDETRACK 0320119 JNUJMD ADDED OKB, REF, & BF ELEV 0320/19 JNUJMD I CORRECTED 2-3/8" LNR VYEIGHT 0320/19 JNL/JMD I CORRECTED OLD GLM VALVE TYPES PER MH I PBTD I PRUDHOE BAY UNIT WELL: 11-25A PERMIT No: 199-0820 API No: 50-029-20488-02 L& 253' FEL, Sec. 28,1-11N, R BP Exolondion (Alaska) THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Travis T. Smith Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-25A Permit to Drill Number: 199-082 Sundry Number: 319-142 Dear Mr. Smith: AIaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o ogc c. o laska.g ov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner d DATED this Z day of April, 2019. RBDMS�W APR 0 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 RECEIVE® MAR 12 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Oper//rpp.t��tio((ppe4)�)�s�f(()uuf��fQQq�((�q,, Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change ordvPCPib�1M Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA Cement Squeeze 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0' 5. Permit to Drill Number 199-082 - 3. Address: P.O. Box 196812 Anchorage, AK ' 99519-6612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-20488-02-00 7. If perforating: e. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 11-25A ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028325 8 028326 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12401 8870 8938 6182 8938 None Casing Length Sin MD TVD Burst Collapse Structural Conductor 80 20" 31 - 111 31 - 111 1530 520 Surface 3005 13-3/8" 31 -3036 31 -2674 5380 2670 Intermediate 9613 9-5/8" 29-9642 29 -636814 6870 4760 Liner 2271 7" 9307-11578 6430 - 8384 8180 7020 Liner 3375 2-3/8" 8988-12363 6215-8846 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12094 - 12276 8709 - 8798 5-1 17# x 3-i/2" 9.2# L-80 / N-80 27-11420 Packers and SSSV Type: 3-112" Baker FB -1 Packer Packets and SSSV MD (ft) and TVD (ft): 11334/8145 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 10, 2019 15. Well Status after proposed work: Oil 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Smith, Travis T be deviated from without prior written approval. Contact Email: trams.smithlabp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564-5412 Authorized Title: En r Authorized Signature: ) Date: 5/Z z llf COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Jh Other Post Initial Injection MIT Req'd? Yes ❑ No ❑ U 2 2019 RgDMS.�"�APR Spacing Exception Required? Yes ❑ No E� Subsequent Form Required: �0 i /A t/ 7 APPROVED BYTHE i(' Approved by: COMMISSIONER COMMISSION Date. k ORIGINAL�� M(.,Qj79 Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 11-26A OA Cement Squeeze Revised/ O Well Interventions Engineer: Travis Smith (907) 564-5412 Pad Engineer: Travis Alatalo (907) 564-5351 History 11-25A was sidetracked to its current location in 1999 with a coil sidetrack from the original 1987 completion (11-25 itself was a re -named sidetrack of 11-14). At the time of the coil sidetrack completion, a hole in the 3-1/2" tubing at 9310' MD was covered with the 2-3/8" liner. In 2002, a tubing leak was found at 7679' MD and remediated with a tubing patch. Shortly thereafter the well was found to have a leak in the production casing and was shut-in. In 2011 the well was secured with an IBP below the tubing patch at 8938'. A temperature LDL run in March 2019 indicated the production casing leak is located at approximately 7740' MD. Additionally, this log indicated IAxOA communication at —1925' MD and an anomaly that may be a surface casing leak at —790' MD. 11-25A has been identified as having no future utility, therefore BP is evaluating the well's candidacy for P&A amongst other such wells. The OA cement squeeze proposed here will mitigate risks to surface prior to upcoming reservoir abandonment work. Current Status The well is currently classified as Not Operable by BP due the production casing leak. The tubing is secured downhole and has been shut-in since 2002. Objective In order to reduce possible risks associated with surface casing leaks, the OA will be cemented to surface with a downsqueeze cement job. Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel or crude down the OA and into formation. Perform a step -rate injection test and record pump pressure and rate at several different pump rates. Max OA pressure 2500 psi. a. Make certain to monitor the cellar and conductor for returns while pumping down the OA. b. Have a vac truck on location and be prepared to pump out of the cellar in case of returns to surface. Special Projects / Fullbore 2. RU to pump down the IA taking returns through the cretaceous leak to formation. Spot the following pill to contaminate cement that comes into the IA: 1. 50 bbls of contaminate gel 2. 35 bbis of brine displacement 3. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash-up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 2500 psi treating pressure. 1. 10 bbls of 60/40 or neat McOH I I -25A OA Down -Squeeze (Revised): 3/27/2019 TTS 2. 50 bbls hot surfactant wash (180°F freshwater + 2 gal/mgal F103 + 2 gal/mgal U067) 3. 10 bbls of 13.5 ppg MUDPUSH II Spacer 4. 30 bbls of neat 15.8 ppg Class G cement 5. 60 bbls of 15.8 ppg Class G with 15 -ppb aggregate 6. 87 bbls of neat 15.8 ppg Class G cement 4. Pump no displacement behind cement. Slow rate to approximately 1 bpm when cement reaches the target displacement (-167 bbls of cement away / 10 bbls cement remaining to pump). a. With 3-5 bbls of cement left to pump: Swap to take returns from upstream of the OA while still on cement (S/D pumping as needed). Be sure to swap away from the OA and direct returns to surface before the last of the cement is pumped downhole to ensure only cement goes down the OA. b. SI the OA and flush lines only to surface, without pumping down the OA. Note that the OA may be on a vacuum and may suck any wash water that is pumped across the OA down into the OA if allowed to do so. Note: Do not attempt to squeeze cement on this job. With multiple possible leaks, including into the IA, the intent of the job is to fill the OA to the level of the shoe (3034' MD), shut -down, close in on the OA, and allow cement to cure with minimal fall -out to the IA. 5. Pumping diesel with a triplex pump, pump —1-2 gallons through the OA gate valve to clear cement. Grease the valve as well to keep it functional. 6. Rig up to pump down the IA taking returns through the cretaceous leak to formation. Hold the OA and tubing shut in at surface. Pump the following flush: a. 190 bbls of brine b. 110 bbls of diesel freeze protect Cement Calculations — Fullbore OA Downsaueeze 13-3/8" x 9-5/8" volume from SC shoe at 3034' MD to surface Class G 15.8 ppg mixed on the fly Field blend to beequal to lab +/- 0.1 ppq Slurry Temperature 0.0581 b 177 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to beequal to lab +/- 0.1 ppq Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc/ 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fl Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Operations 7. Leave well shut-in. DHD 8. Monitor for fluid to surface 11-25A OA Down -Squeeze (Revised): 3/27/2019 TTS Proposed Schemotic: OA Downsqueeze TREE GMY VIELLIEAD= GRAY 11-2520 ACTIWTOR= AXE -SON KB. E3P/ = 58.0' a BF. flEV = FN KOP= 10SS blas Argo = 32 @ 12209' surface DelumkO= 12375' OeNxn ND= 8800'SS Minimum 10 — 1.92"@ 8994' 3.12" X 2318" LNR XO SAFETY NOTES:— POSSIBLE TIGNr SPOTS TN81 2-3i8' UP R83M 11900' -12300' (CMT SWATH). THIS INTEWAL MILL® Our TO 1.88' ON 031011M. 2 6515 F E FORATON SUNWRY 51 WAG Ria LOG: SNS FIST ON 0926M TM 0 ANGLE AT TOP PR6: 60®12094' NAe: Refer b Reduction DS for Nsloreal perf data SIZE SFF I NIHNAL OpNS9z DATE 1-9H6'6 MAG 12094-12120 O 1413100 1-9116'2 6140 12127-12132 S 02115100 1-9116' 2 12215-12220 5 01015100 1-9116' 4 12220-12240 O 03/04/00 1-9H6' 4 17140-12250 O 03103100 1-9/16' 4 12252-12276 O 0&09/00 SAFETY NOTES:— POSSIBLE TIGNr SPOTS TN81 2-3i8' UP R83M 11900' -12300' (CMT SWATH). THIS INTEWAL MILL® Our TO 1.88' ON 031011M. 2 6515 4635 51 WAG OV TM 0 3 7267 5113 50 MAG DOKE N( 16 4 8090 5638 50 MAG S0 R( 24 5 8872 6140 50 MMIG W RK 0 6 9563 6607 46 MM2 VV N( 0 7 10302 7189 31 Mr -2 'OV N( 0 8 10700 7543 24 MM3 -2 'OV RK 0 9 11224 6039 13 MMG2 'DV RK 0 FIR 1)= 7' LWMILLOUTVNlOOIN 11578'-115W (OFF CMT RAMP) ka_mH RL RAY LM VW.L 11-25A PEFUT No: 199-0820 AR No: 50-029-2048802 669'FSL&253'FEI- See. 28. T11 N RI 5E DOTE REV BY I COM.ENIS I nATE I REV BY I COM.ENIS I 03101187 JORIGINAL COMM -MON 09/17/07 OMRJC 2-318-LN2CONECION(07130/ 09177199 1CTOSIDErRAcK 11/15/10 OOBPJC PEW COFFIEcnoS 1722/01 CMP CORECIIOFS 0728111 1 SFC( RO SETIBP(07108111) Otro3102 JWKAK MV�HDLE NTTKi 03175102 CtYSNh SET TBG MTCH SP T3r9bration (Alnaka) 11-25A OA Cement Squeeze Well Interventions Engineer: Travis Smith (907) 564-5412 Pad Engineer: Travis Alatalo (907) 564-5351 History 11-25A was sidetracked to its current location in 1999 witl completion (11-25 itself was a re -named sidetrack of 11-1 completion, a hole in the 3-1/2" tubing at 9310' MD was tubing leak was found at 7679' MD and remediated wit a was found to have a leak in the production casing and a with an IBP below the tubing patch at 8938'. e IN coil stdetrack from the original 1987 At the time of the coil sidetrack vered with the 2-3/8" liner. In 2002, a tubing patch. Shortly thereafter the well o shut-in. In 2011 the well was secured A temperature LDL run in March 2019 indicated th production casing leak is located at approximately 7740' MD. Additionally, this log ind'cated IAxOA communication at —1925' MD and an anomaly that may be a surface casing leaY —790' MD. 11-25A has been identified as having no futulity, therefore BP is evaluating the well's candidacy for P&A amongst other such wellse OA cement squeeze proposed here will mitigate risks to surface prior to upcoming reservoir aonment work. Current Status The well is currently classified as Not is secured downhole and has been sl Objective In order to reduce possible risks asst surface with a downsqueeze cement Procedural steps able by BP due the production casing leak. The tubing since 2002. with surface casing leaks, the OA will be cemented to YJ Fullbore v 1. Establish injectivity rate and pressure with diesel or crude down the OA and into formation. Perform a step -rate injection test and record pump pressure and rate at several different pump rates. Max OA pressure 2500 psi. a. Make certain to monitor the cellar and conductor for returns while pumping down the OA. b. Have a vac truck on location and be prepared to pump out of the cellar in case of returns to surface. Special Projects / Fullbore 2. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash-up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 2500 psi treating pressure. 1. 10 bbls of 60/40 or neat McOH 2. 50 bbls hot surfactant wash (180°F freshwater + 2 gal/mgal F103 + 2 gal/mgal U067) 11-25A OA Down -Squeeze: 3/20/2019 TTS F6 3. 10 bbls of 13.5 ppg MUDPUSH II Spacer V I- �'' 4. 20 bbls of neat 15.8 ppg Class G cement e fC+ 5. 60 bbls of 15.8 ppg Class G with 15 -ppb aggregate a� 1 6. 32 bbls of neat 15.8 ppg Class G cement 3. Pump no displacement behind cement. Slow rate to approximately when cement reaches the target displacement (^102 bbls of cement away / 10 bbls cement r i ng to pump). a. With 3-5 bbls of cement left to pump: Swap to take returns om/upstream of the OA while still on cement (S/D pumping as needed). Be sure to swap a ay from the OA and direct returns to surface before the last of the cement is pumped downh a to ensure only cement goes down the OA. b. SI the OA and flush lines only to surface, without puyfiping down the OA. Note that the OA may be on a vacuum and may suck any wash water th4eis pumped across the OA down into the OA if allowed to do so. Note: Do not attempt to squeeze cement on this joV. With multiple possible leaks, including into the IA, the intent of the job is to fill the OA to the level of a lowest leak (-1925' MD), shut -down, close in on the OA, and allow cement to cure with minimal f -out to the IA. 4. Pumping diesel with a triplex pump, pump -1-2 Grease the valve as well to keep it functional. Cement Calculations - Fullbore OA through the OA gate valve to clear cement. 13-3/8" x 9-5/8" volume from leak at 1925'to surface (0.0581 M Time hours 1 b 112 bbls Cement Type / Weight ass G 15.8 ppg mixed on the fly field blend to be eaual to lab +/- 0.1 Doa 40-200cc (20-100 cc / 30 2000 Dsi in 48 hrs Cement thickening time: Mix on the Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Operations 5. Leave well shut-in. DHD 6 Monitor for fluid to surface 11-25A OA Down -Squeeze: 3/20/2019 TTS WELLHEAD= GRAY ACTUATOR= AXELSON OKB. ELLV = 56' REF ELEV = 58' BF. R-Bf = 29.24' KOP= 1000' Max Angle = 62' @ 12209' Dahan MD= 12375' DahNnTVD= 6600'5] Minimum ID = 1.92" @ 8994' 3-112" X 2318" LNR XO 12.5-BKR IBP (07/08/11) 1 11-25A 9 Wi 9ii D = 2.992" 11 11420' 1 12115' 1 SAFETY NOTES: — POSSIBLE TIGHT SPOTS THRU 2-318' LNR FROM 11900'- 12300' (CMT SHEATH). THIS INTERVAL MILLEDOUT TO 1.85" ON 03101100. 2251' 5-12' CAMCO BAL-O SSSVN, D = 4.562' GAS LFT MANDRELS ST MD PERFORATION SUMMARY DEVI TYPE REF LOG: SWS RST ON 0926/99 LATgi PORT ANGLEATTOPPERF: 60 (@112094' Pbta: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DOTE 1-9/16" 6 12094 - 12120 O 10/13/00 1-9/16" 2 12127- 12132 S 02/15/00 1-9116" 2 M15-12220 S 02/15/00 1-9/16" 4 12220 -12240 O 03/04/00 1-9/16" 4 12240-12250 O 03/03/00 1-9116" 4 12252-12276 O 03/04/00 1 12115' 1 SAFETY NOTES: — POSSIBLE TIGHT SPOTS THRU 2-318' LNR FROM 11900'- 12300' (CMT SHEATH). THIS INTERVAL MILLEDOUT TO 1.85" ON 03101100. 2251' 5-12' CAMCO BAL-O SSSVN, D = 4.562' GAS LFT MANDRELS ST MD I TVDj DEVI TYPE VLV LATgi PORT DATE 1 3627 3028 56 WAG DMY RK 0 11/16/01 2 6515 4635 51 WAG DMY RK 0 02/28/87 3 7267 5113 50 MIG DMY 1*( 0 11/16101 4 8090 5638 50 MMIG DW RK 0 11/16/01 5 8872 6140 50 Muff' 0MY RK 0 02/28187 6 9563 6507 46 MMG-2 *MY RK 0 02/28/87 7 10302 7189 31 M G-2 *MY RK 0 02126!87 8 10700 7543 24 WAG -2 'DNlY RK 0 02/28/87 9 11224 8039 13 M G-2 182MI RK 0 0228/87 NOTE • GLMS # 6,7,8 & 9 ARE BB*D 2.3/8' SDRFM LNR 69�-j4.3W- 5UUW HEAD GUDE, D = 3.70 8989' 3.785' BI(R DEPLOY SLV, D = 3.000' 09M7l99 3112' X 2-3/8" LNR XO, 0320!79 JN.JJMI) CHGD WELL SAG(FROM 11-14B TO 11-25A 08/17/07 DTRIPJC 2-3/8' LNROOFIRBMIOIN 9272' 572' x 312' XO, D = 2.992" 111/15/101 9307' —19-5/8' X 7' BKR HMC LNR HGP, D = 931W HOLE N 312' TBG X 312' BKR FB -1 PKR, D=4.00' 1 11409' 1 I 1142W I 7' LNR MLLOUT VITRO N 11578'-115W (OFF CMF RAMP) DATE 0=11871 I REV BY I COMMENTS JORIGINALcompt-Eno03H8/19 DATE I REV BY I COMMENTS MJJMD I CHGD WELL NAM= FROM 11-25A TO 11-14B 09M7l99 I CTD SIDETRACK 0320!79 JN.JJMI) CHGD WELL SAG(FROM 11-14B TO 11-25A 08/17/07 DTRIPJC 2-3/8' LNROOFIRBMIOIN 03120/19 JNJJM7 ADDED OKB, Fill, & BF BEV 111/15/101 OOBIPJC I PEW COFiRECTDNS 03/20/19 JNJJMD CORRECTED 2-318- LNR WEIGHT 07)28/11 SRD/ RIC SEr BP (07/08111) 03/20/19 JN JJM) COFZRECTED OLD GLM VALVE TYPES PER MU I FBTD I .0039 bnf. D = 1.995' PRUDHOE BAY UNIT WELL: 11-25A PERMIT No: 199-0620 AR No: 50.029-20488-02 569' FSL & 253' FB, Sec. 28, T11 N, R15E BP Exploration (Alaska) Proposed Schematic: OA Downsqueeze NFninum ID = 1.92" @ 8994' 3-112" X 2318" SNR XO �r 9pf, D 11-25A WERVAL M IL LED OUT TO 1,W ON 03/01100 2 6515 PERPOSATIONSU"RY 51 MAO RFF LOO: SM PST ON 09126'99 RK 0 ANGLE AT TOP {ES: 60 C 12(199' 5113 Nok: Rafer M Production OB for Worical Pert dale SVE SPF KnRVAL OPr0Sgz DATE 1-9116' 6 12094-12120 O 10113M 1-9/19" 2 12127-12132 S 02115/0 1-9116" 2 12216- 12220 s 02/15100 1-9116" 4 12220- 12240 O 03RKM 1-9116" 4 12240-12250 O 03103/0 1-9116' 4 12252- 12276 O OY04100 11-25A WERVAL M IL LED OUT TO 1,W ON 03/01100 2 6515 4635 51 MAO W RK 0 3 7257 5113 50 MM DOLE RK 16 4 8090 5639 50 MAC S/O RK 24 5 8872 6140 50 k98C OV RK 0 6 9563 6607 46 MACs2 'DJ PK 0 7 10302 7189 31 WA4,2 'IN R( 0 8 10700 7543 24 IHACs2 'M 1K 0 9 11224 9039 13 Mrl2 'OV W 0 D= BOSS' --13 765' BKR DE�oY SLV, ID X 3-12' XO, D= 2.992' r LM M-LOurWTDON 11578-11590' (CFFCHATRAWb 3UNerY PREHOE BAY UHT WEAL 11-25A PHAR No 199-0820 AR Pb: 50-02320488-02 569' FSL r 253' FH, Sec. 28, Tl IR R15E DATE REV BY 1 COk0434fS DATE I REV BY COM NTS 0810127 ONf#iNI COYPLEf10N 08117/7 DRYPJC 2-38' LM CORREMM(07 M77A9 0CTDSIOETRACK 11115/1Q OOBiPJC PE>F C0RRE:IAP6 1122/01 a-VTp IDPS 0728111 SRD PJCSEr 13P(07818/11) 01A M AA/KAK IMN R HOLE W TBG 03/15M CN9T ISEFTBG PATCH 8P BtPlurAlon (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 < Anchorage, Alaska 99519 -6612 December 21, 2010 JAN -� ,gip. 7`i Mr. Tom Maunder i ii: Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ^x Anchorage, Alaska 99501 r Cons .e, 'ssIQn Incngragia Subject: Corrosion Inhibitor Treatments of GPB DS 11 199 _ ("Sa Dear Mr. Maunder, i 1� Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off 1 Report of Sundry Operations (10 -404) DS-11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA _ NA 6/25/2010 11-02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11-03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11-04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 _ NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 _ NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 1-25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 • 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 4 Permit to Drill No. 1990820 MD 12401 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT 11-25A Operator BP EXPLORATION (ALASKA) INC . 8877 Completion Date 3/4/2000 J Completion Status 1-OIL Current Status AP1 No. 1-OIL 50-029-20488-02-00 UIC N REQUIRED INFORMATION Mud Log No Samples No -- Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Log Log Run Interval OH / Scale Media No Start Stop CH cJ~GR-TVD ~//RST ~"~SRVY LSTNG 25 FINAL 8332 8802 1 11290 12399 5 FINAL 11690 12275 (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments O 9/21/1999 09331'-/' 11290-12399 OH 9/19/2000 9/9/00 THRU O 9/19/2000 09810 .'-'"'~11555-12399 OH 9/21/1999 C 11/30/1999 09377~,,'~"'11666-12255 CH 11/30/1999 9/26/99 OH 10/8/1999 BHI 11500.-12401. Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Interval Start Stop Sent Received Dataset Number Comments Daily History Received? ~/N Formation Tops Receuived? (~/N Comments: Compliance Reviewed By: Date: _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 58 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4708' FNL, 250' FEL, Sec. 28, T11N, R15E, UM (asp's 707283, 5952287) 11-25A At top of productive interval 9. Permit number / approval number 908' FNL, 1202' FEL, Sec. 29, T11 N, R15E, UM (asp's 700941, 5955918) 199-082 At effective depth 10. APl number 50-029-20488-02 At total depth 11. Field / Pool 631' FNL, 1085' FEL, Sec. 29, T11 N, R15E, UM (asp's 701052, 5956198) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12401 feet Plugs (measured) Tagged PBTD (10/25/2000) @ 12268' MD. true vertical 8869 feet Effective depth: measured 12268 feet Junk (measured) true vertical 8792 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 12' 20" 300 Sx PF 1 12' 1 12' Surface 2976' 13-3/8" 22oo sx Fondu & 400 Sx PF II 3034' 2673' Production 9584' 9-5/8" 5oo Sx C~ass G 9642' 6662' Liner 2275' 7" 55o Sx C~ass G 1 1582' 8389' Liner 3375' 2-9/8" 15.5 bbls 15.8 ppg LARC & 12 12363' 8844' bb115.6 ppg Class G Perforation depth: measured 12100'-12120'; 12220'-12250'; 12252'- 12276'. ~CEIVED Nov 0 9 true vertical 8709' - 8719'; 8768' - 8782'; 8783' - 8796'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 Tbg @ 9272' MD; 3-1/2", 12.6#, N-80 Tbg @ 11420' MD. ~,~c~ocal~e Packers & SSSV (type & measured depth) 7' X 3-1/2" BAKER FB-1 EL PERNAMENT PACKER (BEHIND LINER) @ 11334' MD. 5-1/2" CAMCO BALO SSSV @ 2251' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Da y Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 369 47 435 215 Subsequent to operation 625 8419 1848 - 264 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: DS11 Surveillance Engineer Date /I- ~"' 0 ~ Dan Babcock Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 11-25A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date 10/09/2000: 10/13/2000: 10/14/2000: 10/15/2000: 10/16/2000 - 10/19/2000: 10/23/2000: 10/24/2000: 10/25/2000: Event Summary RIH &tagged PBTD @ 12260' MD. MIRU ELU. PT'd equip to 3000 psi. RIH w/perforating guns & shot 20' of add perforations located @' 12100' - 12120' MD (Zone 2Al Used 1-9/16" carriers & all shots @ 6 SPF. Attempted to POOH w/guns but stuck. Used Kinley Cutter to cut cable. Perf guns & cutter left in hole as fish. Fished cutter f/wellbore. Numerous attempts to fish guns f/wellbore - no recovery. Recovered 27' of E-line f/wellbore. RIH & recovered E-line tool string & perf guns. ASF. RIH &tagged PBTD @ 12268'. Placed well BOL & obtained production data. RECEIVED 0 9 000 Alasta Oil & Gas Cons. Commission Page I AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99510 Well Reference Data: I~'c~~' O~ ~ Well No: 11-25A ~ q~ I~ate: 09/15/00 Field: Prudhoe Bay Unit API No: 500292048802 County: North Slope BHI Job#: 107730 State: Alaska Enclosed is the following data as listed below: 2" + 5" Measured Depth Logs Log Type Bluelines Folded Sepias Rolled Sepias Mylar Film 1 Navigamma USMPR MDL/MNP TOTALS: 2" + 5" True Vertical Depth Logs Log Type Bluelines Folded Sepias Rolled Sepias Mylar Film 1 Navigamma USMPR ~D,./~P DPR/~D,./~DP LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks :1 LIS Verification Report & Listings :1 Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Fax#: (907) 267-6621 O,,te: SEP 19 2000 Alaska Oil & Gas Cons. Commission Anchoraoe ,"-"' STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMM~ iON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well 2. Name of Operator ~~ r~ 7. Permit Number ARCO Alaska, Inc. ~ ~ ~ ! 99-82 3. Address .~.~:.~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360! 50-029-20488-02 4. Location of well at surface ~ 9. Unit or Lease Name 4708' FNL, 250' FEL, Sec. 28, T11 N, R15E, UM (asp's 707287, 5952288) ~ Prudhoe Bay Unit AtTop Producing Interval ~i' .~.~~''~ 10. Well Number 908' FNL, 1202' FEL, SEC 29, T11 N, R15E, UM (asp's 700941, 5955918) ......... 11-25A 632' FNL, 1083' FEL, SEC 29, T11 N, R15E, UM (asp's 701051, 5956199) ~ ~ ~ ! Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 58 feetI ADL 28326 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 6, 1999 September 13, 1999 March 4, 2000 I N/A feet USE 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness o! Permafrost 12401' MD/8877' TVD 12300' MD / 8808' TVD YES ~1 No [--1I 2252' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & CCL/GR, Mere Induction/GR/RST, Mere GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 112' 32" 260 Sx PF 13-3/8" 72# L-80 Surface 3034' 17-1/2" 2200 Sx Fondu & 400 Sx PF II 9-5/8" 47# Soo-95 Surface 9642' 12-1/4" 500 Sx Class G 7" 29# L-80 9307' 11582' 8-1/2" 550 Sx Class G 2-3/8" 4.6# L-80 8988' 12363' 3" 15.5 bbls 15.8 ppg LARC & 12 bbls 15.6 ppg Class G 24. Per/orations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 9272' 11335' 3-1/2" 11420' 12220' - 12250' MD; 8768' - 8782' TVD; @ 4 SPF 12252' - 12276' MD; 8783' - 8796' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production !Method of Operation (Flowing, gas lift, etc.) 10/19/1999 (flow test) Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/12/2000 3.2 Test Period >I 475 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -218 psi 24-Hour Rate > 1329 632 170 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. *This 10-407 is submitted as directed per the 10-401 form approved September 02, 1999 (Permit ~99-82) mit'lb ~mp,ca[e Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 2A Top of Zone 1 B Base of Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 11442' 11481' 11539' 12035' 12178' 12279' TRUE VERT. DEPTH 8252' 8290' 8347' 8687' 8757' 8806' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 11-25A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed Title AAI Coil Tubin,q Drillin,q Supervisor Bruce E. Smith, P.E. Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEtVED Item 28; If no cores taken, indicate "none". Form 10-407 MAR 15 2000 Alaska 0il & G~.s Cons. 00mmissi0n Anchorage 11-25A uESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 9/06/1999: 9/07/1999: 9/08/1999: 9/09/1999: 9/10/1999: 9/11/1999: 9/12/1999: 9/13/1999: 9/14/1999: 9/16/1999: ~1W1999: 9/26/1999: 11/16/1999: RIH & drilled pilot hole f/11437' - 11551' MD. POOH. RIH & began time milling @ 11543' MD. Drilled to 11546'. Logged tie-in. TOW=Il550.5'. Drilled window to 11558' MD & POOH. RIH & UR'd Cement to 11521 '. UR'd to 11559' & POOH w/UR. RIH & milled pilot hole f/11561' - 11577.5' MD. POOH. RIH & commenced window milling sequence. Time milled window f/11580' - 11590'. Through 7" casing. POOH. RIH w/window dressing mill & dressed f/11573' - 11590'. Drilled OH to 11595'. Backreamed. POOH. RIH w/bi-centered bit & displaced well to FIo Pro. Drilled to 11610'. Performed LOT to EMW of 9.19 ppg. Drilled to 11640' & POOH. RIH & drilled to 11689'. POOH. PT'd BOPE. RIH & drilled ahead to 11695' MD. Drilled to 11829' & POOH. RIH & drilled to 12100'. Drilled to TD @ 12401' MD. POOH. RIH w/PDS induction/GR memory logging tools & logged OH. POOH. RIH w/2-3/8" FL4S liner & landed it @ 12363'. Hole smooth to 12300'. Liner stuck. Displaced hole to 2% KCI Water. Established ability to reverse circulate. Unstung f/liner & POOH. CS Hydril connection washed out, leaving fish in hole. RIH & latched onto fish. POOH w/fish (CSH Inner String). RIH & attempted to fish 2-3/8" liner - unsuccessful. POOH. RU ELU. RIH w/perf guns & punched holes in the liner for circulation f/12260' - 12280'. Used 1-11/16" carriers & all shots @ 4 SPF & 0° phasing. Tagged PBTD @ 12329'. POOH w/guns. RD ELU. ASF. RIH w/liner seal assembly but unable to circulate. POOH w/CT. RU ELU. RIH w/CCL/GR tool & 1-1/11" perf guns. Perforated for circulation f/12080' - 12090' @ 4 SPF & 0° phasing. POOH w/guns. ASF. RD ELU. RIH w/liner seal assembly but unable to circulate. POOH w/CT. FP'd well. RDMOL. Nabors 3S Rig released @ 0600 hrs. RIH w/CCL/GR/RST logging tools & logged f/12288' - 11690' in 3 passes. Produced well for 10 hrs to remove mud f/liner lap. MIRU CTU. Killed well. Liquid packed tbg & IA. Established injectivity of 2.5 bpm @ 2000 psi. Confirmed injectivity down liner. Operations shut down due to high winds. Sidetrack Summary Page I 11-25A ~ESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/18/1999: 11/19/1999: 11/20/1999: 11/21/1999: 11/23/1999: 11/24/1999: 11/27/1999: 12/08/1999 - 12/09/1999: 12/22/1999: 12/23/1999: 12/25/1999: 1/10/2000: 1/16/2000: 1/19/2000: Circulated all gas f/tbg & IA. Injection rate down liner 0.8 bpm @ 1500 psi. Could not establish circulation up f/behind liner. Injection d/liner backside established 1 bpm @ 2000 psi. FP'd tbg w/Crude. Standback for night. A Multi-step Liner Top Lap Cement Squeeze was performed as follows: PT'd equip to 4000 psi. RIH w/liner top cementing tool (LTCT) & stung into 2-3/8" liner. Pumped 17.5 bbls of 15.8 ppg LARC down the backside of the liner to the Tango shale interval. Contaminated Cement w/Biozan & POOH. RIH w/CT & cleaned out liner to 12327' CTM. POOH. FP'd TBG f/3000' w/Crude. WOC 18-24 Hrs. RIH w/LTCT & stung into liner top. PT'd liner lap cement to 3000 psi WHP - lost 70 psi in 1 hr. IA tracked WHP. Could not unsting f/liner top. Disconnected LTCT w/seal assembly & POOH w/CT. Left LTCT in well as fish. RD. RIH & retrieved fish f/8983' SLM. RIH & set Retrievable TIW Liner Top Packer @ 8989' CTM. PT'd IA to 2950 psi - lost 50 psi in 30 min. Running tool did not release f/packer. Disconnected f/running tool & POOH w/ CT, leaving fish in hole. Well loaded w/Crude to BTM. RIH & attempted to extract fish in hole. Good jar action but unsuccessful. MITIA to 3000 psi - passed. Attempted to retrieve fish - unsuccessful. Tagged Fish @ 8970'. RIH & tagged TIW running tool fish @ 8997', Appeared to have backed fish out of liner top packer. RIH & latched TIW Fish. POOH w/fish. RIH & drifted to 12336' SLM w/1.75 sample bailer. Drifted to 11980' w/10' 1.75 dummy gun. Drifted to 12336' SLM w/5' 1.75 dummy gun. MIRU ELU. PT'd equip. RIH w/perf guns & shot 10' of Add Perfs in the 2-3/8" liner @: 12127' - 12132' MD Reference Log: RST on 9/26/1999. 12215' - 12220' MD All shots @ 2 SPF, random orientation, balanced press & 0° phasing. POOH w/guns. ASF. RD. Opened choke & flowed well. Performed well test. Test time = 2.2 hrs, oil = 362 STBD, water = 1246 BPD, gas = 8469 MSCFD, formation GOR = 23395, & FTP = 853 psi. Sidetrack Summary Page 2 11-25A UESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/12/2000: 2/15/2000: Injectivity test: 2.7 bpm @ 2850 psi. MITIA to 2950 psi - passed. A Cement Channel Squeeze was performed as follows: MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & fluid packed well w/1% KCL Water & Crude. Tagged PBTD @ 12327' MD. Pumped 12 bbls of 15.6 ppg Class G Cement through the following perfs to cement the lower 2-3/8" liner. 12080'-12090' MD 12127'-12132' MD 12215'-12220' MD 12260'-12280' MD 2/17/2000: 2/18/2000: Placed 3 bbls of Cement behind pipe @ a max sqz press of 600 psi. Contaminated Cement w/Biozan & jetted contaminated Cement to 11900'. POOH. FP'd well w/Crude. Left 500 psi on wellhead. WOC. RIH & tagged TOC @ 10898' MD. Milled Cement to 12015'. Milled Cement to 12048'. 2/22/2000: Milled Cement to 12180'. 2/23/2000: Milled Cement to 12315'. CT stuck - disconnected & POOH. Left BHA & motor as fish. 2/24/2000: 2/27/2000: Attempted to fish motor/BHA f/liner. Drifted to 11707 SLM. FCO'd to 12310' CTM. Drifted to 12071' SLM w/LIB. Fines still in liner. 2/28/2000: Reversed out (FCO) w/SLK Water down to12,181'. Jet in FIo Pro into 5-1/2" tbg & reversed out. 2/29/2000: 3/01/2000: 3/02/2000: 3/03/2000 - 3/04/2000: Jetted in FIo-Pro above TOL & Reversed out same. Attempted to penetrate liner but unable. POOH. RIH w/nozzle & reversed FCO to 12,197'. POOH. Milled tight spots in 2 3/8" liner to 12,300' MD. Drifted through section f/11,900' - 12,300' twice without problems. Jetted rtns w/Biozan while POOH. Ran Memory GR/CCL logs. PT'd equip. RIH w/1-9/16" HSD perf guns & shot 54' of initial perforations located @: 12220' - 12250' MD 12252' - 12276' MD All shots @ 4SPF & underbalanced press. POOH. 4 shots on upper section did not fire. On lower section, ASF. RD. Placed well 11-25A on production & obtained a valid well test. Sidetrack Summary Page 3 7900 8000 8100 --~ 8200 8300 n 8400 8500 8600 8700 8800 8900 9000 ARCO Alaska, Inc. Structure : D.S. 11 Field : Prudhoe Bay Well : 11-25A, 50-029-20488-01 Location : North Slope, Alaska <- West (feet) Brlj Potnis Ootc plotted: B-Oct-1999 Plot Reference ie Coordlnatee ere in feet reference 11-25. True VerUcol Depthe are reference RKB - MSL = 49.77 ft. ---- Baker Hughes tNT[O --- 6800 6700 6600 6500 6400 6300 6200 6100 6000 5900 5800 5700 5600 5500 5400 I t I I I I I I I I I I I I I I I I I I I I I I I I I I 4400 Tie-in Point Top Zone 3 Bottom Zone 3 1-25 Fault Top 1-25 Fault Bottom 1-25 Top of Target 11-25 Bose of Target * Projected to TD 11-25 Top of I I I i I I I I i i I i i i Ii i ii i I i i i I I i I i 3500 3600 3700 3800 5900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 Vertical Sect[on (feet) -> Azimuth 559.00 with reference 0.00 S, 0.00 W from 11-25 Projected to TD 11-25 Bose of Target ORIGINAL 1-25 Fault Top 1-25 Fault Bottom Bottom Zone 3 Top Zone 3 Tie-in Point RECEIVED OCT 0 8 1999 4300 4200 4100 4ooo A I z 3900 0 3800 · ~ --i- 3700 -../ · 3600 ~ 3500 3400 3300 ARCO Alaska, Inc. D.S. 11 11-25A 11-25 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 11-25A Our ref : svy229 License : 50-029-20488-01 Date printed : 6-Oct-1999 Date created : 6-Oct-1999 Last revised : 6-Oct-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 707552.621,5951724.740,999.00000,N Slot location is n70 16 23.056,w148 19 23.737 Slot Grid coordinates are N 5952286.600, E 707282.700 Slot local coordinates are 569.12 N 254.34 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 11,11-25A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 11-25A Last revised : 6-0ct-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing. 11500.00 11.70 327.53 8258.80 3510.20N 6066.13W 0.25 3615.54 701122.39 5955628.00 11550.00 11.71 326.95 8307.76 3518.73N 6071.62W 0.24 3624.16 701116.67 5955636.38 11575.00 11.72 326.93 8332.23 3522.99N 6074.38W 0.04 3628.46 701113.78 5955640.56 11617.00 29.00 312.00 8371.48 3533.46N 6084.36W 42.64 3639.11 701103.52 5955650.75 11649.00 35.20 305.10 8398.59 3543.97N 6097.69W 22.48 3649.85 701089.91 5955660.88 11680.00 37.70 310.40 8423.53 3555.25N 6112.22W 12.96 3661.38 701075.07 5955671.76 11715.00 42.50 311.40 8450.29 3570.02N 6129.25W 13.84 3676.44 701057.65 5955686.05 11742.00 48.10 313.50 8469.28 3582.97N 6143.39W 21.46 3689.65 701043.15 5955698.61 11775.00 54.20 317.00 8489.97 3601.24N 6161.45W 20.24 3708.22 701024.60 5955716.37 11804.00 58.20 322.00 8506.11 3619.56N 6177.07W 19.88 3726.82 701008.48 5955734.26 11830.00 60.90 327.80 8519.29 3637.90N 6189.93W 21.85 3745.37 700995.12 5955752.23 11860.00 59.20 330.80 8534.27 3660.24N 6203.21W 10.35 3767.94 700981.23 5955774.20 11891.00 56.00 337.60 8550.89 3683.77N 6214.61W 21.20 3791.67 700969.18 5955797.40 11924.00 54.90 344.80 8569.63 3709.47N 6223.37W 18.27 3817.51 700959.72 5955822.85 11958.00 57.40 348.30 8588.57 3736.92N 6229.93W 11.27 3845.08 700952.41 5955850.11 11988.00 59.70 351.20 8604.22 3762.10N 6234.47W 11.26 3870.34 700947.17 5955875.15 12023.00 61.60 356.60 8621.38 3792.42N 6237.70W 14.50 3900.71 700943.11 5955905.37 12053.00 60.80 0.60 8635.84 3818.69N 6238.34W 11.98 3926.99 700941.74 5955931.61 12088.00 59.70 7.10 8653.22 3848.99N 6236.31W 16.42 3957.24 700942.93 5955961.95 12124.00 57.90 10.70 8671.88 3879.40N 6231.56W 9.91 3987.57 700946.85 5955992.48 12153.00 60.50 15.20 8686.73 3903.67N 6225.97W 16.06 4011.73 700951.77 5956016.89 12181.00 61.60 17.90 8700.28 3927.15N 6218.99W 9.31 4035.09 700958.10 5956040.55 12209.00 62.30 21.90 8713.45 3950.37N 6210.58W 12.85 4058.16 700965.87 5956064.00 12241.00 61.30 27.80 8728.59 3975.95N 6198.74W 16.54 4083.53 700976.99 5956089.90 12273.00 59.10 32.20 8744.49 4000.00N 6184.87W 13.77 4107.33 700990.19 5956114.31 12304.00 57.10 34.30 8760.88 4022.00N 6170.45W 8.64 4129.08 701004.00 5956136.71 12339.00 55.80 38.40 8780.23 4045.49N 6153.17W 10.44 4152.27 701020.62 5956160.66 12375.00 49.70 44.30 8802.02 4067.02N 6134.31W 21.37 4173.46 701038.89 5956182.70 12401.00 49.70 44.30 8818.83 4081.21N 6120.46W 0.00 4187.41 701052.34 5956197.27 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 11-25 and SSTVD from RKB - MSL = 49.77 ft. Bottom hole distance is 7356.38 on azimuth 303.70 degrees from wellhead. Vertical section is from wellhead on azimuth 359.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 11, 11-25A Prudhoe Bay,North Slope, AlaSka SURVEY LISTING Page 2 Your ref : 11-25A Last revised : 6-0ct-1999 Comments in wellpath MD SSTVD Rectangular Coords. Comment ........................................................................................................... 11500.00 8258.80 3510.20N 6066.13W Tie-in Point 12401.00 8818.83 4081.21N 6120.46W Projected to TD Targets associated with this wellpath ===================================== Target name Geographic Location SSTVD Rectangular Coordinates Revised ........................................................................................................... 11-25 Fault Bottom 700992.000,5955848.000,999.00 8625.00 3733.72N 6190.41W 8-Ju1-1999 11-25 Top of Target 700988.000,5956040.000,999.00 8650.00 3925.77N 6189.11W 8-Ju1-1999 11-25 Fault Top 700992.000,5955848.000,999.00 8575.00 3733.72N 6190.41W 24-Jun-1999 11-25 Base of Target 700998.000,5956044.000,999.00 8780.00 3929.49N 6179.00W Il-Aug-1999 WbLL LOG ProActive Diagnostic Services, Inc. T0~ ARCO Alaska, Inc. AOGCC Lori Taylor RE · Correction - Final Print(s) The following Open Hole Induction Log reported an incorrect APl Number in the header page. The correct APl # is 50- 029-20488-02. Please change any final copies to reflect this correction. Only the last two digits need to be corrected. Well Number: 11-25a Date: 9-13-99 Log Type: Open Hole Induction Log Incorrect APl#: 50-029-20488-01 Correct APl #: 50-029-20488-02 If you are unable to make the changes' ancl would like a corrected copy(s) sent, please mail or fax a copy of this letter to~ Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 Fax # (907) 659-2314 Your reference number: 99.082 #9331 We apologize for any inconvenience this error has caused. Signed · Print Name: RECEIVED ProActive Diagnostic Services, Inc., Pouch 340112, Pruclhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-maih pdsprudhoe~NAS00.net Website: www.memorylog.com C:~vly Documents\Excel_Word_Documents\Distribution_Forms\Log_Data_Correction_Form.doc Scbh berger NO. 12959 11/23/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 11-25A 99380 RST ~ c;.~ g.~r",jr"-j 990926 I 1 1 D.S. 14-07 99363 RST ~ ~ ~ r-j A 990922 1 1 1 I "~'/ ~. 0 ~999 $1~N£ DATE: ~ ' ' .AJ~I~ Oil & Gas Cons. L;o.lmissioii Please ~ign and ~eIu~n one cop~ of Ibis I~ansmiIIal Io She~ie al Ihe above address o~ ~ax Io {907) 561-831~. Than~ ~u. ~oActive Diagnostic Services, Inc. TRA ITTAL To~ ARCO Alaska, Inc. AOGCC Lori Taylor RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG CD-ROM ! MYLAR / BLUE LINE DIGITAL WELL DATE TYPE OR SEPIA PRINT(S ) REPORT FLOPPY F~LM i 9/13/99 Open Hole I I 1 11-25a t Res. Eval. CH 1 ~ I Mech. CH 1 , I I Caliper Survey Signed · Print Name: -- "1 1999 Date · ~ ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdspmdhoe@NA800.net Website: www.lnemo~?'log.c9,m C :X&ly Documents\Exgel_Word_Documents\Distribution_FormsXArco_pb_form.do, Pos~ Office ~. ,~6105 Anchorage, Ala~a 99519-6105 Dui Z I~ 1':3ct,d , ~I- J./ .1. August 31, 1999 Mr. Robert N..Christenson, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. Christenson: ARCO Alaska, Inc. requests a short turnaround approval of the attached Permit to Drill for the Drill Site 11-25A Sidetrack wellbore. The original spud date was expected to be mid September 1999 but an immediate schedule revision is now required. Operations on our current wellbore 18-22A have run into unexpected problems and we may require a rig move as early as tomorrow. Your immediate attention would be greatly appreciated. If you have any questions, please contact Bruce Smith at 263-4572, Sincerely. ~.....~.._.~.~----~-.~ ('"" Coiled Tubing Drilling Supervisor ARCO Wells Group cc: Paul Rauf ATO-1509 ?, FCE VED AUG 3 1 !999 ()ii & ~S L;Uli3. UOfi'hqlJSSiO[l Anchorage .Re': 11~)5 Flow Request Subject: Re: 11-25 Flow Request Date: Mon, 04 Oct 1999 11:36:06 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 ~mail.aai.arco.com> CC: john_spaulding~admin.state.ak.us 11 -- Joe, We agree there are not many options and this may work. Good Luck, Blair Wondzell PRB Problem Wells wrote: Dear Mr. Wondzell : We would like to do a short term flow test on well 11-25 to remove mud from the well in preparation of remedial cement squeeze operations. The well was recently sidetracked using coiled tubing and the liner stuck above TD. Attempts to circulate cement behind the liner were unsuccessful. Our plan is to flow out as much of the mud located between the liner and open hole out of the well as possible, then squeeze cement either through existing holes in the liner or down the tubing/liner annulus. There is Tubing x 9-5/8" communication and we expect to see pressures up to 2600 psi on the 9-5/8" while flowing the well. A MIT to 3000 psi was successfully conducted on 8/24/99 and we will closely monitor well pressures during the flow period. We don't anticipate needing to flow the well longer than 7 days to remove the mud. I faxed copies of the current wellbore configuration and the 8/24/99 MIT report to your fax number. Please call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 659-5102 1 of 1 10/4/99 12:52 PM 10-01-99 14:48 F rom-EOC gO?'$sgsgl? T-g60 P.O1/Ol F-83g ARO0 ~ f~- ' C.Ioulations Chin 10-04-99 09:29 From-EOC MECHANICAL INTEGRITY TE-~ IMm FORM NO... t-- a^'rE;__ WEI-I.~'I~PE (¢lrcl. ona): Pr~du=er Inlector Disposal ~ , MIT Tt~T "i'YPE.. ~a'm.~_ (i.e., ~^ is a/a'l, o^ {~, ~/e'],(~. x_!^ com~ REQUIRED TEST PR1E~SUREI ,.~AO_. C:~ ._PSI (ir, er Ann camm or injection Wall weW, pleue cgnaUj~ ttte ACE i! there's any qug.li~n: xB102 / ~§r 1-1 FLUID TYPE(S) USED 1'O PRF.~SURE TEST: 5a~//~-o ~?_o I __ II .............. J_ ............... -- i I, Itl..Il ........... III .......... i _ IIII . . -- .......... ............ I I Ill ............. Il illll ii ._ L .......... Ill ....... II .............. · Start the MIT 0verif'praS" lea.m ~ Sc,/. ~ 15 iiiinUteg, '*Repeat tho MIT If prom. Io~ Is ~. 10% O ~tO minutes. MUST lie C~O~ AND UHE©KED OFFII] THE GA,~lllla YAI.V~ wm, l I.~MI) AND TEiiT INPgFIMATION 11'1E WING VALVE IF Si AT TIME OF I. OAI!NNG &ND TEb'I1N~, r--]~. NO?lily IX:lllJ. ~ OlI;;J~T~R OF ~ RESULT~ VOLUMES PUMPED AND STATUS OF Y/ELL. Witness: Post-It'" brand fax transmittal memo 7671 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 2. 1999 Bruce E. Smith, PE. AAI Coil Tubing Drilling Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Prudhoc Bay Unit 11-25A ARCO Alaska. Inc. Permit No: 99-82 Sur Loc: 4708'FNL. 250'FEL. Sec. 28. T11N. RI5E. UM Btmhole Loc. 565'FNL. 1067'FEL. Sec. 29. T11N. RI5E. UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to rcdrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Bloxx-out prevcntion equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to alloxv a rcprescntative of the Commission to ,~vitncss a test of BOPE installed prior to drilling new hole. Notice max' be given bx- contacting thc Commission pctrolcum ficld inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC2 Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation ,~v/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill D Redrill ~] I lb. Type of well. Exploratory D Stratigraphic Test D Development Oil r~l Re-ently r~ Deepen [~]] Service Development Gas r'~ single zone r~l Multiple Zone r'] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28326 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.02.51) 4708' FNL, 250' FEL, Sec. 28, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1211' FNL, 1035' FEL, SEC. 29, T11 N, R15E, UU 11~25A #U-630610 At total depth 9. Approximate spud date Amount 565' FNL, 1067' FEL, Sec 29, T11 N, R15E, UM September 17, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'IYD) feet No Close Approach feet 12440' MD /8878' 'I'VD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 2.5.035 (e)(2)) Kickoff depth: 11620' MD Maximum hole angle 60° Vlaximum surface 2570 psicJ At total depth (TVD) 3450 psicJ @ 8800' 18. Casing program Settinc, i Depth size specifications Top Bottom Quantity o! Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 3" 2-3/8" 5.95 L-80 FL4S 3440' 9000' 6223' 12440' 8878' 22.5 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 12125 feet Plugs (measured) PBTD tagged @ 12038' MD (5/21/1999) true vertical 8920 feet measured 12038 feet Junk(measured) ORIGINAL Effective Depth: true vertical 8835 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 260 Sx PF 112' 112' Surface 2976' 13-3/8" 2200 Sx Fondu & 400 Sx PF II 3034' 2672' Production 9584' 9-5/8" 500 Sx Class G 9642' 6659' Liner 2808' 7" 550 Sx Class G 12115' 8907' Perloration depth: measured 11912' - 11924'; 11928' - 11940'; 11963' - 11987'. true vertical 8712' - 8724'; 8727' - 8739'; 8762'- 8785'. 20. Attachments Filing fee .~1 Property Plat r-1 BoP Sketch ~] Diverter Sketch D Drilling program [] Anch0ra§¢ Drilling fluid program Time vs depth plot r~ Refraction analysis E~] Seabed report D 20 AAC 25.050 requirements r~ 21. i hereby certify that the foregoing ~ t~ue'~nd correct to the best ~my knowledge Questions? Call Mark Johnson @ 265-1305. Signed it AAI Coil Tubing Drilling Supervisor Date Bruce E. Smith, P.E. v~ f I ~ Prepared b~/ Paul Rauf 263-4990 /",,~ L/Commission Use Onl) Permit Number I APInumber [ mprova, date^ ISee cover letter ~'~'-- ~:~'~_.. 50-~:)-~--~'--~--(:~--~o°'~-~c~'~--- Y"'~" ~¢ Iforotherrequlrements Conditions of approval Samples required [~] Yes ~' No Mud Icg required r"] Yes ~ No Hydrogen sulfidemeasures ~ Yes [~ No Directional surveyrequired ~ Yes ~1 No Required working pressure for BOPE K12M; [~ [~ 5M; [~ lOM;E~] r~i 3500 psi for CTU v Other: by order of Approved by ORIGINAL ~ ll'~l~l ~'r~ Robert N. Chnstenson Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 11-25A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a 60° inclination well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 11550' md. Mill window in 7" casing at -11620' md. Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. Directionally drill 2.75" (or 3") x 820' well to access Sadlerochit reserves. Inclination through target formation will be -60°. Run and cement 2-3/8'"' liner to TD. Note: The top of liner may be extended up to -9000' to cover a tubing leak at 9310' MD. A liner top packer or cement would then be used to isolate the leak, · Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at CC2A or GNI and drilling mud will be disposed at CC2A, GNI, or Pad 3. August 13, 1999 5-1/2", 17#, L-80 Tubing to 9272' Top of 2-3/8" Liner -9000' Completed Cement Top @ N9000' 7" @ 93O7' 9-5/8" Shoe @ 9642' 3-1/2", 12.5#, N-80 Tubing to 11420' Packer @ 11334' XN Nipple @ 11409' P&A Cement Top @ 11550' Tubing Tail @ 11419' Window @ 11620' 2-3/8" FL4S Liner Cemented & Perforated 3" 0 en Hole 7"Shoe @ 12115! TD @ 12440' 11-25A Version#1 Plan.xls Created by Date ptotted :12-Aug-1999 Plot Reference is 11-25A Verslon~5, Coordlrlates are in feet reference II-25 iTrue Vertical Depths are reference RKB - MSL --- Baker Hughes INTEQ <- West {feef) .............................................................................. 6700 6600 6500 6400 6300 6200 6100 6000 5900 5800 5700 5600 8200 8500 8400 8500 8600 8700 8000 - ~ 8100- Kick-off Doint tT Target 11-25 Bose of 8800 : b x.% TD 8900 :~ _ q 0{.~0 - 5709 5~00 59074"'3n 4!99 4330 4400 -.500 47C~, 4853 z900 Vertical Section (feet) -> Azimuth 356.00 with reference 0.00 S, 0.00 W from 11-25 - Target '~,, Kick-off PoNt * Tie on 4100 4000 I Z o 5900 ~ -.+, 3800 ~ --i- - ~ -5700 Prepared by BHI 08/13/99 Proposal Calculations EH~G~S Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Alaska~ Inc. Vertical Sect. Plane: 356.000 TRUE Job No: 0 Field: Prudhoe Bay~ Alaska Mag. Declination: 27.600 AFE No: 0 Well: 11-25A Version #5 Grid Correction: 1.580 API No: 50-029-20488-01 Rig: Nabors 3S Total Correction: 26.020 BHI Rep: 0 Surface Location Dip: 80.730 Job Start Date: 00-Jan-00 X: 707282.7 RKB Height: 49.770 Job End Date: 00-Jan-00 Y: 5952286.6 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn )-"- Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) fit) Lat. (Y) Dep. (X) Lat. (Y) De[~. (X) (°/100ft) /TIPl (°/100ft) (°/100ft) 11500.00 11.70 327.53 8258.80 3510.20 -6066.13 5955628.00 701122.39 0.00 3924.80 -83.00 0.00 0.00 Tie-in Point 11525.00 11.71 327.24 8283.28 3514.47 -6068.86 5955632.20 701119.54 0.24 3929.26 -82.00 0.04 -1.16 11550.00 11.71 326.95 8307.75 3518.73 -6071.62 5955636.38 701116.67 0.24 3933.70 -82.00 0.00 -1.16 11575.00 11.72 326.67 8332.23 3522.98 -6074.40 5955640.55 701113.77 0.24 3938.13 -82.00 0.04 -1.12 11600.00 11.73 326.38 8356.71 3527.22 -6077.20 5955644.71 701110.85 0.24 3942.55 -90.00 0.04 -1.16 11620.00 11.73 326.37 8376.29 3530.61 -6079.45 5955648.03 701108.51 0.01 3946.09 0.00 0.00 -0.05 Kick-off Point 11625.00 13.48 326.37 8381.17 3531.52 -6080.05 5955648.92 701107.88 35.09 3947.04 0.00 35.00 0.00 11650.00 22.26 326.37 8404.94 3537.90 -6084.30 5955655.19 701103.46 35.09 3953.70 0.00 35.12 0.00~ ! 1675.00 31.03 326.37 8427.27 3547.22 -6090.50 5955664.34 701097.01 35.09 3963.43 0.00 35.08 0.00 1 !686.57 35.09 326.37 8436.97 3552.48 -6094.00 5955669.49 701093.37 35.09 3968.92 0.00 35.09 0.00 11700.00 39.80 326.37 8447.62 3559.27 -6098.52 5955676.16 701088.66 35.09 3976.02 0.00 35.07 0.00 11725.00 48.58 326.37 8465.53 3573.77 -6108.16 5955690.38 701078.62 35.09 3991.15 0.00 35.12 0.00 11750.00 57.35 326.37 8480.57 3590.37 -6119.20 5955706.67 701067.13 35.09 4008.48 0.00 35.08 0.00 11757.55 60.00 326.37 8484.50 3595.74 -6122.77 5955711.94 701063.41 35.09 4014.09 94.00 35.10 0.00 3 11775.00 59.88 328.18 8493.24 3608.44 -6130.94 5955724.42 701054.90 9.00 4027.33 93.00 -0.69 10.37 ~)~ 11800.00 59.76 330.78 8505.81 3627.06 -6141.91 5955742.72 701043.42 9.00 4046.66 92.00 -0.48 10.40 11825.00 59.69 333.38 8518.41 3646.13 -6152.02 5955761.51 701032.79 9.00 4066.40 91.00 -0.28 10.40 11850.00 59.67 335.99 8531.04 3665.64 -6161.24 5955780.75 701023.03 9.00 4086.50 89.00 -0.08 10.44 11875.00 59.701 338.60 8543.66 3685.54 -6169.57 5955800.42 701014.15 9.00 4106.94 88.00 0.12 10.44 11900.00 59.78~ 341.20 8556.26 3705.82 -6176.99 5955820.48 701006.18 9.00 4127.68 87.00 0.32 10.40 11925.00 59.91 343.80 8568.82 3726.43 -6183.49 5955840.91 700999.11 9.00 4148.70 85.00 0.52 10.40 11937.35 60.00 345.08 8575.00 3736.73 -6186.36 5955851.12 700995.96 9.00 4159.17 93.00 0.73 10.36 4/FaultIntersection 11950.00 59.93 346.39 8581.33 3747.35 -6189.06 5955861.66 700992.97 9.00 4169.95 93.00 -0.55 10.36 11975.00 59.83 348.99 8593.88 3768.47 -6193.67 5955882.64 700987.78 9.00 4191.34 91.00 -0.40 10.40 12000.00 59.78 351.59 8606.46 3789.77 -6197.31 5955903.83 700983.55 9.00 4212.84 90.00 -0.20 10.40 12025.00 59.78 354.20, 8619.04 3811.20 -6199.98 5955925.18 700980.29 9.00 4234.41 89.00 0.00 10.44 12050.00 59.83 356.80 8631.62 3832.74 -6201.68 5955946.66 700978.01 9.00 4256.01 88.00 0.20 10.40 12075.00 59.93 359.40 8644.16 3854.35 -6202.39 5955968.24 700976.69 9.00 4277.62 86.00 0.40 10.40 12086.66 60.00 0.61 8650.00 3864.44 -6202.39 5955978.33 700976.42 9.00 4287.69 96.00 0.60 -3077.10 5/TopofTar~et Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. (Y) DeF. (X) Lat. (Y) Dep. (X) (°/100ft) /'I'IP/ (°/100ft) (°/100ft) 12100.00 59.87 1.99 8656.68 3875.98 -6202.13 5955989.88 700976.36 9.00 4299.18 96.00 -0.97 10.34 12125.00 59.65 4.58 8669.28 3897.54 -6200.89 5956011.46 700977.00 9.00 4320.60 94.00 -0.88 10.36 12150.00 59.49 7.19 8681.94 3918.98 -6198.68 5956032.95 700978.62 9.00 4341.84 93.00 -0.64 10.44 12175.00 59.38 9.80 8694.65 3940.27 -6195.51 5956054.32 700981.21 9.00 4362.85 92.00 -0.44 10.44 12200.00 59.32 12.41 8707.40 3961.37 -6191.36 5956075.53 700984.77 9.00 4383.61 90.00 -0.24 10.44 12225.00 59.32 15.03 8720.16 3982.26 -6186.27 5956096.54 700989.29 9.00 4404.09 89.00 0.00 10.48 12250.00 59.37 17.64 8732.91 4002.89 -6180.22 5956117.34 700994.76 9.00 4424.25 88.00 0.20 i0.44 12275.00 59.47 20.25 8745.63 4023.25 -6173.23 5956137.87 701001.19 9.00 4~.~.~..07 86.00 0.40 10.44 12300.00 59.62 22.86 8758.30 4043.29 -6165.31 5956158.12 701008.55 9.00 4463.51 85.00 0.60 10.44 12325.00 59.82 25.45 8770.91 4062.98 ~6156.48 5956178.06 701016.83 9.00 4482.54 84.00 0.80 10.36 12343.13 60.00 27.33 8780.00 4077.04 -6149.50 5956192.29 701023.42 9.00 4496.07 92.00 0.99 10.37 6 ! Base of Target 12350.00 59.97 28.04 8783.44 4082.30 -6146.74 5956197.63 701026.03 9.00 4501.13 92.00 -0.44 10.33 Rathole '~ 12375.00 59.92 30.64 8795.96 4101.16 -6136.14 5956216.78 701036.11 9.00 4519.21 90.00 -0.20 10.40 Rathole .. 12400.00 59.91 33.24 8808.49 4119.52 -6124.70 5956235.44 701047.04 9.00 4536.72 89.00 -0.04 10.40 Rathole 12425.00 59.95 35.84 8821.02 4137.33 -6112.43 5956253.59 701058.81 9.00 4553.64 88.00 0.16 10.40 Rathole 12440.00 60.00 37.40 8828.53 4147.76 -6104.68 5956264.22 701066.27 9.00 4563.50 0.00 0.33 10.40 TD C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection tis 7" WLA Quick onnect --"- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ---- 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold ~ . Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve · 0.458' (5,5") ' 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Shop Fuel Boilers Mul Tanks Water Pump Fire Ext. ~, 60/40 I hire Ext. /{Pipe rac/~ O~ Fire Ext. Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling DS 11-25 Drilling Program Well 11-25 is a sidetracked well out of the original DS 11-14 (T3) well. The lower wellbore of the original well has been plugged and abandoned per Sundry Notice dated 01/28/87. This Well Plan begins after all cement plugs are in place. NOTE: 13-5/8" BOP equipment will already be in place. 1. RU Schlumberger and run CET from about 11,000' to 9000'. Planned sidetrack depth is 9600'. 2. Run 60 arm casing inspection tool from 11,000' to surface. 3. Evaluate CET. Squeeze if necessary. 4. Set Baker DW-1 packer at about 9600'MD. 5. Run single shot gyro and obtain key slot orientation. 6. TIH w/whipstock on DP. Whipstock face should be oriented at about 45° left of high side. 7. Anchor whipstock in packer and make starting cut. 8. Open window and proceed to drill 8-1/2" hole to TD at 12,194'MD (8974'TVD). 9. If the NL Baroid RLLB tool was not used, run open hole logs. Depending on drilling time, a casing inspection log may be run to evaluate the 9-5/8" casing. 10. Set 7" liner from 9300'-12,194'MD (6431'-8974'TVD). Hanger setting depth may be altered depending on casing condition. 11. Clean out liner and test to 3000 psi. Displace with 9.4 ppg brine. 12. Secure well and release rig. 13. Run cased hole logs. 14. MIRU completion rig. 15. Run 5-1/2" x 3-1/2" tubing string with 3-1/2" x 7" packer, gas lift mandrels and SSSV. 16. NU tree and test to 5000 psi. 17. Secure well and release completion rig. 18. Perforate well and stimulate as needed. PD2/O6a 1-30-87 ARCO ALASKA INC. P. O. BOX 100360 ATO 1509 ANCHORAGE, AK 99510-0360 .~cay to the ., .,, / PAUL RAUF 015412452359 1 ~ 2 ~ /') ,, , ~ 2-1/710 ~ ~. I$1~.~ NOT wu9 FOR OVER Sl000.00 0FIl~'r CHICAGO The First National Bank of Chicago Chicago, Illinois 60670 / ~'-O ? ],DODO I, ~,~: c~o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION APPLICATION FOR SUNDRY APPROVALS Alter casing _ Repair well _ Change approved program _ Operational shutdown _ Re-enter suspended well _ Plugging _X Time extension _ Stimulate _ Pull tubing _ Vadance _ Perforate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4708' FNL, 250' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1211' FNL, 1035' FEL, SEC. 29, T11N, R15E, UM At effective depth At total depth 1095' FNL, 1102' FEL, Sec. 29, T11N, R15E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service _ 6. Datum elevation (DF or KB feet) RKB 58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 11-25 9. Permit number / approval number 87-11 50-029-20488-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12125 feet Plugs (measured) true vertical 8920 feet Effective depth: measured 12038 feet Junk (measured) true vertical 8835 feet Casing Length Size Cemented Conductor 1 10' 20" 260 Sx PF Surface 2976' 13-3/8" 2200 sx Fondu & 400 Sx PF II Production 9584' 9-5/8" 500 Sx Class G Uner 2808' 7" 55o Sx Class G Perforation depth: measured 11912' - 11924'; true vertical 8712' - 8724'; Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) PBTD tagged @ 12038' MD (5/21/1999) Measured Depth Truevertic~ Depth 112' 112' 3034' 2672' 9642' 6659' 12115' 8900 11928'-11940'; 11963'-11987'. ORIGINAL 8727'-8739'; 8762'-8785'. 5-1/2", 17#, L-80 PCT @ 9272' MD; 3-1/2', 12.6#, N-80 PCT @ 11420' MD. 7" X 3-1/2' BAKER FB-1 EL PERMANENT PACKER @ 11335' MD. 5-1/2" CAMCO BAL-O SSSV @ 2252' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch ._.X 14. Estimated date for commencing operation 15. Status of well classification as: September 1, 1999 16. If proposal was verbally approved Oil __X Name of approver Date approved Service 17. I hereby certily that the loregoing is~rue~d correct to the best o! my knowledge. Signed ' I Bruce E. Smith, P.E. / ,/ F(~R COMM ~3~,ommission so representative may witness Gas __ AAI Coil Tubing Drilling Supervisor ~R COMMISSION USE ONLY Suspended Questions? Call Mark Johnson ~ 265-1305. Date (~;jTj~ ~/~ ~ Prepared b~/ Paul Rabf 263-al,qgo Conditions of approval: Not Plug integrity __ BOP Test _ Mechanical Integrity Test __ Approved by order of the Commission Location clearance _ Subsequent form required 10- Appr°va' ,~f __/~1 Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ~ wellbore seg ann. disposal para req WELL PERMIT CHECKLIST FIELD & POOL ~'~//4::~/~"~:~ ADMINISTRATION COMPANY ENGINEERING APPR. D,ATE WELL NAME/~_~. ///".2~ PROGRAM: exp dev ~' redrll .~ serv INIT CLASS Z~z.~ //'-,d3,~"// GEOL AREA ~.~'<;~ UNIT# 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 drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Ddlling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~OOO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ON/OFF SHORE (~)N GEOLOGY AB.PR DATE, 29. Is presence of H.S gas probable ................. ~ Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ~y ~ ~ ~., 33. Seabed condition survey (if off-shore) ............. / 34. Contact name/phone for weekly progress reports [explorato~;~ily] Y N / ANNULAR DISPOSAL APPR DATE 35. With proper cemen~ting records, this plan (A) will containcC~s~-- in a suitab~7.,~iving zone; ....... Y N (B) will not contarr/nate fres~ter; o/cause dn'llin~q~aste... Y N to surface; / / // ~ (C) will not iml~ir~h~nte~he well used for disposal; Y N (D) will not da~-~ formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular JDH ~ COMMISSION: DWJ ~ RNC co _~.,~ ~!~, ! ~ Comments/Instructions: 0 Z --I m Z i> c:\msoffice\wordian\diana\checklist Well Histo.ry 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 APPENDIXi No 'special'effort has been made to chronologically organize this category of information. · ,, · ,o Tape Subfile 1 is type: LIS **** REEL HEADER MWD **/ 8/31 BHI O1 LIS Customer Format Tape ** TAPE HEADER **** MWD 00/ 8/31 107730 01 i.75" NaviGamma - Gamma Ray data LIS COMMENT RECORD(s): ~234567890~23456789~~234567890~234567890~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: Header.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.F 11550.0000: Starting Depth STOP.F 12405.0000: Ending Depth STEP.F 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPA~Y: ARCO Alaska, Inc. WELL. WELL: !!-25A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 4708' FNL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray REF . JOB REFERENCE: 107730 DATE. LOG DATE: 12 Sep 99 API. API NUMBER: 500292048802 -Parameter Tnformation Block #MNEM.UNIT Value Description FL 250' FEL : Field Location SECT. 28 : Section TO~q.N lin : Township RANG. iSE : Range PDAT. MSt : Permanent Datum EPD .F 58' : Elevation Of Perm. Datum LMF . KB : Log Measured From FAPD. F 58 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 58' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL .F N/A : Elevation Of Ground Level CAFE.F 11575 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 Remarks -~ (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 11-25A was kicked off @ 11575' MD (8332' SSTVD) from the wellbore of Well 11-25. RECEIVED SEP lS 2000 A~ask.a Oil & Gas Cons. Commission Anchoraoe (5 Well 11-25A was drilled to TD @ 12400' MD (8802' SSTVD) on Run 10. (6 The interval from 12381' MD (8802' SSTVD) to 12400' MD (8802' SSTVD) was not logged due to sensor to bit offset. (7 The Gamma Ray log has been depth shifted to match ProActive Diagnostic Services Gamma Ray logged 13 September 1999. (8 A Magnetic Declination correction of 27.60 degrees has been applied to the Directional Surveys. ~Mnemonics GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet ~Sensor Offsets RUN GAMMA DIRECTIONAL 6 21.40 ft. 25.55 ft. 7 18.19 ft. 23.17 ft. 8 17.62 ft. 22.60 ft. 9 18.05 ft. 23.03 ft. 10 18.21 ft. 23.19 ft. Tape Subfiie: I 66 records... Minimum record length: '14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 11-25A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~Z3456789~23456789~23456789~23456789~23456789~23456789~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska Inc. 3. The PDC used is the ProActive Diagnostic Services' open hole gr_dil Gamma Ray data, dated 13 September, 1999. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 [GR 2 ROP ~ FORMAT RECORD (TYPE~ 64) Entry Type( 1) Size( 1) Data record type is: GRAX 0.0 ROPS 0.0 Repcode(66) 0 Entry Type( 2) Size 1 Repcode 66 Datum Specification Block Type is: 0 Entry Type( 3) Size 2 Repcode 79 Datum Frame Size is: 12 bytes Entry Type( 4) Size 1 Repcode 66 Logging direction is down (value= 255) Entry Type( 5) Size( 1 Repcode 66 Optical Log Depth Scale Units: Feet Entry Type( 8) Size( ~4 Repcode 68 Frame spacing: 0.500000 Entry Type( 9) Size 4 Repcode 65 Frame spacing units: F ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode( 66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry t~pes encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size GR MWD 68 1 API 4 ROP ~D 68 ~ 4 DATA RECORD (TYPE# 0) Total Data Records: 21 1014 BYTES * API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 i 4 99 995 99 1 Tape File Start Depth = 11545.000000 Tape File End Depth = 12405.000000 Tape File Level Spacing = -0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5167 datums Rep Code: 79 2 datums Tape Subfile: !2~. 28 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 11-25A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i GPJ%X GRAX 2 ROPS ROPS * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size 1) Repcode 66 Data record type is: 0 Entry Type( 2) Size 1) Repcode 66 Datum Specification Block Type is: 0 Entry Type( 3) Size 2) Repcode 79 Datum Frame Size is: 12 bytes Entry Type( 4) Size 1) Repcode 66 Logging direction is down (value= 255) Entry Type( ° 5) Size 1) Repcode 66 Optical Log Depth Scale Units: Feet Entry Type( 8) Size 4) Repcode 68 Frame spacing: 0.500000 Entry Type( 9) Size 4) Repcode 65 Frame spacing units: F ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repeode( 66) Datum Specification Block Sub-type is: 1 Entry Block terminator. Summary of entry types encountered: 5~ 1 2 3 4 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 0.0 0.0 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size i GgJ~X ~5~D 68 ! 4 2 ROPS N~ND 68 i 4 * DATA RECORD (TYPE# 0) Total Data Records: 21 1014 BYTES * Tape File Start Depth = 11545.000000 Tape File End Depth = 12405.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5167 datums Rep Code: 79 2 datums Tape Subfile: 3 2° records Minimum record length: 54 bytes Maximum record length: 1014 bytes [] Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD oo/ 8/31 107730 01 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 **** REEL TRAILER MWD **/ 8/31 BHI 01 Tape Subfile: 4 ' Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Thu 31 AUG ** 3:10p Elapsed execution time = 1.49 seconds. SYSTEM RETURN CODE = 0 [] Tape Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH GR ROP 11545.0000 -999.2500 -999.2500 11545.5000 -999.2500 -999.2500 11600.0000 43.3200 90.0000 11700.0000 26.2200 12.8000 11800.0000 23.9400 47.6000 11900.0000 99.1800 45.3280 12000.0000 22.8000 18.6000 12100.0000 28.3540 60.0000 12200.0000 23.9400 75.0000 12300.0000 112.8600 39.8460 12400.0000 -999.2500 23.3530 12405.0000 -999.2500 -999.2500 Tape File Start Depth = 11545.000000 Tape File End Depth = 12405.000000 Tape File Level Spacing = 0.500000 Tape. File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11545.0000 -999.2500 -999.2500 11545.5000 -999.2500 -999.2500 11600.0000 60.5860 68.3110 11700.0000 22.8000 26.0000 11800.0000 23.9400 47.6000 11900.0000 78.6600 49.3000 12000.0000 22.8000 18.6000 12100.0000 27.3600 60.0000 12200.0000 23.9400 46.1160 12300.0000 110.5800 40.9000 12400.0000 -999.2500 31.3000 12405.0000 -999.2500 -999.2500 Tape File Start Depth = 11545.000000 Tape File End Depth = 12405.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS RECEIVED i'