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Home My WebLink About199-0221a. Well Status:Oil Gas SPLUG Other Abandoned Suspended GINJ WINJ WAG WDSPL No. of Completions: 2. Operator Name: 3. Address: 4a. Location of Well (Governmental Section): 4b. Location of Well (State Based Plane Coordinates, NAD 27): 5. Directional or Inclination Survey: 6. Date Comp., Susp., or Aband.: 1b. Well Class: 7. Date Spudded: 14. Permit to Drill Number / Sundry: 15. API Number: 16. Well Name and Number: 17. Field / Pool(s): 18. Property Designation: 19. DNR Approval Number: 20. Thickness of Permafrost MD/TVD: 21. Redrill/Lateral Top Window MD/TVD: 8. Date TD Reached: 9. Ref Elevations: KB: 10. Plug Back Depth MD/TVD: 11. Total Depth MD/TVD: 12. SSSV Depth MD/TVD: 13. Water Depth, if Offshore: GL: BF: Development Service Exploratory Stratigraphic Test 20AAC 25.105 20AAC 25.110 Surface: Top of Productive Interval: Total Depth: Yes No(attached) Surface: TPI: Total Depth: x- x- x- y- y- y- Zone- Zone- Zone- Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 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 suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. CASING WT. PER FT.GRADE TOP BOTTOM TOP BOTTOM HOLE SIZESETTING DEPTH TVDSETTING DEPTH MD CEMENTING RECORD AMOUNT PULLED CASING, LINER AND CEMENTING RECORD23. Yes No Yes No 24. Open to production or injection? If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd or liner run): 25. TUBING RECORD SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27.PRODUCTION TEST Date of Test:Hours Tested: Flow TubingPress. Casing Press: Oil-Bbl: Oil-Bbl: Gas-MCF: Gas-MCF: Water-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): Production for Calculated 24-Hour Rate Test Period Method of Operation (Flowing, gas lift, etc.): WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 4/11/1999 50-029-20223-01-00 PBU 09-07A 199-022 8900' / 8386' PRUDHOE OIL ADL 0028324 , 0028327 74-01710934' / 9009' N/A ~1900' 9248 / 8708 0 12/10/2024 N/A 4/23/1999 ASP4 ASP4 ASP4 5943399 5945340 5946800 718315 716762 717224 RES, GR, CCL, Temp, MWD 1191' FSL, 1633' FEL, Sec. 23, T10N, R15E, UM 3917' FSL, 1544' FEL, Sec. 02, T1ON, R15E, UM 1933' FSL, 49' FEL, Sec. 02, T1ON, R15E, UM 20"94#H-40 Surface 108'Surface 108' 30" 300 sx Arctic Set 13-3/8"72#N-80 Surface 2772'Surface 2772' 17- 1/ 2" 6700 sx Arctic Set 9-5/8"47#RS-95 / Surface 9248'Surface 8708 12- 1/ 4" 1000 sx Class' G', 300 sx Arctic S 3-3/16"6.2# L-80 9105'10847'8576'9002' 4- 1/ 8" 16 Bbls 15.6 ppg LARC 3-1/2" 9.3# L-80 8867' 8951'/ 8442'8920'-9063'5-1/ 2", 17#, 13Cr80 ~2500 -4017'MD Tbg x IA 401 290 bbls 15.3 ppg Class G Cmt 502' MD Tbg x IA x OA 51 bbls 15.8 ppg Class G Cmt Not on Production N/A 21 22 54 324-036 PRUDHOE BAY Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Date First Production: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov By James Brooks at 3:00 pm, Jan 08, 2025 Abandoned 12/10/2024 JSB RBDMS JSB 011525 xGDSR-4/7/25JJL 5/6/25 SFD 3/27/2025 28. CORE DATA Conventional Cores(s): Yes No Sidewall Cores(s): Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and persence 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 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)30. FORMATION TESTS Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this for, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. MD TVDNAME Permafrost - Top Permafrost - Base Top of Productive Interval Formation Name at TD: 31. List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). 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). 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. 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. 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). 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 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. 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. 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: INSTRUCTIONS Bo York Operations Manager Andy Ogg Andrew.Ogg@hilcorp.com (907) 659-5103 Daily Operations Summary, Wellbore Schematic, Well Photos Permafrost - Top Permafrost - Base Top of Productive Interval Sadlerochit Zone 1B Zone 1A 9222' 9222' 9791' 9963' 8684' 8684' 8978' 9022' Zone 1A 9963 9022 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.01.08 07:05:49 - 09'00' Bo York (1248) FULL ABANDONMENT - ALL CSG STRINGS CUT OFF 3'8" BELOW TUNDRA ELEVATION MARKER PLATE WELDED TO CONDUCTOR (12/10/24) ACTIVITYDATE SUMMARY 4/2/2024 ***WELL S/I ON ARRIVAL*** (drift for eline cbp) SCAFFOLD CREW INSTALLS SCAFFOLD ON WELL HEAD RAN 2.725" CENT, 1.75" SAMPLE BAILER, DRIFT FREELY TO 4,800' SLM (target depth of 4,500' md) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 4/6/2024 ***WELL S/I ON ARRIVAL*** (PLUG AND TUBING PUNCH) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH SET NS 2.75''CIBP @ 4500' MD, (CCL TO MID ELEMENT 10', CCL STOP DEPTH 4490' MD) CCL LOG CORRELATE TO CASING TALLY DATED 02/27/2016 PT PLUG TO 2000 PSI W/ TRIPLEX (PASS) PUNCH TUBING FROM 4016.5''-4021.5' CCL TO MD ELEMENT 6.5' CCL STOP DEPTH 4010'' CCL LOG CORRELATE TO CASING TALLY DATED 02/27/2016 ***JOB IN PROGRESS*** 4/7/2024 *** JOB CONTINUED FROM 4/6/24*** POOH W/ 1.56'' TUBING PUNCH CONFIRMED TXIA COMMUNICATION W/ TRIPLEX JOB COMPLETE **WELL S/I ON DEPARTURE*** 8/19/2024 T/I/O= 26/17/62, LRS Unit 72,(PLUG AND ABANDONMENT)Pummped 50 bbls of DSL down TBG and up IA out to open tops, Shut in to open tops and let TBG and IA U-TUBE for one hour, Well secured DSO notified upon departure FWHP= 265/264/65 8/28/2024 Circulate Upright to of Fresh water to 78*F. 8/28/2024 T/I/O = 200/130/60 (PLUG AND ABANDONMENT) **Assist Halliburton** Pump 5 bbls 60/40 meth spear. Pump 7.7 bbls 9.8 ppg brine followed by 9 bbls 60/40 to displace cement and Freeze protect. Freeze protect Skid with 2 bbls Diesel. DSO Notified of well status upon departure. SV,MV, Choke Skid = Closed IA,OA = OTG FWHPs = 1196/267/84 8/28/2024 T/I/O= 200/130/60 HES Cement IA to surface. Tubing cement ~2,500' - 4,016.5' MD. LRS pumped 5 bbls of 50/50, HES pumped 75 bbls of hot surfactant, 10 bbls of FW spacer, 290 bbls of 15.3 ppg Class G cement down tubing while taking returns out of the IA. Launced foam ball with 5 bbls of FW. Confirmed 15.3 ppg of cement from IA at surface. LRS pumped displacement of 7.7 bbls of 9.8 brine. Shut-in IA and and began to squeeze off PC leak, pressured tubing up to 2,000 psi with 2.2 bbls of 50/50 and had a pressure fall off of 100 psi in 10 mins. Then displaced the rest of the 50/50 for a total of 9 bbls, Job complete. TOC in tubing ~ 2,500' and IA cemented from 4,016.5' MD to surface. Daily Report of Well Operations PBU 09-07A Daily Report of Well Operations PBU 09-07A 9/1/2024 T/I/O = 0/VAC/60. Temp = SI. Strap IA Cement top (P&A). Dry hole tree installed. Removed IA CV flange, valve fiiled full of cement. Re-install IA CV flange and torqued up. SV = C. MV = O. IA, OA = OTG. 11:00 9/19/2024 *****WELL S/I ON ARRIVAL***** RAN 2.25" CENT,1.75" S.BAILER (ms-bb) TAG TOC @ 2,261' SLM (recovered bailer of cement) STATE WHITNESS MIT-T PASSED RAN 2.25" CENT,1.75" S.BAILER (ms,bb) TAG TOC @ 2,261' SLM - Confer w/ State Rep & WSS Cement Sample Good. *****WELL LEFT S/I ON DEPARTURE***** 9/19/2024 T/I/O=27/0/67 MIT T PASSED to 2250 psi ( MA=2500 psi ) / AOGCC MIT T PASSED to 2250 psi ( MA=2500 psi ) ( Witnessed by J. Hunt) Pre Test:Pumped 0.36 bbls diesel down tbg to 2551 psi TP lost 107 psi 1st 15 min & 32 psi 2nd 15 mins. Bled back 0.3 bbls. AOGCC MIT T: Pumped 0.27 bbls diesel down tbg to 2575 psi TP lost 75 psi 1st 15 min & 20 psi 2nd 15 min. Bled back 0.25 bbls FWHPs=0/0/69 10/1/2024 ***WELL S/I UPON ARRIVAL*** MIRU HALLIBURTON PT TO 300PSI LOW AND 2500PSI HIGH RAN 1.56" GUN. PERFORATION TUBING AND CASING FROM 502'-507'.CCL TO TOP SHOT OFFSET 17.5'. CCL STOPPING DEPTH: 484.5'. PRESSURE UP TUBING TO 1000PSI BEFORE PERFORATION T/I/O: 1000/0/0 AFTER PERFORATION T/I/O: 600/0/0. 5 MINUTES LATER T/I/O: 200/0/0 RDMO ***WELL S/I ON DEPARTURE. PAD OP NOTIFID OF STATUS*** 10/10/2024 T/I/O= 0/0/7 Confirm circulation through perf tunnel from T x OA (PLUG AND ABANDONMENT) Open OA to OTT and allow energized fluid to bleed off. Circulated 66 bbls of 180-degree diesel at 0.4 bpm at ~2700 psi getting 1:1 returns. Pressured OA to 1000 psi and performed AP flush to OTT. Rate improved to 0.7 bpm at ~2700 psi. Circulated and additional 41 bbls of hot diesel for a total of 107 bbls. Deisel returns from OA started at 28 degrees and ended at 60 degrees on Return MM. RDMO and allow disel to soak in OA. FWHPs= 0/0/0 10/12/2024 T/I/O = 0/0/0. Temp = SI. WHPs. No AL or flowline. Dry hole tree. Scaffolding installed. SV, MV = C. IA, OA = OTG. 08:00 10/24/2024 *** WELL S/I ON ARRIVAL *** (TUBING/CASING PUNCH) MIRU HES PT LOW 300 PSI HIGH 3000 PSI PUNCH TUBING AND CASING FROM 493' TO 498' WITH 1.56" MILLENIUM CHGS 6SPF 60PHASE CCL-TS=7.5', CCL STOP 485.5'. CONFIRM SHOTS FIRED RDMO HES ***WELL S/I ON DEPARTURE*** 10/27/2024 T/I/O = 0/0/5 (PLUG AND ABANDONMENT) Pump 48 bbls Diesel down TBG take returns out of OA to confirm circulation. Pad op notified of well status upon completion. Well S/I and DSO Notifed upon departure. FWHPs = 0/0/5 Daily Report of Well Operations PBU 09-07A 11/1/2024 HAL Cementing Job Scope: P&A - Cement Tbg and OA 500' to surface MIRU. PTW. PJSM. Tbg and OA zero psi. Well Supt install OA companion valve. Verify T x OA flowpath to return tanks and choke and bypass. PT HAL 3000 psi. Pump 50 bbls 160F surfactant wash, 20 bbl FW spacer, and 51 bbls 15.8 ppg class G cement (16 bbls excess) 1:1 returns through out. Close dry hole tree valves and OA valve on cement. Tbg and OA cemented from 500' to surface. Wash-up surface lines. DHD blew N2 across OA valves to clear wellhead. RD and release rig-up. ***Job Complete*** 11/1/2024 T/I/O = 0/0/0. Temp = N/A. Assist w/ cementing (P&A). No S-riser or flow line, Dry hole tree installed. IA cemented to surface. Integral flange and block valve installed on OA companion. RU to well. Pump 1.5 bbls MEOH down TBG taking returns out of OA to verify injectivity TBG xOA. Good returns to OT and 500 bbl tanks. HB pumped surfactant and cement. Blew down across top of OA w/ air. FP hard line to tanks w/ 4 bbl MEOH. FWHP's = 0/0/0. SV, MV = C. IA & OA = OTG. 17:15. 12/4/2024 ***P&A in Progress*** Pad Elevation = 21'. Tundra Elevation = 11'. Excavate with trimmer and bucket to a depth of 9' 6" below pad elevation. Tundra elevation clearly visible 10' below pad elevation. No water inflow. Cover excavation with rig mats. LDFN. 12/5/2024 ***P&A in Progress*** Pad Elevation = 21'. Tundra Elevation = 11'. Remove rig mats and continue excavation. Begin to notice the smell of hydrocarbons and shut down excavation. Contact SRT and Environmental. SRT inspected site, clear to proceed with excavation. Excavate to 15' 8" below pad elevation. Remove contaminated gravel/soil and send to GNI. Cover excavation with rig mats. LDFN. 12/6/2024 ***P&A in Progress*** Pad Elevation = 21'. Tundra Elevation = 11'. Excavation depth = 5'8" below tundra elevation. Remove rig mats, water inflowed ~1'. Vac out 25 bbls of water. Set shoring box. Callout Fire Department, rescue plan approved. LDFN. 12/7/2024 ***P&A in Progress*** Pad Elevation = 21'. Tundra Elevation = 11'. Excavation Depth = 5'8" below tundra elevation. Conduct CSE PJSM with DS Lead & HSE Rep. Vac out 30 bbls of water. Set WACHS Goliath guilotine saw 3' 8" below tundra elevation. Cut ~halfway through casing strings, blade breaks. Replace blade. LDFN. 12/8/2024 ***P&A in Progress*** Pad Elevation = 21'. Tundra Elevation = 11'. Excavation Depth = 5'8" below tundra elevation. Cut depth = 3'8" below tundra elevation. Conduct PJSM with DS Lead & HSE Rep. Finish wellhead removal. Cement at surface in all casing string annuli. Cement in good condition. Cover excavation with visqueen and place heater trunks into the excavation. LDFN. 12/10/2024 ***P&A Complete*** Conduct CSE & Hot Work PJSM with DS Lead, HSE Rep & Worley welding. AOGCC Inspector Josh Hunt verified cut casing strings, cement and marker plate. Split conductor patch and marker plate welded to conductor. Remove rig mats, pull shoring box and backfill excavation. Photo documentation of P&A stored in the U:drive. ***P&A Complete*** 2024-1210_Surface_Abandon_PBU_09-07A_jh Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:12/11/2024 P. I. Supervisor FROM: Josh Hunt SUBJECT:Surface Abandonment Petroleum Inspector PBU 09-07A Hilcorp North Slope LLC. PTD 1990220; Sundry 324-036 12/10/2024: I traveled to PBU 09-07A and met with Hilcorp representative Robert Bryan for a surface abandonment inspection. The excavation was complete and proper shoring procedures were followed. The hole was dug to a depth of 15 feet 8 inches from the pad level for abandonment operations. Original grade (tundra) was 10 feet below pad grade and the well was cut off 13 feet inches below pad grade – cutoff is 3 feet 8 inches below tundra or original grade. I had them beat on each ring of cement with a 5- foot steel bar to confirm good cement to surface in well spaces. They had to make a new cover plate due to the conductor being split. Confirmed the information on the marker plate was correct and gave them the go ahead to proceed with welding. The split in the conductor was welded up and the well was capped with the marker plate being welded on top of the new cap. Attachments:Photos () 2024-1210_Surface_Abandon_PBU_09-07A_jh Page 2 of 3 Surface Abandonment – PBU 09-07A (PTD 1990220) Photos by AOGCC Inspector J. Hunt 12/10/2024 2024-1210_Surface_Abandon_PBU_09-07A_jh Page 3 of 3 From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20241020 1238 APPROVAL PTD 199-022 PBU 09-07A Abandonment questions Date:Monday, October 21, 2024 2:39:26 PM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Sunday, October 20, 2024 12:38 PM To: 'Andrew Ogg' <Andrew.Ogg@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andrew, Perforating plan approved as you described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Andrew Ogg <Andrew.Ogg@hilcorp.com> Sent: Saturday, October 19, 2024 1:20 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Hi Mel, We have initiated the P&A work on 09-07A. The IA was cemented to surface on 08/28 and an AOGCC witnessed MIT-T passed with a slickline tag of 2261’ SLMD in the 3-1/2” tubing. Eline perforated through the 3-1/2” kill string/IA cement and 9-5/8” casing into the OA @ a depth of 502’-507’ MD (there is a tubing collar @ 500’ MD). Fullbore attempted to circulate from the tubing to OA but were only able to achieve a rate of 0.7 bpm @ 2700 psi. They circulated 107 barrels of diesel and the rate did not improve so I do not think arctic pack is the culprit. I would like your approval to shoot another 5’ of perfs from the Tbg into the OA in attempt to You don't often get email from andrew.ogg@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. increase the circulation rate and aid in pumping the Tbg/OA surface cement plug. I am proposing a depth of 493’498’ MD. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, February 29, 2024 2:38 PM To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andrew, Send me the revised procedure and schematic and I will append it to the existing sundry. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Andrew Ogg <Andrew.Ogg@hilcorp.com> Sent: Wednesday, February 28, 2024 6:31 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Hey Mel, Yes, we can do that. During the IA cement job, we will add cement volume and reduce the displacement volume to leave the cement top in the 3-1/2” @ 2500’. Here is an updated schematic, let me know if this works for you. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com You don't often get email from andrew.ogg@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. P: (907) 659-5102 M: (307)399-3816 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, February 28, 2024 3:52 PM To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andrew, Thanks for your response. AOGCC can approve the existing cement plugs across all annuli at the confining zones above the Prudhoe Bay oil pool. Regarding the surface casing shoe, AOGCC would like to see cement across all annuli at that shoe. This is a place in the wellbore with a recorded formation pressure test. With all annuli cemented at the surface casing shoe, a cemented barrier is in place at the shoe, that should endure the test of time and the corrosion that is expected to occur in the steal tubulars and limit possible pressurized fluid from migrating below. Can you place a cement plug of 200’ (100’ above and 100’ below) across the SC shoe withing the 3-1/2”? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Andrew Ogg <Andrew.Ogg@hilcorp.com> Sent: Wednesday, February 28, 2024 1:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Mel, Answers in red below. Let me know if you have any more questions. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, February 27, 2024 12:06 PM To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andy, In the well history, it is mentioned that perforations were to be added to access MI benefit. Where were those perfs to be added? They were planned to be added in the parent bore from 9285’ – 9295’ MD Was cement tagged and pressure tested inside the 3-1/16” liner at 9120’ MD. Yes, after service coil down squeezed the liner, they performed a coil flag log for depth control for the tbg cut and logged TOC @ 9117 MD. They also did a MIT-T that passed to 3,541 psi. What MD is the base of the upper confining zone for the PB oil pool on PBU 09-07 (PTD 176-058)? 9224’ MD Why not comply to 20 AAC 25.112 (c)(2)(C) and place cement on the EZSV at 8900’? Since we have the required cement over the top of the DPZ @ 9224’ MD and there is no other DPZ’s between the TOC @ 9120’ & the EZSV, I did not interpret this rule to apply to the production tubing stub. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 2 Township: 10N Range: 15E Meridian: Umiat Drilling Rig: n/a Rig Elevation: Total Depth: 10,934 ft MD Lease No.: ADL0028327 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2772 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 9248 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8,867 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 4,500 ft 2,261 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result MIT-T Tubing 2575 2500 2480 IA 0 0 0 OA 67 66 67 Remarks: Attachments: Andreas Ponti Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to location and met with the Little Red crew and Andreas Ponti representing Hilcorp. When I showed up I was informed that they had already tagged the cement and completed a pre-test on the tubing prior to my arrival. I told them to do it again for my witness (as described in approved Sundry). They did the pressure test first since they were still hooked up - good test. While they rigged the equipment down, I went over the slickline tools with the operator before running in the hole. They ran a 1 3/4-inch bailer with a ball valve and stabilizer, 8 ft of 2 1/8-inch weight pipe, a 4-ft set of oil jars, and a 8-ft set of spangs. This weighed roughly 150-160 lbs and 26 feet long. They hit cement at 2,261 ft MD and tagged it 5 times pretty hard. The depth never changed between runs or hits. They ended up with two cement samples - the first one had a better consistency; the second one was a little runny looking but did have some hard chunks in there with it. The next step in the Sundry is to perforate above the cement in the tubing and pump cement into the OA all the way to surface. I believe they are set up well to complete this with 2,239' of cement above the bridge plug. September 19, 2024 Josh Hunt Well Bore Plug & Abandonment PBU 09-07A Hilcorp North Slope LLC PTD 1990220; Sundry 324-036 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0919_Plug_Verification_PBU_09-07A_jh 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.04 16:38:26 -09'00' 2024-0919_Plug_Verification_PBU_09-07A_photos_jh Plug Verification – PBU 09-07A (PTD 1990220) Photos by AOGCC Inspector J. Hunt 9/19/2024 Bailer Sample 1 Bailer Sample 2 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 09-07A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-022 50-029-20223-01-00 10934 Conductor Surface Intermediate Production Liner 9009 75 2708 9219 1742 8900 20" 13-3/8" 9-5/8" 3-3/16" 8386 33 - 108 32 - 2772 29 - 9248 9105 - 10847 33 - 108 32 - 2772 29 - 8708 8576 - 9002 ~9006 520 2670 4760 8900 , 9120 1530 4930 6870 none 3-1/2" L-80 27 - 8867 none Structural 5-1/2" TIW HBBP 8958 , 8440 No SSSV 8951 8440 Bo York Operations Manager Ryan Holt Ryan.Holt@hilcorp.com (907) 659-5102 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028327 & 0028324 27 - 8356 0 0 0 0 0 0 0 0 0 0 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:11 pm, Aug 06, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.08.06 12:18:31 -08'00' David Bjork (3888) RBDMS JSB 080824 DSR-8/12/24WCB 10-1-2024 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay UNIT 09-07 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 199022 API Number: Lease Wellbore Traverses: Expiration Date: Operator: Hilcorp Alaska LLC Date Suspended: 2/26/2016 Surface Location: Section: 2 Twsp: 10N Range: 15E Nearest active pad or road: DS-09 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 4 Wellhouse and Well Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good FMC Wellhead and Tree Cellar description, condition, fluids: Good Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Good Tubing Pressure (or casing if no tubing): 70 psi Annulus pressures: IA - 40 psi OA - 40 psi Wellhead Photos taken (# and description): Work Required: None Operator Rep (name and signature): Ryan Holt AOGCC Inspector: Brian Bixby Other Observers: Inspection Date: 7/7/2024 AOGCC Notice Date: 7/6/2024 Time of arrival: 8:00 AM Time of Departure: 8:15 AM Site access method: Drive 500292022301 5 Year Digitally signed by Ryan Holt (4157) DN: cn=Ryan Holt (4157) Date: 2024.07.07 14:30:34 - 08'00' Ryan Holt (4157) ACTIVITYDATE SUMMARY 7/6/2024 T/I/O = LOTO/70/60. Temp = SI. WHPs (suspended well inspection). No AL. Dryhole tree installed. Wellhead, wellhouse, and cellar are clean. SV, MV = LOTO. IA, OA = OTG. 12:00 7/7/2024 T/I/O = 70/40/40. Temp = SI. WHPs (Well inspection). (Inspected by Brian Bixby). No AL or flowline. Dry hole tree. Wellhead, wellhouse and cellar are clean and dry. Surface area around well is clean and free of debris. Well ID sign attached to wellhouse. SV = C. MV = LOTO. IA, OA = OTG. 07:30 Daily Report of Well Operations PBU 09-07A Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϭϲͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐϮϰϬϳϬϳϭϮϱϱϯϲ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϳͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƌŝĂŶŝǆďǇ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϱͬϭϮͬϮϬϭϲ η ϯϭϲͲϭϲϭ dƵďŝŶŐ͗ϳϬ /͗ϰϬ K͗ϰϬ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ZǇĂŶ,Žůƚ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dϬϵͲϬϳ WĞƌŵŝƚEƵŵďĞƌ͗ϭϵϵϬϮϮϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ 'ŽŽĚ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ 'ŽŽĚ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ 'ŽŽĚ ŽŵŵĞŶƚƐ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚtŝƚŚƐͲƵŝůƚDĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽƐ;ϰͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϭϲ͕ϮϬϮϰ 9 9 9 9 9 9 2024-0707_Suspend_PBU_09-07A_photos_bb Page 1 of 2 Suspended Well Inspection – PBU 09-07A PTD 1990220 AOGCC Inspection Rpt # susBDB240707125536 Photos by AOGCC Inspector B. Bixby 7/7/2024 2024-0707_Suspend_PBU_09-07A_photos_bb Page 2 of 2 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 09-07A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-022 50-029-20223-01-00 ADL 0028327 & 0028324 10934 Conductor Surface Intermediate Production Liner 9009 75 2708 9219 1742 8900 20" 13-3/8" 9-5/8" 3-3/16" 8386 33 - 108 32 - 2772 29 - 9248 9105 - 10847 2500 33 - 108 32 - 2772 29 - 8708 8576 - 9002 ~99006 520 2670 4760 8900 , 9120 1530 4930 6870 none 3-1/2" L-80 29 - 8867none Structural 5-1/2" TIW HBBP 8958 , 8440 No SSSV Installed Date: Bo York Operations Manager Andy Ogg Andrew.Ogg@hilcorp.com 307-399-3816 PRUDHOE BAY 2/7/24 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:14 pm, Jan 25, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.01.25 12:46:55 - 09'00' Bo York (1248) 324-036 SFD 1/30/2024 DSR-1/26/24 * AOGCC to witness as described. * Photo document cement in all annuli before top cementing. * Photo document cement in all annuli before welding plate * Photo document welded plate in place. 2500 MGR01MAR24 10-407 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.01 15:50:54 -09'00' RBDMS JSB 030524 P&A Well:09Ͳ07A PTD:199Ͳ022 API:50Ͳ029Ͳ20223Ͳ01Ͳ00 WellName:09Ͳ07APermittoDrill:1990220 CurrentStatus:SuspendedAPINumber:50Ͳ029Ͳ20223Ͳ01 EstimatedStartDate:2/7/2024EstimatedDuration:14days RegulatoryContact:CarrieJanowski FirstCallEngineer:AndyOgg307Ͳ399Ͳ3816 SecondCallEngineer:BrodieWages713Ͳ380Ͳ9836 CurrentBottomHolePressure:Perfscemented,hydrostaticatEZSV(8900’MD,8386’TVD)=3531psi Max.AnticipatedSurfacePressure:2500psiMaxtreatingpressure LastSIWHP:0psi MinID:2.80”,3Ͳ3/16liner@9079’’MD MaxAngle:101deg@10120’MD WellHistory: Well09Ͳ07wasoriginallydrilledin1976.Itwassidetrackedto09Ͳ07Ain1999andwasa100%onͲtime producerthrough2009untiltheoilproductiondeclinedandthewellwasnolongercompetitive.ARWOwas plannedtoremovedamagedlinerandabandonthelowerperfs(AͲbore).Afterabandoningthelowerperfs, newperfsweregoingtobeaddedinthe9Ͳ5/8”intermediatecasing(parentͲbore)toprovideaccesstoMI benefit.InDecemberof2015serviceCoilTubingcementedtheAͲboreperfsupto9120’CTMDanda subsequentMITͲTpassedto3,638psi.Thedamagedlinerwascut@9105’CTMDandthe5Ͳ1/2”production tubingwascut@8920’MD.ARWOwasattemptedinFebruaryof2016butafterthe5Ͳ1/2”productiontubing waspulleda9Ͳ5/8”EZSVcasingplugwasset@8900’MDandthe9Ͳ5/8”productioncasingfaileda3500psi pressuretest.Theproductioncasingleakwasdeterminedtobesomewherebetween2200’–3750’MDwhich isanonͲhydrocarbonbearingnoflowtosurfacezone.Acasingrepairwasnoteconomicalsoa3Ͳ1/2”killstring wasinstalledandthewellenteredsuspendedstatuson02/26/2016. Objectives: PerformafullP&Aonthewellbyplacingcementtosurfaceinthe3Ͳ1/2”x9Ͳ5/8”annulusfrom4000’MDwith cementfrom3500’2500’Ͳ4000’MDinthetubing.TheOAcasingshoewasalreadycementedbyatopjob pumpedthroughtheFOvalve@2437’MDandthelastMITͲOApassedto1300psi.Soafinalcementplugwill beplacedacrossallannulifromsurfaceto~500’MD.Excavateandcutcasings3’beloworiginaltundralevel andinstallmarkerplate. Procedure: AOGCCWitness:AllAOGCCwitnessedoperationsrequireaminimumof24ͲhournoticetoAOGCCinspectorsof thetimingoftheoperationsotheycanbeavailable. SL: 1. Driftto4500’MD. EL: 1. Set3Ͳ1/2”CIBP~4500’MD a. Donotsetinacollar. b. Perform1000psipressuretest–pressuretestisnotforintegrity,itstoensurehardbottomfor circulatingcement. 2. Punch3Ͳ1/2”killstringfrom3995’Ͳ4000’MD a. Movedepthasneededtoensurenotpunchingatcollar. Page 7 P&A Well:09Ͳ07A PTD:199Ͳ022 API:50Ͳ029Ͳ20223Ͳ01Ͳ00 b. Tieinto3Ͳ1/2”killstringtubingtalley–dated02/27/2016 c. PressureuponkillstringtoverifyTxIAcommunication. WellSupport: 1. Nippledownproductiontree,installdryholetreeforcementing. FB: 1. Confirmcirculationthroughtbgpunchholes. FBCement: 1. Pumpthefollowingdownthetubing,uptheIA.Maxpressurewhilepumping=2500psi. A. 5bblsMeOH B. 75bblshot(160degF)freshwater+surfactant C. 10bblsfreshwater D. 270279bbls(20bblsovercalculatedvolume)14Ͳ15.8ppgClassGcement E. 5bblsfreshwater F. Foamball G. 178bbls9.8ppgbrine H. 9bbls60/40forfreezeprotect. I. ConfirmcementatsurfaceinIA. a. Oncecleancementatsurface(shouldtake~280bblstotalvolumetocirculatecement tosurfaceinIA)closechokeandpressureuptubingto2000psiinattempttosqueeze offPCleaktomitigatecementfallbackinIA. i. Squeezeuntilpressurefalloffisnomorethan50Ͳ100psiin10 minutesoruntilthe9.8ppgbrineand60/40volumesoutlined abovehavebeenreached. J. Closechokeleaving0psionIAandtrappressureontubingtoaccountforhydrostatic difference(~1200psi). K. CementpluginIAwillbefromtubingpunchtosurface L. Cementplugintubingwillbefrom3500’2500’MDtotubingpunch@4000’MD. DHD: 1. WOC~3days.StrapIATOCfortocheckforanyfallback. SL: 1. DrifttoTOC~3500’2500’MD. EL: 1. Perforate3Ͳ1/2”tubingand9Ͳ5/8”casingat495Ͳ500’MDw/1.56”MilleniumHMX. A. Perforate3Ͳ1/2”tubingand9Ͳ5/8”casingfrom495’Ͳ500’MDtoestablishcirculationpointfor cementing. B. Apply1000psito3Ͳ1/2”priortoperforating,recordbefore/afterpressures C. Noteanypressurechanges FB: 1. Confirmcirculationthroughperforationholes. Displacement in 3.5" kill string with ID = 2.98" ID to 2500' MD = 0.0086 * 2500 = 21.6 bbls - mgr Do not over displace cement. Assure minimum of 100' of cement in tubing above surface casing shoe. TOC ~2640' MD minimum. - mgr P&A Well:09Ͳ07A PTD:199Ͳ022 API:50Ͳ029Ͳ20223Ͳ01Ͳ00 CT:ContingentstepiffullboreisunabletogetcirculationtotheOAduetoarcticpack. 1. Warmthewellbycirculatingdowncoiltubingtakingreturnsfromcoiltubingbacksidewithhot seawatertothawthe9Ͳ5/8”x13Ͳ3/8”annulus. 2. PumpthefollowingdownthecoiltubingtakingreturnsfromtheOAtoflushthearcticpackoutofthe 9Ͳ5/8”x13Ͳ3/8”annulus A. 5bblsMeOH B. 200bbls160Fdiesel C. C.Allowdieseltosoakasneededtobreakuparcticpack. FB: 1. Circulatethefollowingdownthetubingandupthe9Ͳ5/8”x13Ͳ3/8”annulustoprepforcement. A. 5bblsMeOH B. 25bblshotdiesel(pumphotaspossible,whilestillensuring<100Fgoingtoreturntanks) C. 50bblshot(160degF)freshwater+surfactant D. 60bblsof9.8brine(80Ͳ100degF) 2. Circulatethefollowingdownthetubingtocementthetubingand9Ͳ5/8”x13Ͳ3/8”annulusfrom surfaceto500'MD A. 5bblsMeOH B. 10bblsfreshwater C. 50bbls(16bblsovercalculatedvolume)14Ͳ15.8ppgClassGcementoruntiluncontaminated cementisseenatsurface. D. Maxpressurewhilepumping1500psi. E. Topofcementwillbeatsurfaceinthetubingand9Ͳ5/8”x13Ͳ3/8”annulus.Confirmcementat surfaceinOA. DHD: 1. AssistfullborewithcementjobandpumpN2acrossthewellheadtoremoveexcesscementfrom valves. 2. Bleedallwellheadpressuresto0psi. 3. Monitorwellheadpressures24hoursafterpressureswerebledto0psi. SpecialProjects:Photodocumentallsteps. 1. Excavateandinstallshoringbox. 2. Cutoffallcasingsandwellhead3’beloworiginaltundralevel. 3. AOGCCwitnessofcutͲoffcasingsbeforeanytopjobcommences. 4. Topjobofcementvoidsinallannuliasneeded. 5. Beadweldmarkercaponoutermostcasingstring. 6. AOGCCwitnessofinstalledmarkercapbeforebackfilling. 7. Removeshoringboxandbackfill. Hilcorp North Slope, LLC PTD # 199-022 Well: PBU 09-07A API # 50-029-20223-01-00 P&A Well:09Ͳ07A PTD:199Ͳ022 API:50Ͳ029Ͳ20223Ͳ01Ͳ00 Figure1:CurrentWBS P&A Well:09-07A PTD:199-022 API:50-029-20223-01-00 Figure 1: Current WBS P&A Well:09Ͳ07A PTD:199Ͳ022 API:50Ͳ029Ͳ20223Ͳ01Ͳ00 Figure2:ProposedP&AWBS P&A Well:09-07A PTD:199-022 API:50-029-20223-01-00 Well Name:09-07A Permit to Drill:1990220 Current Status:Suspended API Number:50-029-20223-01 Estimated Start Date:2/7/2024 Estimated Duration:14 days Regulatory Contact:Carrie Janowski First Call Engineer:Andy Ogg 307-399-3816 Second Call Engineer:Brodie Wages 713-380-9836 Current Bottom Hole Pressure:Perfs cemented, hydrostatic at EZSV (8900’ MD, 8386’ TVD)= 3531 psi Max. Anticipated Surface Pressure:2500 psi Max treating pressure Last SI WHP:0psi Min ID:2.80”, 3-3/16 liner @ 9079’’ MD Max Angle:101 deg @ 10120’ MD Well History: Well 09-07 was originally drilled in 1976. It was sidetracked to 09-07A in 1999 and was a 100% on-time producer through 2009 until the oil production declined and the well was no longer competitive. A RWO was planned to remove damaged liner and abandon the lower perfs (A-bore). After abandoning the lower perfs, new perfs were going to be added in the 9-5/8” intermediate casing (parent-bore) to provide access to MI benefit. In December of 2015 service Coil Tubing cemented the A-bore perfs up to 9120’ CTMD and a subsequent MIT-T passed to 3,638 psi. The damaged liner was cut @ 9105’ CTMD and the 5-1/2” production tubing was cut @ 8920’ MD. A RWO was attempted in February of 2016 but after the 5-1/2”production tubing was pulled a 9-5/8” EZSV casing plug was set @ 8900’ MD and the 9-5/8” production casing failed a 3500 psi pressure test. The production casing leak was determined to be somewhere between 2200’ – 3750’ MD which is a non-hydrocarbon bearing no flow to surface zone. A casing repair was not economical so a 3-1/2” kill string was installed and the well entered suspended status on 02/26/2016. Objectives: Perform a full P&A on the well by placing cement to surface in the 3-1/2” x 9-5/8” annulus from 4000’ MD with cement from 3500’-4000’ MD in the tubing. The OA casing shoe was already cemented by a top job pumped through the FO valve @ 2437’ MD and the last MIT-OA passed to 1300 psi. So a final cement plug will be placed across all annuli from surface to ~500’ MD. Excavate and cut casings 3’ below original tundra level and install marker plate. Procedure: 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. SL: 1. Drift to 4500’ MD. EL: 1. Set 3-1/2” CIBP ~4500’ MD a. Do not set in a collar. b. Perform 1000 psi pressure test – pressure test is not for integrity, its to ensure hard bottom for circulating cement. 2. Punch 3-1/2” kill string from 3995’-4000’ MD a. Move depth as needed to ensure not punching at collar. Superceded on page 7 Page 2 P&A Well:09-07A PTD:199-022 API:50-029-20223-01-00 b. Tie into 3-1/2” kill string tubing talley – dated 02/27/2016 c. Pressure up on kill string to verify TxIA communication. Well Support : 1. Nipple down production tree, install dry hole tree for cementing. FB : 1. Confirm circulation through tbg punch holes. FB Cement: 1. Pump the following down the tubing, up the IA. Max pressure while pumping= 2500 psi. A. 5 bbls MeOH B. 75 bbls hot (160degF) fresh water + surfactant C. 10 bbls fresh water D. 270 bbls (20 bbls over calculated volume) 14-15.8 ppg Class G cement E. 5 bbls fresh water F. Foam ball G. 17 bbls 9.8 ppg brine H. 9 bbls 60/40 for freeze protect. I. Confirm cement at surface in IA. a. Once clean cement at surface (should take ~280 bbls total volume to circulate cement to surface in IA) close choke and pressure up tubing to 2000 psi in attempt to squeeze off PC leak to mitigate cement fallback in IA. i. Squeeze until pressure falloff is no more than 50-100 psi in 10 minutes or until the 9.8 ppg brine and 60/40 volumes outlined above have been reached. J. Close choke leaving 0 psi on IA and trap pressure on tubing to account for hydrostatic difference (~1200 psi). K. Cement plug in IA will be from tubing punch to surface L. Cement plug in tubing will be from 3500’ MD to tubing punch @ 4000’ MD. DHD : 1. WOC ~3 days. Strap IA TOC for to check for any fallback. SL: 1. Drift to TOC ~3500’ MD. EL: 1. Perforate 3-1/2” tubing and 9-5/8” casing at 495-500’ MD w/ 1.56” Millenium HMX. A. Perforate 3-1/2” tubing and 9-5/8” casing from 495’-500’ MD to establish circulation point for cementing. B. Apply 1000 psi to 3-1/2” prior to perforating, record before/after pressures C. Note any pressure changes FB : 1. Confirm circulation through perforation holes. Superceded P&A Well:09-07A PTD:199-022 API:50-029-20223-01-00 CT:Contingent step if fullbore is unable to get circulation to the OA due to arctic pack. 1. Warm the well by circulating down coil tubing taking returns from coil tubing backside with hot seawater to thaw the 9-5/8” x 13-3/8” annulus. 2. Pump the following down the coil tubing taking returns from the OA to flush the arctic pack out of the 9-5/8”x13-3/8” annulus A. 5 bbls MeOH B. 200 bbls 160 F diesel C. C. Allow diesel to soak as needed to break up arctic pack. FB : 1. Circulate the following down the tubing and up the 9-5/8”x 13-3/8” annulus to prep for cement. A. 5 bbls MeOH B. 25 bbls hot diesel (pump hot as possible, while still ensuring <100F going to return tanks) C. 50 bbls hot (160degF) fresh water + surfactant D. 60 bbls of 9.8 brine (80-100 degF) 2. Circulate the following down the tubing to cement the tubing and 9-5/8”x 13-3/8” annulus from surface to 500' MD A. 5 bbls MeOH B. 10 bbls fresh water C. 50 bbls (16 bbls over calculated volume) 14- 15.8 ppg Class G cement or until uncontaminated cement is seen at surface. D. Max pressure while pumping 1500 psi. E. Top of cement will be at surface in the tubing and 9-5/8”x13-3/8” annulus. Confirm cement at surface in OA. DHD: 1. Assist fullbore with cement job and pump N2 across the wellhead to remove excess cement from valves. 2. Bleed all wellhead pressures to 0 psi. 3. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. Special Projects: Photo document all steps. 1. Excavate and install shoring box. 2. Cut off all casings and wellhead 3’ below original tundra level. 3. AOGCC witness of cut-off casings before any top job commences. 4. Top job of cement voids in all annuli as needed. 5. Bead weld marker cap on outermost casing string. 6.AOGCC witness of installed marker cap before backfilling. 7.Remove shoring box and backfill. Hilcorp North Slope, LLC PTD # 199-022 Well: PBU 09-07A API # 50-029-20223-01-00 Superceded P&A Well:09-07A PTD:199-022 API:50-029-20223-01-00 Figure 2: Proposed P&A WBS ABANDONED Superceded You don't often get email from andrew.ogg@hilcorp.com. Learn why this is important From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240229 1438 Reservoir Plug Assurance Final P&A PTD 199-022 PBU 09-07A Abandonment questions Date:Friday, March 1, 2024 3:00:36 PM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Thursday, February 29, 2024 2:38 PM To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andrew, Send me the revised procedure and schematic and I will append it to the existing sundry. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Andrew Ogg <Andrew.Ogg@hilcorp.com> Sent: Wednesday, February 28, 2024 6:31 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Hey Mel, Yes, we can do that. During the IA cement job, we will add cement volume and reduce the displacement volume to leave the cement top in the 3-1/2” @ 2500’. Here is an updated schematic, let me know if this works for you. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, February 28, 2024 3:52 PM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from andrew.ogg@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andrew, Thanks for your response. AOGCC can approve the existing cement plugs across all annuli at the confining zones above the Prudhoe Bay oil pool. Regarding the surface casing shoe, AOGCC would like to see cement across all annuli at that shoe. This is a place in the wellbore with a recorded formation pressure test. With all annuli cemented at the surface casing shoe, a cemented barrier is in place at the shoe, that should endure the test of time and the corrosion that is expected to occur in the steal tubulars and limit possible pressurized fluid from migrating below. Can you place a cement plug of 200’ (100’ above and 100’ below) across the SC shoe withing the 3-1/2”? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Andrew Ogg <Andrew.Ogg@hilcorp.com> Sent: Wednesday, February 28, 2024 1:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: RE: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Hello Mel, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Answers in red below. Let me know if you have any more questions. Thanks, Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, February 27, 2024 12:06 PM To: Andrew Ogg <Andrew.Ogg@hilcorp.com> Cc: Carrie Janowski <Carrie.Janowski@hilcorp.com> Subject: [EXTERNAL] PTD 199-022 PBU 09-07A Abandonment questions Andy, In the well history, it is mentioned that perforations were to be added to access MI benefit. Where were those perfs to be added? They were planned to be added in the parent bore from 9285’ – 9295’ MD Was cement tagged and pressure tested inside the 3-1/16” liner at 9120’ MD. Yes, after service coil down squeezed the liner, they performed a coil flag log for depth control for the tbg cut and logged TOC @ 9117 MD. They also did a MIT-T that passed to 3,541 psi. What MD is the base of the upper confining zone for the PB oil pool on PBU 09-07 (PTD 176-058)? 9224’ MD Why not comply to 20 AAC 25.112 (c)(2)(C) and place cement on the EZSV at 8900’? Since we have the required cement over the top of the DPZ @ 9224’ MD and there is no other DPZ’s between the TOC @ 9120’ & the EZSV, I did not interpret this rule to apply to the production tubing stub. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS V ED 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change App Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number. 199-022 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 1 6. API Number 50-029-20223-01-00 7. Property Designation (Lease Number): ADL 028327 & 028324 8. Well Name and Number: PBU 09-07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10934 feet Plugs measured 8900, 9120 feet true vertical 9009 feet Junk measured 9006 - 9120, 9719 feet Effective Depth: measured 8900 feet Packer measured 8958 feet true vertical 8386 feet Packer true verfical 8440 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 33-108 33 - 10B 1530 520 Surface 2740 13-3/8" 32-2772 32-2772 4930 2670 Intermediate 9219 9-5/8" 29-9248 29-8708 8150 / 6870 5080 / 4760 Production Liner 1742 3-3/16" 9105-10847 8576-9002 Perforation Depth: Measured depth: None feet True vertical depth: feel Tubing (size, grade, measured and true vertical depth) 3-1 /2" 9.3# L-80 / 5-1/2" 17# 13Cr80 27 - 8867 / 8920 - 9061 27 - 8356 18405 - 8535 Packers and SSSV (type, measured and 5-1/2" TIW HBBP Packer 8958 8440 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments: (required per 20 nAC 25.070.25071, a 252821) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 16. Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 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: WA Authonzed Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: alist A I Contact Email: Travis.Montgomeryabp.com Authorized Signature: Dater 50h 9 Contact Phone'. +1 907 564 4127 Form 10-404 Revised 0412017 --fg�f % ^^�" / RBDMS E' AUG 0 12019 Submit Original Only T/I/O = LOTO/0/0. Temp = SI. Pre AOGCC SU well inspection. No AL or flowline. Dry hole tree. Wellhead, wellhouse and cellar are clean and dry. Surface area around well is clean, dry and free of debris. Well ID sign attached to wellhouse. 6/29/2019 SV = C. MV = LOTO. IA, OA = OTG. 21:15 T/I/O = LOTO/0/0. Temp = SI. AOGCC SU well inspection. (Witnessed by Bob Noble). No AL. 7/6/2019 SV = C. MV = LOTO. IA, OA = OTG. 10:30 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Initial Inspection Well Name: 09-07A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1990220 API Number: 50-029-20223-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: W+V2 45. Surface Location: Section: 2 Twsp: 10N Range: 15E Nearest active pad or road: DS -09 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Pad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None Access road condition: Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition:EY Cellar description, condition, fluids: t^y Rat Hale: Al1.A. Wellhouse or protective tia Well identification sign: Tubing Pressure (or casino Annulus pressures: Wellhead Photos taken (# Operator Rep (name and AOGCC Inspector: Inspection Date: Time of arrival: Site access method Josh Prowant AOGCC Notice Date: Time of Departure: WELL: 09-07A OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50-029-20223-01-00 SUR. LOCATION SE 1/4, Sec. 02. T10N, R15E DRILLING PERMIT 199-022 • � F NJ $} I Y V J EYE t � r WELL: 09-07A OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50-029-20223-01-00 SUR. LOCATION SE 1/4, Sec. 02. T10N, R15E DRILLING PERMIT 199-022 • � F NJ $} I Y V J EYE i 4. 04-0k��'-%- 94-27P81 ---- 04-4� 41,gP82 (r 04-4A �. 04-37 n 0429AL1 `, 0439 0440 -- y �L_ 0441A 04-41AP --- 04-29ALlPB1 r OBPHT- DS4 - 09-40 _ --_ 04 29A04-11 _ ~l 04-42 �1 _I_� ..� 0-i.4 _ _ 0-I C 04-29 to ()4, r�.i2 or i C , 04-ae611 — µ 1 ,t04-1 0401 J _- 04-09PBi r' - C 0448 [109-34 09-41 09-43 C 0431 X35 I r 09-15A .' 04301 04-32A _ 104_ - 32 ` 04-01A F- - 0430PB1 _0401 - 09-3AAP81 „1 09-24A ' 09-08 04-15 09- 62 04 04u04 -04A 40, 04-4L' .�-83a05B l't 09-35A - 091 J 09.3:✓1 ` X09-4�r j1— �09-30 0342AP81 10332 �� . 0344 0443 i 0305 V04- 09,44 '09=3iC- 09-15 09 �'-09-14 09-07 C 09.29A ..7A 033881- 3BA 09-28A 09-31 IAF 03 C - 05-28 .L to-�S I.! 0338„09-45 '- �, , 0347 L 09-29 2,.. I r 033- L - 09-37 0338 '. Q9 -U8 70317 1 0304114 T 0310 C r 09-04A T 09-13 09-49 Ir03-28 ` 1M t t�. ;: 09-49A -� 1 _ 4- 09-31 C �t 1 .r Q9-27 - s 09-50 C 03-OJA—03-10A 0&28 03-338 - L 03-01 I = 03-10 09-03 LJ 09-20= 09-02 C 03-33A E 0302A 09)2APB1 I 03-32 03-29 03-3 { 7. 12 11 49 .r 1 C 03.93 C 03-38 L 09-51 � 413116 09-03A rs�.r 0-03 mpp= rw WELLLHEAD= FMC ACTUATOR= AXELSON 0103. ELEV = 54' REF ELEV = 54• BF. ELEV= 21.75' KOP = 316T Max Angle = 101' 0 10120' Dain MD= 94ST Dalin TVD= 88001813 SUSPENDED 09-07A I 10 -ma i ", rc , ry , u= lc.. f 11 [/4Y Minimum ID = 2.80" @ 9079' 3-3/16" LINER 3-1/2' TBG. 93#. L-80 TCL .0087 bof. D = 2.992' — I RCT CUT TBG (12/17/15) I l6-1/2' TBG PUNCH (12/27/15) I 1 9053' 9-5/8' CSG, 47#, 14L80, D = 8.681' 9658• PERFORATION SLANAARY REF LOG (iE.SISTNBY ON 04/23/99 ANGLE AT TOP PERF: 65 @ 9504' Note: Refer to Production DB for historical perf data SIZE SPF WERVAL OpNSgz GATE 2- 4 9504 - 9509 S 1222/15 2" 4 9554-9564 S 12rM15 2- 4 9590- 9600 S 1222115 2• 4 9654- 9674 S 1222/15 2- 4 9684 - 9704 S 1222/15 2- 4 9788-9798 S 1222115 2' 6 9910-10135 S 1222/15 2' 6 10805 - 10840 S 1222/15 3-3116- LNR 6.29, L-80, .0087 bof. ID = 2.786' TD —L '093W SAFETY NOTES: CAUTION: 112S OVER 300 ppm. WELL ANGLE> 70° @ 9478. —CHROM E TBG"' LE 9696• Ha -1/2• DEPLOY SLV, D=7 9025 5-12•HESXNIP, D=4.56• BEHIND __ _ ____ _ CT LNR 9053• 5-1/2-ALEG, D=4.892• ELMD TT NOT LOGGED MILOUT WINDOW (09-07A) 9248' - 9257' DATE REV BY COMMENTS DATE REV BY COMMENTS 10!76 ORIGINAL COMPLETION 12/3W15 STF/JMD TBG CUT &PUNCH(1227/15) 11118M LASTWORKOVER 0303/16 JMD DRLGHOCORRECTDNS W 27199 SIDETRACKED (01147A) 0323/16 JMD EDITS 0228116 P,272 OPS SUSPENDED 0324/16 SWJMD FINAL ODE APPROVAL 10/13/08 PJP/PJC POSSIBLE LNR DMG 11A6A6 0729/19 JNJJMD ADDED OKB, REF, & BF ELEV 12x"15 TTR/JMD JET CUT LNR/CMTSQZ(1222-24/15) PRUDHOE BAY UNIT WELL- 09-07A PERMIT No: 1990220 API No: 50029-20223-01 SEC 2, T10N, R15E,1933' FSL & 49' FEL BP Exploration (Alaska) Suspended Well Inspection Review Report InspectNo: susRCN190707182734 Date Inspected: 7/6/2019 Inspector: Bob Noble Well Name: PRUDHOE BAY UNIT 09-07A Permit Number: 1990220 Suspension Approval: Sundry # 316-161 Suspension Date: 2/29/2016 Location Verified? O If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: IA: OA: Type of Inspection: Subsequent Date AOGCC Notified: 7/5/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? Photos Taken? ' Fluid in Cellar? ❑ 0 BPV Installed? ❑ 0 VR Plug(s) Installed? ❑ Wellhead Condition Well house to protect the wellhead. Flowline and AL lines had been removed and blinded. SSV is shut. Wellhead looks in good condition. Condition of Cellar Good clean gravel. Surrounding Surface Condition Clean gravel. Comments Location is verified with a pad map. Supervisor Comments Photos (2) attached "j Gllw�lq Friday, August 16, 2019 v M N _ Y �q1 � {R I` M r - , y 4w�s A.'. 0 N STATE OF ALASKA 111,LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspended Well Report H 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-022 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20223-01-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-07A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10934 feet Plugs measured feet RECEIVED true vertical 9009 feet Junkmfeet easured Effective Depth: measured 9120 feet Packer measured 8961 feet JUN 0 9 2016 true vertical_ 8589 feet Packer true vertical 8442 feet .AOGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20"94#1-1-40 35-111 35-111 1530 520 Surface 2740 13-3/8"72#N-80 35-2775 35-2775 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9504-9509 feet feet 9554-9564 feet 9590-9600 feet 9654-9674 feet 9684-9704 feet 9788-9798 feet 9910-10135 feet 10805-10835 feet True vertical depth: 8876-8878 feet feet 8892-8896 feet 8904-8908 feet 8929-8937 feet 8941-8948 feet 8977-8980 feet 9011-9007 feet 8999-9001 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"TIW HBBP Packer 8961 8442 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): (� Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 '7 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2875 3884 1973 220 Subsequent to operation: Susoended Well 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development el?! Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP H SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-161 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A'% Phone +1 907 564 4424 Date 6/9/16 Form 10-404 Revised 5/2015 TL q/Z/lL L JUN 0 2016 RBDMS 1 //� Submit Original Only • • w p N LO 'ct LO LOCND 0 0 M M LLO N- �L() cF O 3 Ln 0 N— CO A— N 1"- ca - cOCflp � N- 1.0 CO N CO N N M CO I,- tocOOLc) OCo ►nM N N I- CO CO CA N CO CO 1 1 1 1 1 III II H Ln LO N fO ONO CO N O O O CO M CO Ln LO M M Tr N I� CO CO CO Ln 00 f� 00 O M t co N, CO CO CO CV CO O = N N CO a) a) N OO O) v o CO Q O L) LANLL� CMOOOON CO M M M N CO 0) M M CO _ o M_ " N 0 LC) p 0 0" p co CO CA 00 00 p O 00 �) � ZO � J 'j0Oo0U N *k02cc' U4 � N ' N-N- c0 •Cp CO N- C.) O M a0 -O0 N N CV N MLO.JI Ln M j� O O) Cr) M tC") t Ln N N NV Cr)CO M co J C N CD O N- N- O N. N CO W W W I— =o U W W U a u_ ccc c o c Z Z Z Z c W W W W W pp pp m 0 HHZZD � al 7 a N L d U 6. 41 C Y L f d E. 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(„10,., No t i , a 1 _ 1111 1 1 tr p y iiii, ,.„ .. . ,„.. : • A.. ?;ti (.... ,..,......„.„.,,. .L.,,,„:„,..„,..,.,,. ...... . aa .w� I Vis, • • o >- CC 0 i Q 2 O W ~ < u o rno 14- o U a 0` Q. a) >. a) -o Q U a) 0_ 0 E -o L ^a) LL W I- < CD 0 o N -Q Co I U Q • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 05/12/16 Inspector: Jeff Jones Operator: BP Exploration(Alaska) Well Name: PBU 09-07A Oper.Rep: Beau Obrigewitch PTD No.: 199-022 Oper.Phone: 659-5766 Location Verified? Yes Oper. Email: Beau.Obriciewitchbp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 02/29/16 Date AOGCC Notified: 05/10/16 Sundry No.: 316-161 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Well head is clean and in good condition with no visible leaks or exceptions.The tree valves are operable and working gauges for the tubing, IA&OA are in place. Condition of Surrounding Surface Good condition. Lots of water from melting snow&ice on pad.There is a well house over the well with a well sign and Mr.Obrigewitch Location: provided an anal map for identification.The plywood covering the opening for the flowline(removed)has fallen down and the cellar is full of snow&ice. Follow Up Actions Needed: Repair plywood covering hole in back of well house. SCANNEtY SEP 2 3 2016 Comments: Operator Rep.states and well schematic shows that the perforations and HRZ are isolated with cement. Attachments: Photos(2) REVIEWED BY: Insp.Supry Comm PLB 12/2015 2016-0512_Suspend_PBU_09-07Ajj.xlsx • • F t { -4115 O f I O i Q\ O I CA a� fl.Y s err MIR te., ° � vr o 0 v a U •Ng CA c10 p N 4Q N V) * _ t STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! WELL COMPLETION OR RECOMPLETION REPO AND LOG 1 a. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended 10 - 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ ❑ WINJ 0 WAG ❑ WDSPL ❑ No.of Completions: Zero - Service 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 2/26/2016 199-022 ' 315-710/316-161 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 4/11/1999 50-029-20223-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 4/23/1999 PBU 09-07A • Surface: 1933'FSL,49'FEL,Sec.02,T1ON,R15E,UM - 9 Ref Elevations KB 54 17. Field/Pool(s): Top of Productive Interval: 3917'FSL,1544'FEL,Sec.02,T1ON,R15E,UM GL 21 BF 21.75 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 83'FSL,1039'FEL,Sec.35,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 8900'/8386' ADL 028327&028324 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 718315 . y- 5943399 - Zone - ASP 4 10934'/9009' _ 74-017 TPI: x- 716762 y- 5945340 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 717224 y- 5946800 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No WI 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9248'/8708' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary RES,GR,CCL,Temp,MWD . ^"' I tis MAR 24 2018 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING Rr Df AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 35' 111' 35' 111' 30" 300 sx Arctic Set 13-3/8" 72# N-80 35' 2775' 35' 2775' 17-1/2" 6700 sx Arctic Set 47# 500-95/MN-80 9-5/8" /RS-95 32' 9248' 32' 8708' 12-1/4" 1000 sx Class'G',300 sx Arctic Set 3-3/16" 6.2# L-80 9105' 10847' 8576' 9002' 4-1/8" 16 Bbls 15.6 ppg LARC 24. Open to production or injection? Yes 0 No IZI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 3-1/2",9.3#,L-80; 8867' 5-1/2",17#,13Cr80 8920'-9063' 8961'/8442' JUN ){�{ 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Sr ANN 2 4 LU 16Was hydraulic fracturing used during completion? Yes LI No I11 M !! Per 20 AAC 25.283(i)(2)attach electronic and printed - information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �..► Flow Tubing Casing Press: Calculated Oil-Bbl: - Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate —♦ Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only v'rL 5/3/ 1‘... j/ 4 RBDMS t--t, MAR 2 5 2016 r _.`/./c 28. CORE DATA • Conventional Core(s) Yes ❑ No II - • Sidewall Cores Yes ❑ No 0 ' If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No 0 - Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9222' 8684' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 9222' 8684' Zone 1B 9791' 8978' Zone 1A 9963' 9022' Formation at total depth: 31. List of Attachments: Summary of Pre-Workover Work,Summary of Daily Workover Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mclaughlin,Sean M Email: Sean.McLaughlin@bp.com Printed Name: Joe Lastufk JA1 Title: Drilling Technologist Signature: \ ' Phone: +1 907 564 4091 Date: 5/24/ 11 ��....••rrr INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • WELL NAME: 09-07A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9120' 12.3 Bbls Class 'G' 9105' Cut Liner 9006' Fish: 3-1/2", 8.81#x 3-3/16" 6.2#, L-80 8930' - 8932' Tubing Punch 8920' Cut & Pull Tubing 8900' Set EZSV • . 09-07A, Well History (Pre-Rig Workover) DATE I , ' . MARY T/I/O=SSV/400/320, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port(1100 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, 1 is stuck, all the rest moved freely (2.5''). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min ' (PASS). Bled void to 0 psi. **Stuck LDS is in the 11:00 position***. PPPOT-IC: Stung into test port (250 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely(2.5"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 12/20/2015 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. T/I/O= 220/390/314 Temp= S/I (RWO EXPENSE) Pumped 16 bbls diesel down TBG in attempt to 12/20/2015 achieve 3500 psi. Temp= S/I MIT-T to 3500 psi ***FAILED*** MIT-OA to 1200 psi ***PASSED*** (RWO EXPENSE) Pumped 30 bbls diesel down TBG, Unable to reach test pressure, Established LLR of 5 bpm @ 528 psi with 20 bbls diesel, MIT-OA- Pumped 22 bbls 35*crude down OA to reach test pressure of 1327 psi, OA lost 17 psi in 1st 15 min and 10 psi in 2nd 15 min for total loss of 27 psi in 30 min test, Bleed OAP, Bleed back—2 bbls, FWHP= 216/305/293 AFE sign and tags hung on 12/21/2015 well, Valve position @ departure-WV, SV, SSV= Closed MV= Open IA& OA= OTG. CTU#3 1.75" Coil 31.6 bbl CV Job Scope: Cement P&A pre RWO. MIRU. Perform Weekly BOP test. MU SLB 2.50" BDJSN. Load well with 360 bbl's of 1% KCL w/safe lube and 210 bbls diesel while rih. At depth, park CT at 9120' Elec 9108' Mech. Injection rate at 1 bpm 268 psi WHP. Static baseline pressure 188 psi. (no pumping). Cementer batch up cement 15,8 ppg Class G cement w/5 lbs/bbl aggregate 3 bbls NEET, 7 bbls aggergate, 3.4 bbls NEET. Squeezed 12.3 bbls cement down in liner, walked squeeze pressure up to 2320 psi. PUH to 9100' FT. begin reverse clean out down to 12/22/2015 9120' CTM of 1.1 bbls cement. PUH in 5-1/2 TBG. Cement top at 9120'-10737' CTM. CTU #3 1.75" Coil 31.6 bbl CV Job Scope: Cement P&A pre RWO. Park CT at 8847' CTM wait for a couple hours for cement to start thickning up, WHP 1859 psi. POOH 80 fpm fill ct displacement .2 bpm with diesel, maintaining WHP. At surface monitor WHP 1830 psi. RIH with WFD MHA& PDS gamma/CCL in a 2 3/8" carrier and 2 75" nozzle drift, (OAL = 13.67'). Tag TOC at 9120' ctmd, log to 8800.7' &flag pipe, (RED). 8800.7 minus MHA& PDS carrier of 13.67' = (8787' EOP flag). Pull to 8700' and perform 5 minute pressure test at 3462 psi prior to pulling out of the hole. Got good data - 6' FT correction. 1st CCL spike off bottom = 9119,98' + 4.10'-6.50' correction = 9117.58' CTM. Corrected EOP depth at flag 8784.61' CTM. MIT-T PASSED to 3638 psi . Pressured tubing to 3638 psi with 2.2 bbl's of 60/40 MeoH. MIT-T lost 52 psi in 1st 15 minutes, and 28 psi in 2nd 15 minutes, held for additonal 15 min lost 17 psi a total of 97 psi during 45 minute test. Bled tubing to 350 psi. 12/23/2015 Final WHPs =468/393/249. CTU #3 1.75" Coil 31.6 bbl CV Job Scope: Cement P&A pre RWO. MU WFD CTC MHA DISCO 3/4" ball 2.375", KNUCKLE 2.1, XOVER 2", SLB 2.50" JET CUTTER. RIH to 9105' and shoot Jet Cutter with E-Fire pump sequence, good indication on shot detection box. POOH. MU WFD fishing BHA w/4.5" GS spear. RIH and tag liner top at 9006'. Appears the liner has been pushed down hole. Stack down 7k with no overpulls multiple times. At surface, closed swab, no liner at surface. 12/24/2015 RD. (HES TUBING CUT). T/I/OA= 0/350/250. RUN 2"X 2' TUBING PUNCH CONTAINING 5/8" 12/26/2015 CHARGES. CORRELATE TO TUBING DETAIL RECORD DATED 11/16/1994. • • 09-07A, Well History (Pre-Rig Workover) (HES TBG CUT). INITIAL T/I/0 = 350/0/250. CONTINUE RIH WITH 2' x 2" TUBING PUNCH AT 8930'-8932' -CCL TO TOP SHOT AT 3.8' - CCL STOP AT 8926.2'.CORRELATED TO TUBING DETAIL RECORD DATED 11/16/1994 POSITIVE INDICATION OF SHOT ON SHOOTING PANEL. POSITIVE INDICATION OF TxIA COMMUNICATION. RIH WITH RCT PULL INTO POSITION WITH CUTTER. SET EMA ARMS -VERIFY SET WITH 200 LB OVERPULL. FIRE RCT AT 8920.7' - CCL TO CUT DEPTH 10.7' -CCL STOP DEPTH 8910.0'. CORRELATED TO TUBING DETAIL 12/2.7/2015 RECORD DATED 11/16/1994. POSITIVE INDICATION OF CUT. FINIAL T/I/0 = 650/650/250. T/I/0=631/639/221. (Post RWO Circ-out/CMIT T x IA(FAIL)) Spear into tbg w/5 bbls neat meth followed by 719 bbls 1% KCL to circ-out well. Pump 160 bbls diesel heated to 80-*down tbg. Let U- tube from tbg to IA for 1 hr. FP serface lines with 5 bbls neat. Pumped 13 bbls DSL down TBG to obtain test pressure 1st 15 min = TBG lost 119 psi/ IA lost 120 psi 2nd 15 min = TBG lost 99 psi/ 100 psi Total test= TBG lost 218 psi/ IA lost 220 psi Bled TBG & IA down Bled 13 bbls DSL SV, SSV, WV= C MV= 0 CVs= OTG. DSO notified of well status upon LRS departure. AFE 12/29/2015 sign hung Caution tags hung. FWHP's= 320/318/24 T/I/O = 223/225/230. Temp= SI. CMIT-TxIA to 3750 psi (pre rig). AL spool dropped. Hard line 12/30/2015 rigged up to tree cap & IA valve to 09-43. Tbg & IA FL @ surface. Started pumping down Tbg/IA. T/I/O = 223/225/230. Temp= SI. CMIT-TxIA*FAILED*to3750 psi (pre rig). AL spool dropped. Tbg & IA FL @ surface. Lateral SI behind wellhouse. Monitored S-riser& hardline pressure. Used 9.7 bbls of AMB DSL to pressure up Tbg/IA from 223/225 psi to 3752/3750. On the second test Tbg/IA lost 363/366 psi in the 1st 15 minutes &239/237 psi in the 2nd 15 minutes, for a total loss of 602/603 psi in 30 minutes. No change in S-riser or hardline pressure during test. Bled Tbg/IA to 300/300 psi (8 bbls). Hung tags &AFE sign. Final WHP's = 300/300/260. SV, WV, SSV= Closed. MV= Open. 12/31/2015 IA& OA= OTG. NOVP. 03:00. T/I/O = 620/620/230. Temp = SI. Bleed TP & IAP & OAP to 0 psi (assist cameron). AL spool dropped. T& IA FLs @ surface. Bled TP & IAP to 0 psi in 10 min (2 bbls). Monitor for 1 hr for BUR. TP increased 12 psi and IAP increased 16 psi. Bled TP & IAP to 0 psi in 10 seconds with no observable flow. Continue open bleed monitor for 1 hr with no observable flow. WIC and WIE approval to use fluid column as KWF. OA FL near surface. Bleed OAP to slop trailer from 230 psi to 170 psi in 40 min (gas &fluid mix). ***WIE (Ryan Hayes) verified hydrostatic calculations prior to starting job. Estimated BHP (2011 survey) is 3323 psi. Hydrostatic pressure of diesel x 1 % KCL in Tbg&IA is 3434 psi. Giving an overbalance of 111 psi. Final WHPs = 0/0/170. SV, WV, SSV= C. 12/31/2015 MV= 0. IA, OA= OTG. 18:00. T/I/O = 620/620/230, Temp: SI, Extract stuck LDS. DHD bled Tubing & IAP to 0 psi. Shut in bleed and monitored build up for 1 hour. Monitored for another hour with open bleed. No flow with 1 hour monitor. Stung into tubing test void, (0+ psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Held open bleed for LDS extraction. Removed stuck LDS. Tapped threads and installed new LDS assembly. Torqued LDS assembly to 350 ft/lbs. Ball check on test void alemite was not seating. Removed old alemite and installed new alemite test fitting. Pumped through void, good returns. Pressured test void to 5,000 psi for 15 minute PT. Lost 50 psi in 15 minutes. No leaks from LDS. 12/31/2015 (PASS). T/I/O = SSV/8/180 Temp = S/I. WHPs (pre RWO). No well house, flowline removed. SV, WV, SSV 1/4/2016 = C. MV= O. IA, OA= OTG. 16:15. T/I/O = 220/240/200. Set 6" CIW"J" BPV#401 @ 125", set good. Performed LTT on BPV 1/5/2016 (Passed). Bled TBG to 0 psi through I/A. Bled O/A to 18 psi. FWHP's = 0/0/18. T/I/O = TWC/10/90. Temp = SI. WHPs (pre RWO). No well house or flow line installed. OAP 1/6/2016 decreased 90 psi since 1/4/16. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 2200. T/I/0=BPV/0/35 Pre Parker 272, Removed 6" upper tree and R/U TEMP#78 as dryhole, R/U Temp 1/7/2016 #65 as IA piggyback, R/U temp#67 as OA Piggyback. FWP's BPV/0/5. T/I/0=BPV/0/31. Pre Parker 272. Pressure tested Dryhole tree to 5000 psi. Passed. Pressure tested 1/7/2016 IA/OA piggyback valves and IA Front VR plug to 3500 psi. Passed. Final WHP's BPV/0/31. • . 09-07A, Well History (Pre-Rig Workover) T/I/O = BPV/8/68. Temp = SI. Bleed WHPs to 0 psi (pre RIG). No AL, no flow line, no well house, No WV or SSV. BPV installed. IA FL @ surface. OA FL near surface. Bled IAP to bleed trailer from 8 psi to 0 psi in 10 min (all fluid). Bled OAP from 68 psi to 0 psi in 2.5 hours, (all gas). 1/9/2016 Monitored for 30 min, IAP and OAP unchanged. FWHPs= BPV/0/0. 23:59. T/I/O = BPV/VAC/65. Temp = SI. WHPs (pre RWO). No well house, scaffolding or flow line 2/4/2016 installed. SV, MV= ? (unable to reach). IA, OA= OTG. 1730. T/I/O = BPV/8/68. Temp = SI. Bleed WHPs to 0 psi (pre RIG). No AL, no flow line, no well house, dry hole tree installed. BPV installed. OA FL near surface. Bled OAP to bleed trailer from 65 psi to 0 psi in 1 hr , (all gas). Monitored for 1 hr, OAP increased 9 psi. Bled OAP to 0 psi. Final WHPs = 2/6/2016 BPV/0/0. SV, MV= (unable to reach). IA, OA= OTG. 14:00. T/I/O = BPV/0/21. Temp = SI. WHP's (Pre Rig). No AL, Flowline &Wellhouse. IAP unchanged, 2/7/2016 OAP increased 21 psi overnight. SV, MV= ? (Unable to reach). IA, OA= OTG. 11:30. • North America-ALASKA-BR'% Page 1 of 13 , = Page 2 of 13 / rF J, Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project.Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release.2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN @68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 20:00 5.00 RIGU P PRE RIG UP FLOOR EQUIPMENT -INSTALL MUD,CEMENT AND BLEEDER LINES HANG RIG TONGS,INSTALL OFFLINE MOUSE HOLE -CLEAR AND CLEAN FLOOR WHILE RIGGING UP PITS AND PIPE SHED INSTALL HCR'S AND MANUAL VALVES ON NEW STACK -LOAD PITS WITH 120°,8.5 PPG SEAWATER *HOLD PRE-SPUD WOOD'S CREW AND ANCHORAGE TEAM* *RIG ACCEPTED AT 20:00 HOURS* 20:00 - 21:30 1.50 RIGU P PRE RIG UP TO CIRCULATE OUT FREEZE PROTECT -RU TO CIRC DOWN TUBING AND IA -RU TO TAKE RETURNS THRU CHOKE TO TIGER TANK 21:30 - 22:00 0.50 RIGU P PRE HOLD H2S RIG EVACUATION DRILL WITH AND AAR NO SIGNIFICANT FINDINGS 22:00 - 23:30 1.50 WHSUR P DECOMP .RIG UP HYDRAULIC LUBRICATOR TEST LUBRICATOR TO 300 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH-PASS 23:30 - 00:00 0.50 WHSUR P DECOMP PULL 6-3/8"CIW#401"J"STYLE BACK PRESSURE VALVE -WELLBORE STATIC,STAND BACK LUBRICATOR I-CLOSE MASTER AND SWAB VALVES 2/21/2016 00:00 - 01:00 1.00 WHSUR P DECOMP CONTINUE RIG UP TO CIRCULATE OUT FREEZE PROTECT -RU TO CIRC DOWN TUBING AND IA. -RU TO TAKE RETURNS THRU CHOKE TO TIGER TANK. *HOLD PRE-SPUD BURLEY'S CREW* START MONITOR OF OA FOR WELLHEAD WORK AT MIDNIGHT-NO FLOW 01:00 - 02:00 1.00 WHSUR P DECOMP HOLD H2S RIG EVACUATION DRILL WITH AND AAR -DISCUSS HISTORIC H2S ON PAD AND WELL. 02:00 - 03:00 1.00 WHSUR P DECOMP PJSM TO CIRC OUT FREEZE PROTECT -HOLD PJSM WITH CREW,MUD ENGINEERS, TRUCK DRIVERS -DISCUSS PUMP PLAN AND LINE-UPS -PRESSURE TEST LINES FROM MUD PUMP TO WELLHEAD TO 300 PSI LOW,3500 PSI HIGH FOR 5 MINUTES WSL PERFORM PRESSURE CROSSCHECK CHECKLIST. WALK LINES AND BLOW DOWN TO VERIFY CLEAR. Printed 3/7/2016 9:06:05AM • North America ALA^c Operation Summary Repo' Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. LUWI.500292022300 Active datum:09-07B PLAN @68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 08:00 5.00 WHSUR P DECOMP CIRC OUT FREEZE PROTECT FROM TUBING AND IA -CIRC 100 BBLS 120°F SEAWATER DOWN IA -TAKE RETURNS FROM TUBING TO TIGER TANK STAGE UP TO 5 BPM.ICP=1575 PSI.FCP= 12100 PSI CIRC 100 BBLS NO-SULF PILL,600 BBL 120°F SEAWATER DOWN TUBING -TAKE RETURNS FROM IA TO TIGER TANK STAGE UP TO 4 BPM.ICP=2100 PSI.FCP= 2800 PSI -ALL DIESEL(160 BBLS),SEAWATER,AND NO-SULF PILL RETURNS TAKEN TO THE FLOW BACK TANK I-DISPLACE WELL TO CLEAN 8.5 PPG SEAWATER MANUAL STRAP TIGER TANK EVERY 100 BBL PUMPED TO VERIFY BBL IN BBL OUT 08:00 - 09:30 1.50 WHSUR P DECOMP BLOW DOWN SURFACE LINES TO FLOW BACK TANK,RIG DOWN LINES FROM TREE AND RIG 09:30 - 12:00 2.50 WHSUR P DECOMP HOLD PRE-JOB SAFETY MEETING FOR RIGGING UP LUBRICATOR -TEST TO 3500 PSI FOR 5 MINUTES SET TWC,TEST FROM BELOW TO 250 PSI LOW,1500 PSI HIGH-PASS(DID NOT ROLL PUMPS) -TEST FROM ABOVE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH-FAIL -FLUID LEAKING BY TWC 12:00 - 15:00 3.00 WHSUR N SFAL DECOMP UNABLE TO GET PASSING TEST OF TWC -PULL TWC,LAY DOWN,NO OBVIOUS ISSUES WITH PLUG -MAKE LUBRICATOR BACKUP WITH NEW TWC,TEST LUBRICATOR ON QUICK TEST SUB TO 3500 PSI FOR 5 MINUTES INSTALL TWC -TEST TWC FROM BELOW TO 250 PSI LOW, 1500 PSI HIGH FOR 5 MINUTES EACH-PASS DID NOT ROLL PUMPS) -TEST TWC FROM ABOVE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES EACH-PASS 15:00 - 17:00 2.00 WHSUR P DECOMP RIG DOWN LUBRICATOR,LAY DOWN TO PIPE SHED -CLEAR AND CLEAN FLOOR `ACCUMULATOR HYDRAULIC FLUID LEAK DURING OFFLINE PRESSURE TESTING OF BOP STACK,SEE 2016-IR-5199908. Printed 3/7/2016 9:06.05AM • North America-ALASKA-BP Page 4 of 13 Aeration Summary Report' Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 1 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN @68.15usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 21:00 4.00 WHSUR P DECOMP NIPPLE DOWN TREE AND ADAPTER FLANGE -FMC REPRESENTATIVE BLEED OFF CONTROL LINES AND CAP -PREP FOR NIPPLE DOWN OF TREE -BREAK BOLTS ON ADAPTER -VERIFY HANGER THREAD,CLEAN WELLHEAD,MAKE UP CROSSOVER WITH 7-1/2 TURNS,THREADS LOOK GOOD SIMOPS CHAMBER TEST ON ANNULAR PREVENTER, TOP PIPE RAMS AND BLIND RAMS -TEST ANNULAR PREVENTER ON STUMP WITH 7"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -SHELL TEST ON STUMP TO 250 PSI LOW, 5000 PSI HIGH FOR 5 MINUTES EACH 21:00 - 21:30 0.50 BOPSUR P DECOMP SERVICE RIG HOISTING EQUIPMENT. SERVICE TOP DRIVE,DRAWWORKS,IRON ROUGHNECK. 21:30 - 00:00 2.50 BOPSUR P DECOMP NIPPLE UP BOPE. I-NU 18"SPACER SPOOL AND 15'HIGH • PRESSURE RISER. -BREAK BOP STACK OFF TEST STUMP. CLEAN GASKET GROOVES AND INSTALL NEWAPI RINGS. -INSTALL DUTCH RISER NIPPLE. 2/22/2016 00:00 - 06:30 6.50 BOPSUR P DECOMP CONTINUE NU BOPE STACK,13-5/8"5K CAMERON -ANNULAR PREVENTER -7"FIXED BORE UPPER RAM -BLIND/SHEAR RAM -MUD CROSS -5-1/2"FIXED BORE LOWER RAM -RU 5-1/2"TEST JOINT. -TAKE MEASUREMENTS FROM RKB. -CLEAN NEW CAMERON STACK. -INVENTORY SHAFFER RAMS AND OFFLOAD FOR INSPECTION. CONTINUE HOURLY MONITOR OF OA STARTED 02/21 00:00-NO FLOW. 06:30 - 07:30 1.00 BOPSUR P DECOMP HOLD PRE JOB SAFETY MEETING,RIG UP BOP TESTING EQUIPMENT 07:30 - 09:00 1.50 BOPSUR P DECOMP FILL STACK,SHELL TEST BOPE STACK AND HIGH PRESSURE RISER. 09:00 - 14:30 5.50 BOPSUR P DECOMP TEST UPPER 7"FIXED RAMS AND LOWER 5-1/2"FIXED RAMS TO 250 PSI LOW,5000 PSI HIGH FOR 5 CHARTED MINUTES EACH -FAIL/PASS ON KILL LINE FLANGE, RE-TIGHTEN AND RE-TEST -FAIL/PASS ON KILL HCR,GREASE, FUNCTION AND RE-TEST -TEST RAM LOCKS -TEST GAS AND PVT ALARMS I-SEE ATTACHED BOP TEST CHARTS -TESTS WITNESSED BYAOGCC REPRESENTATIVE JEFF JONES Printed 3/7/2016 9:06.05AM 411 North America-ALASKA-BP Page 5 of 13 /fli Operation Summary Report Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. iI MIA:500292022300 Active datum:09-07B PLAN c@68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) j (usft) 14:30 - 16:30 2.00 WHSUR N SFAL DECOMP TWO WAY CHECK LEAKING(TWC) -PRESSURE UP FROM ABOVE TO 2000 AND 4000 PSI IN ATTEMPT TO SEAT POPPET -RIG UP,PRESSURE UP FROM BELOW TO 2000 AND 3500 PSI,POPPET SEATED -PRESSURE UP TO 4000 PSI TO VERIFY TWC NOT LEAKING 16:30 - 18:30 2.00 BOPSUR P DECOMP "-TEST ANNULAR PREVENTER TO 250 PSI LOW /3500 PSI HIGH FOR CHARTED MINUTES EACH WITH 5-1/2"AND 7"TEST JOINTS -COMPLETE CHAMBER TEST ON LOWER PIPE RAMS TESTS WITNESSED BYAOGCC REPRESENTATIVE JEFF JONES 18:30 - 19:00 0.50 BOPSUR P DECOMP SERVICE TOP DRIVE AND FLOOR EQUIPMENT 19:00 - 22:30 3.50 WHSUR P DECOMP RIG UP DUTCH RISER AND LUBRICATOR TO PULL TWC -INSTALL 40'OF EXTENSIONS AND BOW SPRINGS -TEST LUBRICATOR TO 250 PSI LOW,3500 IPS!HIGH FOR LEAK TIGHT ASSURANCE PULL TWC,BREAK AND LAY DOWN LUBRICATOR AND DUTCH RISER 22:30 - 23:30 1.00 PULL P DECOMP j RIG UP CONTROL LINE SPOOLER I-MAKE UP LANDING JOINT,RUN IN AND ENGAGE HANGER -CHECK IA TO VERIFY NO PRESSURE 23:30 - 00:00 0.50 PULL P DECOMP UN-SEAT HANGER WITH 193K,CALCULATED PULL 185K -MONITOR WELLBORE WHILE PULLING HANGER TO RIG FLOOR-STATIC -CLOSE ANNULAR PREVENTER,PREPARE TO CIRCULATE 2/23/2016 00:00 - 01:30 1.50 PULL P DECOMP CIRCULATE BOTTOMS UP PLUS(400 BBLS) AFTER PULLING TUBING HANGER TO THE RIG FLOOR ,-LINE UP TO GAS BUSTER THROUGH CHOKE 1-VERIFY GAS BUSTER IS CLEAR OF OBSTRUCTION -BRING ON PUMPS SLOWLY AT 1 BPM, INCREASING TO 7 BPM WITH 210 PSI CONTINUE HOURLY MONITOR OF OA STARTED 02/21 00:00-NO FLOW. 01.30 - 02:00 0.50 PULL P DECOMP MONITOR WELL WHILE HOLDING A PRE-JOB SAFETY MEETING FOR PULLING AND LAYING DOWN TUBING COMPLETION 02:00 - 02:30 0.50 PULL P DECOMP I RIG UP TO PULL TUBING ,-RIG UP DOUBLE STACK POWER TONGS j-MAKE UP SAFETY SHEAR JOINTS AND J SAFETY VALVES I-TERMINATE CONTROL LINE I-BREAK OUT LANDING JOINT WITH CROSSOVER AND TUBING HANGER 02:30 - 05:30 3.00 PULL P DECOMP PULL OUT OF THE HOLE LAYING DOWN 7", 26#,13CR-80,NSCC TUBING FROM 8,920'MD TO 6,869'MD -PICK UP WEIGHT 187K I-SPOOL 1/4"BARE CONTROL LINE FROM 12,100'MD(SSSV) Printed 3/7/2016 9:06:05AM • North America-ALASKA-BP Page 6 of 13 Operation Summary Report Common Well Name 09-07 AFE No Event Type:WORKOVER(WO) I Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN t 68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 06:00 0.50 PULL P DECOMP CHANGE OUT ELEVATORS AND TONG HEADS TO 5-1/2" -MAKE UP 5-1/2"SAFETY SHEAR JOINT 06:00 - 14:30 8.50 PULL P DECOMP PULL 5-1/2,17#,13CR-80,NSCC TUBING FROM 6,869'MD TO 6,818'MD -REMOVE CONTROL LINE FROM SSSV AND LAY DOWN RECOVER 25 STAINLESS STEEL BANDS,5 BANDS LEFT IN HOLE -PULL 5-1/2"TUBING FROM 6,818'MD TO 'SURFACE LAY DOWN CUT JOINT OF 20.71' 14:30 - 15:30 1.00 BOPSUR P DECOMP RIG DOWN,LAY DOWN CASING HANDLING EQUIPMENT -PRESSURE WASH ALL EQUIPMENT BEFORE SENDING OUT SLIDE -INSTALL DOUBLE STACK TONGS IN CARRIER -BREAK AND LAY DOWN SAFETY SHEAR JOINT -CLEAR AND CLEAN FLOOR _ 15:30 - 17:30 2.00 BOPSUR P DECOMP MAKE UP TEST JOINT -MAKE UP TEST PLUG,RUN IN HOLE FMC RUN LOCK DOWNS -PERFORM A ROLLING TEST FROM BELOW TO 1500 PSI,NO LEAKS PAST PLUG 17:30 - 20:00 2.50 BOPSUR P DECOMP CHANGE BOTTOM AND TOP RAMS TO 2-7/8"X 5"VARIABLES 20:00 - 22:00 2.00 BOPSUR P DECOMP TEST BOP RAMS TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST UPPER AND LOWER RAMS WITH 3-1/2" AND 4-1/2"TEST JOINTS -TEST ANNULAR PREVENTER WITH 3-1/2" TEST JOINT TEST CHART ATTACHED 22.00 - 23:00 1.00 BOPSUR P DECOMP PULL FMC TEST PLUG -BACK OUT LOCK DOWNS BREAK AND LAY DOWN TEST JOINTS -BLOW DOWN SURFACE LINES 23:00 - 23:30 0.50 DHB P DECOMP MAKE UP HES,RETRIEVABLE BRIDGE PLUG (RBP) 23:30 - 00:00 0.50 DHB P DECOMP RUN IN HOLE WITH RBP ON DRILLPIPE ONE BY ONE TO 540'MD. 2/24/2016 00:00 - 13:00 13.00 DHB P DECOMP RUN IN HOLE WITH RBP ON DRILLPIPE ONE BY ONE FROM 540'MD TO 8,900'MD -PICK UP DRILL PIPE 1X1 -RUNNING SPEED 100 FPM -PLUG TOOK WEIGHT AT 3,300'MD,WORK UP TWICE,MAKE 1/2 TURN TO THE RIGHT ABLE TO GO DOWN 13:00 - 13:30 0.50 DHB P DECOMP SET RBP AT 8,900'MD WITH LEFT HAND TURNS RELEASE FROM PLUG,RACK BACK 2 STANDS Printed 3/7/2016 9:06:05AM • Page 70 -rmatq• North A rf Operation Summary e Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project.Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time.9/7/1976 12:OO:OOAM Rig Release 2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN©68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 20:30 7.00 DHB P DEC OMP RIG UP TO TEST 9-5/8,47#,N-80,CASING -TEST AT 8,900'MD AGAINST RBP(FIRST RBP RUN) PERFORM PRESSURE CROSS CHECK TEST TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS -TEST TO 3500 PSI HIGH FOR 30 CHARTED MINUTES-FAIL -PRESSURE TO 3630 PSI,35 PSI LOST IN FIRST 15 MINUTES,50 PSI IN SECOND 15 MINUTES,45 PSI LOST IN THIRD 15 MINUTES PUMP 8.3 BBLS,BLEED BACK 7.3 BBLS -CALCULATED 7.8 BBLS TO PRESSURE UP TO 3630 PSI REPEAT TEST -TEST TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS -TEST TO 3500 PSI HIGH FOR 30 CHARTED MINUTES-FAIL -PRESSURE TO 3670 PSI,60 PSI LOST IN FIRST 15 MINUTES,50 PSI IN SECOND 15 MINUTES,60 PSI LOST IN THIRD 15 MINUTES -PUMP 8.0 BBLS,BLEED BACK 6.9 BBLS CALCULATED 7.9 BBLS TO PRESSURE UP TO 3670 PSI RETRIEVE RBP,PULL UP TO 8,400'MD,SET PLUG,RELEASE FROM PLUG AND PULL STANDS PERFORM PRESSURE CROSS -TEST CASING AT 8,400'MD AGAINSTCHECK RBP (FIRST RBP RUN) TEST TO 300 PSI LOW FOR 5 MINUTES- PASS -TEST TO 3500 PSI HIGH FOR 30 MINUTES- FAIL - E O SI, OST FIRST PRESSUR15 MINUTEUP TS,1003690 PSI P01B0 TO INPSI SECOND LIN 15 MINUTES PUMPED 9 BBLS,BLEED BACK 7.3 BBLS -CALCULATED 7.7 BBLS TO PRESSURE UP TO 3690 PSI -TEST CASING TO 2500 PSI FOR 30 MINUTES IN AN ATTEMPT TO MIRROR MIT IN DECEMBER -TEST CASING AT 8,400'MD AGAINST RBP (FIRST RBP RUN) -TEST TO 300 PSI LOW FOR 5 MINUTES- PASS -TEST TO 2500 PSI HIGH FOR 30 MINUTES- FAIL - O P , POSI FIRST PRESSURE 15 MINUTEUPTS,702500 PSI SILOST80 INSI SECOND LE 15 MINUTES PUMPED 5.7 BBLS,BLEED BACK 5.5 BBLS -CALCULATED 5.2 BBLS TO PRESSURE UP TO 2500 PSI -CONSULT WITH ODE AND WOS,DECISION MADE TO PULL OUT OF THE HOLE WITH RBP I I I Printed 3/7/2016 9:06:05AM • Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN @68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -RUN IN,ENGAGE RBP WITH RIGHT HAND TURNS,RELEASE RPB 20:30 - 21:00 0.50 DHB P DECOMP RIG DOWN FROM PRESSURE TESTING, BLOW DOWN SURFACE LINES -MONITOR WELL WHILE RIGGING DOWN- [STATIC MUD WEIGHT IN AND OUT 8.5 PPG 21:00 - 21:30 0.50 DHB P DECOMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 21 30 - 00:00 2.50 DHB P DECOMP PULL OUT OF THE HOLE WITH RPB FROM 8,400'MD TO 1,300'MD [-PULL 100 FPM,UP WEIGHT 155K,DOWN 145K 2/25/2016 00:00 - 01:00 1.00 DHB P DECOMP PULL OUT OF THE HOLE WITH RBP FROM 11,300'MD -FLOW CHECK WELL WITH BHA AT BOP- STATIC 01:00 - 01:30 0.50 DHB P DECOMP LAY DOWN 9-5/8"RETRIEVABLE BRIDGE PLUG(RBP) -RECOVERED 2 SS BANDS FROM RBP, NOTED ONE BAND IN FLOWBOX,WILL RECOVER AT OPPORTUNE TIME. 1 OF 2 RBP ELEMENTS WAS MISSING AND THE OTHER WAS MISSING CHUNKS 01:30 - 02:30 1.00 CLEAN P DECOMP CLEAR AND CLEAN FLOOR 02:30 - 03:30 1.00 CLEAN. P DECOMP BRING BAKER CLEAN OUT ASSEMBLY TOOLS TO RIG FLOOR -CHECK OD/ID AND LENGTHS OF TOOLS AND HANDLING EQUIPMENT -VERIFY OD OF DART FOR PUMP OUT SUB AT 2-1/4" 03:30 - 05:30 2.00 CLEAN P DECOMP MAKE UP CLEANOUT ASSEMBLY AND RUN IN HOLE to 323'MD -MAKE UP TAPERED MILL AND STRING MILL AT 8-1/2"OD 05:30 - 10:30 5.00 CLEAN P DECOMP RUN IN HOLE WITH CLEANOUT ASSEMBLY FROM 323'MD TO 8,943'MD -NO ISSUES AT 3,350'MD,RUN TO BOTTOM WITH NO ISSUES -TAG UP ON TUBING STUMP AT 8,943'MD, SET DOWN 10K -MONITOR WELL FOR 10 MINUTES-STATIC -RECOVERED ONE STAINLESS STEEL BAND FROM FLOW BOX 10:30 - 15:00 4.50 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN OUT ASSEMBLY FROM 8,943'MD TO 323'MD -OFF BOTTOM UP WEIGHT 181K,DOWN WEIGHT 164K -MONITOR WELL FOR 10 MINUTES WITH BHA BELOW BOP-STATIC 15:00 - 16:00 1.00 CLEAN P DECOMP PULL AND LAY DOWN CLEAN OUT ASSEMBLY -STAND BACK DRILL COLLARS BREAK AND LAY DOWN MILL ASSEMBLY -NO WEAR OR DAMAGE OBSERVED ON MILLS -RECOVERED ONE HAND FULL OF PARAFFIN FROM MILL COURSE 16:00 - 16:30 0.50 CLEAN P DECOMP CLEAR AND CLEAN FLOOR WHILE MONITORING WELLBORE-STATIC Printed 3/7/2016 9:06.O5AM Page9of13,r North America-ALASKA-BP r ,'s Operation nmmary deport Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E.(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN©68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 17:00 0.50 DHB N DFAL 8,900.00 DECOMP PICK UP,MAKE UP AND RIH WITH HES RBP -NPT ON THIS RUN DUE TO RBP FAILURE 17:00 - 22:00 5.00 DHB N DFAL 8,900.00 DECOMP RUN IN HOLE WITH RBP ON ELEVATORS AT 100 FPM(FEET PER MINUTE)TO 8,900'MD, NO HOLE PROBLEMS 22:00 - 22:30 0.50 DHB N DFAL 8,900.00 DECOMP SET RBP AT 8,900'MD,RACK BACK 2 STANDS 22:30 - 23:30 1.00 DHB N DFAL 8,900.00 DECOMP RIG UP TO TEST 9-5/8,47#,N-80,CASING -PERFORM PRESSURE CROSS CHECK !-TEST CASING AT 8,900'MD AGAINST RBP (SECOND RBP RUN) -TEST TO 300 PSI LOW FOR 5 MINUTES- PASS TEST TO 3500 PSI HIGH FOR 30 MINUTES- FAIL -PRESSURE UP TO 3760 PSI,100 PSI LOST IN FIRST 15 MINUTES,100 PSI LOST IN SECOND 15 MINUTES -PUMPED 9.4 BBLS,BLEED BACK 8.3 BBLS -CALCULATED 8.3 BBLS TO PRESSURE UP TO 3760 PSI 23:30 - 00:00 0.50 DHB NI DFAL 8,900.00 DECOMP RUN IN 2 STANDS,ENGAGE RBP,RELEASE PLUG -TURN RIGHT AND RELEASE PLUG WITH 40K UP -GO DOWN PAST 8,900'MD TO VERIFY PLUG IS RELEASED MONITOR WELL FOR 10 MINUTES-STATIC 2/26/2016 00:00 - 01:30 1.50 DHB N DFAL 8,900.00 DECOMP POOH FROM 8,900'MD TO 7,500'MD,SET RBP (RETRIEVABLE BRIDGE PLUG) 01:30 - 04:00 2.50 DHB N DFAL 8,900.00 DECOMP RIG UP TO TEST 9-5/8,47#,N-80,CASING i-PERFORM PRESSURE CROSS CHECK TEST CASING AT 7,500'MD AGAINST RBP (SECOND RBP RUN) -TEST TO 300 PSI LOW FOR 5 MINUTES- PASS -TEST TO 3500 PSI HIGH FOR 30 MINUTES- FAIL -PRESSURE UP TO 3760 PSI,160 PSI LOST IN FIRST 15 MINUTES,150 PSI LOST IN SECOND 15 MINUTES -PUMPED 7.9 BBLS,BLEED BACK 7.2 BBLS -CALCULATED 7.0 BBLS TO PRESSURE UP TO 3760 PSI -CHECK OA FOR PRESSURE -CHECK SURFACE EQUIPMENT,VERIFY DOUBLE BLOCK ON SYSTEM 1-PRESSURE UP TO 3700 PSI,LOOSE 100 PSI IN 10 MINUTES,SHUT DOWN TEST 04:00 - 06:00 2.00 DHB N DFAL 8,900.00 DECOMP RELEASE PLUG WITH RIGHT HAND TURNS AND 20K UP,NO PROBLEMS ,-MONITOR FOR 10 MINUTES-STATIC POOH FROM 7,500'MD TO 3,706'MD,NO ISSUES PULLING OUT OF THE HOLE -SET RBP Printed 3/7/2016 9:06:05AM • North America-ALASKA-BP " Operation Summary Report ' Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN(g68.15usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 08:00 2.00 DHB N DFAL 8,900.00 DECOMP RIG UP TO TEST 9-5/8;47#,N-80,CASING -PERFORM PRESSURE CROSS CHECK -TEST CASING AT 3,706'MD AGAINST RBP (SECOND RBP RUN) TEST TO 300 PSI LOW FOR 5 MINUTES- PASS -TEST TO 3500 PSI HIGH FOR 30 MINUTES- -FAIL -PRESSURE UP TO 3650 PSI,300 PSI LOST IN FIRST 15 MINUTES,175 PSI LOST IN SECOND 15 MINUTES -PUMPED 3.6 BBLS,BLEED BACK 3.0 BBLS -CALCULATED 3.3 BBLS TO PRESSURE UP TO 3650 PSI 08:00 - 09:00 1.00 DHB N DFAL 8;900.00 DECOMP RELEASE PLUG WITH RIGHT HAND TURNS PULL UP,NO PROBLEMS -MONITOR FOR 10 MINUTES-STATIC -POOH FROM 3,706'MD TO 2,200'MD,NO ISSUES PULLING OUT OF THE HOLE -SET RBP AT 2,200'MD 09:00 - 10:30 1.50 DHB N DFAL 8,900.00 DECOMP RELEASE FROM RBP WITH RUNNING TOOL MONITOR FOR 10 MINUTES-STATIC -POOH FROM 2,200'MD TO SURFACE LAY DOWN RBP RUNNING TOOL 10:30 - 12:00 1.50 DHB N DFAL 8,900.00 DECOMP RIG UP TO TEST 9-5/8,47#,N-80,CASING -PERFORM PRESSURE CROSS CHECK -TEST CASING AT 2,200'MD AGAINST RBP (SECOND RBP RUN) -TEST TO 300 PSI LOW FOR 5 MINUTES- PASS -TEST TO 3500 PSI HIGH FOR 30 MINUTES- PASS -PRESSURE UP TO 3700 PSI,5 PSI LOST IN FIRST 15 MINUTES,0 PSI LOST IN SECOND 15 MINUTES -PUMPED 2.6 BBLS,BLEED BACK 2.5 BBLS -CALCULATED 2.0 BBLS TO PRESSURE UP TO 3700 PSI 12:00 - 12:30 0.50 DHB P DECOMP CLEAR AND CLEAN FLOOR 12:30 - 14:00 1.50 DHB P DECOMP RUN IN THE HOLE WITH RBP RETRIEVAL TOOL TO 2,200'MD,LATCH UP AND RELEASE PLUG,NO ISSUES 14:00 - 16:00 2.00 DHB P DECOMP MONITOR WELL FOR 10 MINUTES-STATIC PULL OUT OF THE HOLE FROM 2,200'MD -MONITOR WELL FOR 10 MINUTES WITH BHA BELOW BOP -LAD DOWN RBP RUNNING TOOL 16:00 - 16:30 0.50 DHB P DECOMP CLEAR AND CLEAN FLOOR 16:30 - 17:00 0.50 DHB P DECOMP MAKE UP EZSV ASSEMBLY -MAKE UP EZSV WITH 3/4"BALL RELEASE -MAKE UP RTTS AND RUNNING TOOL 17:00 - 22:30 5.50 DHB P DECOMP RUN IN THE HOLE WITH EZSV/RTTS ASSEMBLY TO 8,900'MD 22:30 - 00:00 1.50 DHB P DECOMP DROP EZSV 3/4"SETTING BALL -PUMP DOWN AT 1 BPM WITH 55 PSI Printed 3/7/2016 9:06.O5AM • i North America-ALASKA B `Operat!on Summary Report, x Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 I Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN©68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/27/2016 00:00 - 01:30 1.50 DHB P DECOMP PUMP 3/4"EZSV SETTING BALL DOWN AT 1 BPM WITH 25 PSI -PRESSURE UP TO 2150 PSI,ELEMENT SET -PICK UP TO 50K OVER,SHEAR OFF EZSV -ESTABLISH CIRCULATION TO VERIFY RELEASE -GO DOWN,TAG UP WITH 5K ON PLUG, VERIFY PLUG SET AT DEPTH 01:30 - 02:30 1.00 DHB P DECOMP PULL UP HOLE TO 8,713'MD,SET RTTS NO ISSUES 02:30 - 03:30 1.00 DHB P DECOMP TEST EZSV AT 8,900'MD AGAINST RTTS -PERFORM PRESSURE CROSS CHECK -TEST TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS -TEST TO 3500 PSI HIGH FOR 30 CHARTED MINUTES-PASS -PRESSURE TO 3740 PSI,40 PSI LOST IN FIRST 15 MINUTES,0 PSI IN SECOND 15 MINUTES -PUMP 1.6 BBLS,BLEED BACK 1.6 BBLS CALCULATED 1.4 BBLS TO PRESSURE UP TO 3700 PSI 03:30 - 06:00 2.50 DHB P DECOMI5 PULL OUT OF THE HOLE LAYING DOWN DRILL _PIPE 1X1 FROM 8,713'MD TO 6,620'MD 06:00 - 06:30 0.50 DHB P DECOMP PUMP 75 BBLS,DRILLPIPE VOLUME,DUE TO FLUID SYSTEM OUT OF BALANCE. 06:30 - 11:00 4.50 DHB P DECOMP PULL OUT OF THE HOLE LAYING DOWN DRILL PIPE 1X1 FROM 6,620'MD TO 2,504'MD 11:00 - 13:30 2.50 DHB P DECOMP TEST 9-5/8"CASING BETWEEN EZSV AT 8,900' MD AND RTTS AT 2,504'MD -PERFORM PRESSURE CROSS CHECK -TEST FROM BELOW TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS -TEST FROM BELOW TO 3500 PSI HIGH FOR 30 CHARTED MINUTES-PASS -PRESSURE TO 3700 PSI,0 PSI LOST IN FIRST 15 MINUTES,0 PSI LOST IN SECOND 15 MINUTES -PUMP 6.2 BBLS,BLEED BACK 6 BBLS -CALCULATED 6.3 BBLS TO PRESSURE UP TO 3700 PSI TEST 9-5/8"CASING ABOVE 2,504'MD AGAINST RTTS -TEST FROM ABOVE TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS -TEST FROM ABOVE TO 3500 PSI HIGH FOR 20 CHARTED MINUTES-FAIL I-PRESSURE TO 3700 PSI,600 PSI LOST IN FIRST 15 MINUTES,SHUT DOWN TEST AT 20 MINUTES PUMP 2.5 BBLS,BLEED BACK 1.5 BBLS -CALCULATED 2.4 BBLS TO PRESSURE UP TO 3700 PSI 13:30 - 14:00 0.50 DHB P DECOMP RIG DOWN SURFACE EQUIPMENT AND BLOW DOWN LINES 14:00 - 17:30 3.50 DHB P DECOMP PULL OUT OF THE HOLE FROM 2,504'MD TO BHA LAYING DOWN DRILLPIPE 1X1 -MONITOR FOR 10 MINUTES-STATIC 17:30 - 18:00 0.50 DHB P DECOMP LAY DOWN RTTS AND RUNNING TOOLS Printed 3/7/2016 9:06.05AM North America-ALASKA �� Page 12 of 13 Operation Summary Report z Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) I Start Date:2/18/2016 I End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12.00:OOAM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. I UWI:500292022300 Active datum:09-07B PLAN©68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 19:30 1.50 DHB P DECOMP RUN IN THE HOLE WITH DRILL COLLARS, PULL AND LAY DOWN 19:30 - 22:00 2.50 TA P OTHCMP RIG UP TUBULAR HANDLING EQUIPMENT -RIG UP DOYON DOUBLE STACK TONGS -FINALIZE TUBING STRAP AND TOOLS IN PIPESHED FINALIZE RUNNING ORDER 22:00 - 00:00 2.00 TA P OTHCMP RUN 3-1/2",9.3#,L-80,TCII TUBING KILLSTRING TO 900'MD USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 2400 FT/LBS RUN JOINT#A AND JOINT#1 WITH CENTRALIZERS 2/28/2016 00:00 - 08:30 8.50 TA P OTHCMP RUN 3-1/2",9.3#,L-80,TCII TUBING KILLSTRING FROM 900'MD TO 8,878'MD -USE JET LUBE SEAL GUARD PIPE DOPE TORQUE CONNECTIONS TO 2400 FT/LBS 08:30 - 09:30 1.00 TA P OTHCMP CHANGE OUT ELEVATORS,MAKE UP LANDING JOINT,PICK UP HANGER I-RUN AND LAND HANGER IN PROFILE 09:30 - 10:30 1.00 TA P OTHCMP RUN IN LOCK DOWN SCREWS ON HANGER PULL AND LAY DOWN LANDING JOINT 10:30 - 13:30 3.00 TA _ P OTHCMP PRE-JOB SAFETY MEETING FOR CIRCULATING CORROSION INHIBITOR -RIG UP LINES TO REVERSE CIRCULATE -REVERSE CIRCULATE 445 BBLS OF CORROSION INHIBITED SEAWATER AT 4 BPM WITH 760 PSI. 13:30 - 18:00 4.50 TA P OTHCMP FREEZE PROTECT INNER ANNULUS AND TUBING KILLSTRING TO 2,137'MD/TVD -REVERSE CIRCULATE 175 BBLS DIESEL AT 2.5 BPM -RIG UP AND U-TUBE DIESEL FROM IA TO TUBING FOR ONE HOUR -SIMOPS:OFF LOAD PITS 18:00 - 19:00 1.00 WHSUR P OTHCMP RIG UP"T"BAR,RUN AND SET TWC IN PROFILE 19:00 - 20:30 1.50 WHSUR P OTHCMP PERFORM ROLLING PRESSURE TEST OF I TWC FROM BELOW TO 1500 PSI FOR 5 CHARTED MINUTES -LOSE LESS THAN 10 PSI PER MINUTE FOR 5 MINUTES,NO FLOW OR COMMUNICATION ABOVE TWC PRESSURE TEST FROM ABOVE TO 300 PSI LOW,LOSE 10 PSI OVER 5 MINUTES,SHOWS STABILIZATION -PRESSURE TEST FROM ABOVE TO 3500 PSI HIGH,LOSE 10 PSI OVER 5 MINUTES,SHOWS STABILIZATION 20:30 - 21:30 1.00 WHSUR P OTHCMP BLOW DOWN SURFACE LINES,RIG DOWN _TESTING EQUIPMENT 21:30 - 00:00 2.50 BOPSUR P OTHCMP NIPPLE DOWN BOPE -NIPPLE DOWN FLOW RISER -NIPPLE DOWN BOP STACK AND SET BACK ON STUMP Printed 3/7/2016 9:06:05AM • • -ra urimrrfary Repo Common Well Name:09-07 AFE No Event Type:WORKOVER(WO) Start Date:2/18/2016 I End Date:2/29/2016 X4-0122G-E:(3,457,000.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:9/7/1976 12:00:00AM Rig Release:2/29/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292022300 Active datum:09-07B PLAN @68.15usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/29/2016 00:00 02:00 2.00 BOPSUR P OTHCMP NIPPLE DOWN HIGH PRESSURE RISERS,LAY DOWN -PERFORM RIG DOWN OPERATIONS PREP WELLHOUSE FOR TREE INSTALLATION -HOLD PRE-JOB SAFETY MEETING FOR NIPPLE UP OF TREE WITH RIG CREW AND FMC 02:00 - 04:00 2.00 WHSUR P OTHCMP NIPPLE UP TREE AND ADAPTER PER BP REQUIREMENTS -TORQUE TREE AND ADAPTER PER FMC PROCEDURE 04:00 - 07:00 3.00 WHSUR P OTHCMP TEST TREE AND HANGER VOID -TEST HANGER VOID TO 300 PSI LOW FOR 5 CHARTED MINUTES-PASS TEST HANGER VOID TO 4500 PSI HIGH FOR 5 CHARTED MINUTES-PASS SEE ATTACHED CHART -TEST TREE TO 300 PSI LOW AND 5000 PSI HIGH FOR 5 MINUTES EACH FOR VISUAL LEAK TIGHT ASSURANCE REMOVE MUD LINES UNDER RIG FLOOR -LAY DOWN PIPE CAT,SECURE PIPE SHED, UN-PLUG MUD MODULE 07:00 - 09:00 2.00 RIGD P OTHCMP BRIDLE UP,SECURE PIPE SHED,BLOW DOWN LINES TO RIG FLOOR i *RIG RELEASED AT 09:00 HOURS* Printed 3/7/2016 9 06:05AM TREE= C3VV • " WELLLI-EAD= FMC /� O I- SAF NOTES: CAUTION: H7S OVER 300 ppm. O{9 ACTUATOR= AXELSON WELL ANGLE>70°@ 9478. "'CHROME TBG"" OKB.ELEV= SUSPENDED REF ILE/= BF.EL.EV= , 2200'-2500' {PRODUCTION CSG LEAK KOP= 3167' Max Angle= 101°@ 10120' , 2312' —j9-5/8"HOVUCO FO VALVE Datum MD= 9453' I 2437' H9-5/8"HOW.O FO VALVE • Datum TVD= 8800'SS 13-3/8"CSG,72#,M-80,D=12.347" -H 2740' Minimum ID =2.80" @ 9079' 3-3/16" LINER [3-1/2"TBG,9.3#.L-80 TCI,.0087 bpf,D=2.992" H 8867' 7 \ 8867' —3-1/2"WLEG,D=2.980" [9-5/8"FES EZSV-B(02/27/16) —{ 8900' RCT CUT TBG(12/27/15) 8920' EL—M1 /N.^,/ 5-1/2'TBG PUNCH(12/27/15) IH 8930' -8932' E` Cl. 8951' 9-518"X 5-112"TNV FBBP PKR ' 9006' J-4-1/2"DEPLOY SLV,D=? , 9025' —j5-1/2"FESX NP,D=4.56" BEHIND CT LNR 9041' H5-1/2"HES X NP,D=4.45' ! 5-1/2'TBG,17#,13-CR-80,.0232 bpf,D=4.89T H 9053' ) 9053' —[5-1/2"WLEG,D=4.892" H ELK/OTT NOT LOGGED 9106'CTM —IJET CUT LNR(12/24/15) 3-1/2'LNR,8.8#,L-80,.0087 bpi,D=2.992' ——9120' CTM —9120'CTM —+PRE RIG P&A(12/23/15)[ ivov,. . ,-- —,x ,.V T 9132'CTM H POSSIBLE LM DA MA GE(T.AGGED 11/06/05) 111111 .•::.*44 ..''':;,11111 1111111[,'';:: 141111 111111111'x';::{% '11 MLLOUT WINDOW (09-07A) 9248'-9257' 111111 1111111 L9-5/8"CSG,47#,MN-80,D=8.681" 111111;'``:::-' —{ 9658' 11111 :::., ..... /1 ;::.. FERFORATION SUMMARY 111111111 1111111111': ` 11111111111111111111 .` REF LCX;:RESISTIVITY ON 04/23/99 1111111111111 ANGLE AT TOP PERF:65 @ 9504' 44.4.444.6441 4: . Note:Refer to Production DB for historical perf data 9719' --ICBP2 562" SIZE SPF INTERNAL Opn/Sqz DATE 2" 4 9504-9509 S 12/22/15 2" 4 9554-9564 S 12/22/15 s. 2" 4 9590-9600 S 12/22/15 4. 2" 4 9654-9674 S 12/22/15 2" 4 9684-9704 S 12/22/15 2" 4 9788-9798 S 12/22/15 NO\‘'''s % 2" 6 9910-10135 S 12/22/15 3-3/16"LNR,6.2#,L-80, H 1084T 2" 6 10805- 10840 S 12/22/15 .0087 bpf,D=2.786" TD —{ 10934' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MIT r 10/76 ORIGINAL COMPLETION 12/30/15 STF/JMD TBG CUT&PUNCH(12/27/15) _ WELL: 09-07A 11/18/94 LAST WORKOVER 03/03/16 JMD DRLG HO CORRECTIONS PERM(No:'1990220 04/27/99 SIDETRACKED(09-07A) 03/23/16 JMD EDITS ARND: 50-029-20223-01 02/28/16 P-272 OPS SUSPB+IDED 03/24/16 SMJMD FINAL ODE APPROVAL SEC 2,T10N,R15E,1933'FSL&49'FEL 10/13/08 PJFYPJC POSSIBLE LNR DMG 11/06/06 12/30/15 I IFUJMD JET CUT LW/GMT SQZ(12122-24/15) BP Exploration(Alaska) a. • • OF Tit, A f\�� //j,'•9 THE STATE Alaska Oil and Gas 1 -i^a��1 ofA L A S KA Conservation Commission kiiM - 333 West Seventh Avenue " i C GOVERNOR BILL WALKER a.,Anchorage, Alaska 99501-3572 * ' '"" '� Main: 907.279.1433 gip °'SyCe' Fax: 907.276.7542 www.aogcc.alaska.gov David Bjork Engineering Team Lead , t; 1 � BP Exploration(Alaska), Inc. scoop ? P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-07A Permit to Drill Number: 199-022 Sundry Number: 316-161 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, SL— Cathy . Foerster Chair DATED this day of March, 2016. RBDMS t,v, MAR 2 2 2016 ficLoti vto STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI FEB2 9 2016 APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend Q • Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program I ! • Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 199-022 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p• 6. API Number: 50-029-20223-01-00 • 99519-6612 Stratigraphic 0 Service 0 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 0 No RI PBU 09-07A - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327 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): 10934 • 9009 • 9120 8589 pro i 9120(TOC) 9025,9195 Casing Length Size MD TVD Burst Collapse Structural Conductor 75 20" 35-111 35-111 1530 520 Surface 2740 13-3/8" 35-2775 35-2775 4930 2670 Intermediate 9216 9-5/8" 32-9248 32-8708 8150/6870 5080/4760 Production Liner See Attachment 3-1/2"x 3-3/16" –9120-10847 8589-9002 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None 5-1/2",17# 13Cr80 8920-9063 Packers and SSSV Type: 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8958, 8440 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development p - Service 0 14.Estimated Date for Commencing Operations: 2/26/2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended O 16.Verbal Approval: Date: 2/27/2016 GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: Victoria Loepp GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Mclaughlin,Sean M be deviated from without prior written approval. Email Sean.McLaughlin@bp.com Printed Name David Bjork Title Engineering Team Lead Signature ,... /�i 1 //y� Phone +1 907 564 5683 Date �j /,y COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No IY3' Spacing Exception Required? Yes 0 No N Subsequent Form Required: /Q— 4 D _ APPROVED BYTHE Approved by' /' —_' COMMISSIONER COMMISSION Date:3.22-_/` wry 3/2z//L ORIGINAL N // ' c� RBDMS LL MAR 2 2 2016 ga\ �1 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 09-07B Suspension of Workover operations Reference Documents: • GP 10-65 Well Barriers Verify Start-up Checklist: ❑ BP Alaska has verbal approval from the commission to proceed with workover suspension operations on 09-07B. ❑ A Sundry request for shut down of operations has been filed with the state. . ❑ Primary and secondary well barriers shall be installed in the wellbore prior to temporary abandonment of a well. Issues and Potential Hazards: • 9-5/8" production casing leak between 2200' - 3750'. This is a non-hydrocarbon bearing no flow to surface zone. The well is currently static with seawater KWF. • thS: DS-09 is a high H2S Pad, weekly H2S drills need to be performed. If H2S is . encountered in excess of 20ppm, the WSL or Superintendent shall notify the commission within 24 hours after the encounter. Follow requirements of the"Hydrogen Sulfide" SOP Well Name H2S Level Date of Reading H2S level on RWO well 09-07A 600 Dec-13 Highest H2S on adjacent well (SHL) 09-43 200 Jan-13 Highest H2S level well on pad 09-03 1000 - Sep-11 DS-09 is a high H2S pad. Historical highs in Other relevant H2S the 1400 ppm range. Suspension Plan: (t,t��L� 1. Set a 9-5/8" EZSV-B bridge plug at 8,900', —20' above the 5-1/2" tubing stub • • 9-5/8" HES EZSV-B • Hydraulic setting tool • 1 joint of 4" DP • 9-5/8" RTTS • 4" DP to surface 2. Lay down 1 stand and set RTTS per HES representative. Test EZSV to to 250 psi low/ 1500 psi high for 30 minutes Pass/Fail Criteria 1 b and 3b in section 6.0 of the wellplan. Release RTTS and POOH LDDP. DPZ 3 (TSAD-BSAD)9224' -9601' MD Barriers to the reservoir include EZSV and KWF 3. Run 3-1/2" L-80 TC-II condition B killstring with mule shoe on bottom to —8850' (-50' above EZSV) y The BOPE has been tested to 3-1/2". y Hanger(preferred option) - Reuse old Gen 1 retro fit hanger and THA. Bottom thread on hanger is expected to be 7" NSCC. Crossover to 3-1/2" TC-ll required. Reinstall 7-1/16" dryhole tree. Hanger(back up plan) - Run Jigsaw hanger with 4-1/2" TC-II bottom connection. FMC is looking for an THA. Will need to get a 4-1/16 tree to location. 4. Land Tubing Hanger • • ➢ Run in lock down screws ➢ Lay down landing joint. 5. Circulate Completion Fluid ➢ Rig up to reverse circulate down the IA valve. ➢ Close the blind rams. ➢ Heat all seawater to 120°F. ➢ Reverse circulate the well with 620-bbl seawater w/ MI KI-3869 corrosion inhibitor at maximum rate. 3000 psi max pressure. 6. Freeze Protect Wellbore ➢ RU jumper between the IA and the tubing. ➢ Reverse in 175-bbls diesel into inner annulus. Allow IA and tubing to U-tube for 1- hour. 7. Set TWC by opening the blind shear rams and dry rod in the TWC ➢ Verify there is no pressure underneath the blind shears by opening the choke. ➢ Test TWC from below by"rolling" the pumps to 1500 psi for 5-min. Confirm no flow past the TWC. ➢ Test TWC from above to 250-psi low/ 3,500-psi high for 5 minutes on both tests. Pass/Fail Criteria 1 b and 2b located in section 6. 8. ND BOP and NU Tree ➢ ND BOPE and NU 13-5/8" 5K x 7-1/16" 5K adapter flange and 7-1/16" dry hole tree ➢ Barriers for ND are the kill weight fluid and TWC. ➢ Test tubing hanger void and seals to 4,500-psi for 15 charted minutes. (Pass/Fail Criteria 1 b and 3a located in section 6.0) ➢ Perform a 5 minute 250 psi low/5,000 psi high visual leak tight test of the tree. ➢ Consider dressing BOPE for the next well. 9. Secure the tree and cellar. ➢ A revised schematic is attached for reference. • • Loepp, Victoria T (DOA) From: Bjork, David <David.Bjork@bp.com> Sent: Monday, March 21, 2016 9:08 AM To: Loepp, Victoria T(DOA) Subject: RE: PBU 09-07A(PTD 199-022, Sundry 316-161) Suspension Victoria, This well will be suspended indefinitely, It had very tight economics and a limited production benefit. There is a MI sweep moving through the area that this well is positioned to capture and would yield a 2-3 year production bump. When the casing problem was identified during the RWO,the oil rate did not justify additional spending to repair and ultimately complete the well. Regards, Dave From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Friday, March 18, 2016 9:36 AM To: Bjork, David Subject: PBU 09-07A(PTD 199-022, Sundry 316-161) Suspension David, What are the plans for this well? Does it have future utility? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeooaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 KB.ELEV= 54' 0 BF.REV= 09-07A SAFETY NOTES: CAUTION: HZS OVER 300 ppm. WELL ANGLE>70°@ 9478. "*CHROME TBG*." KOP= " 3167' Max Angle= 101@10120' Suspend Datum MD= 9453' Datum ND= 8800.SS Operations - ! Production casing leak )111 between 2200' - 3750'0 13-3/r CSG,72#,M-80,D=12.347" 2740' es /SOO Minimum ID =2.80" @ 9079' 3-3/16" LINER 3-1/2" L-80 TC-II Kill String -8850' — 9-5/8" EZSV-B at -8900' / RCT cut of 5-1/2" tubing- 8920' *,4 8951' —19-5/8"X 5-112"TNN I-BBP PKR Top of 4-1/2" deployment sleeve- 9006' 9025' H 5-1/2"I-ES X NP,D=4.56" BEHIND CT LNR I 9041' H5-1/2"FES X NP,D=4.45" 5-112"TBG,17#,13-CR-80,.0232 bpf,D=4.892" H 9053' \ I 9053' --I5-1/2"WLEG,ID=4.892" 3-1/2"LNR,8.8M,L-80,.0087 bpf,D=2.992" H 9079' „_.— 9105' Jet cut 3-3/16" tubing . ??? -13-1/2"X3-3/16"ND,ID=2.786' 9132'CTM HPOSSIBLE LNRDAMAGE(TAGGED 11/06/05) 9-5/8"CSG,47#,MN-80,D=8.681" H 9658' IiI ; 1Pre-rig P&Ai11111PEFORATIONSUM WRY11� 111111REF LOG:RESISTIVITY ON 04/23/99 014 411 MLLOUTWINDOW (09 07A) 9257111 •11ANGLE AT TOP PBF:65 @950411111Note:Refer to Roductin DB for historical pert data1111111SIZE SPF INTEVAL Opn/Sqz DATE111111111 `2" 4 9504-9509 0 04/04!00111111111112" 4 9554-9564 O 04/03/0011111111111111111112" 4 9590-9600 O 04/031001�1�1�1�1�1�1�1 2" 4 9654-9674 0 04/02/00 9719' H CBP 2.562" 2" 4 9684-9704 0 04/02/00 ` 2" 4 9788-9798 0 04/01/00 2" 6 9910-10135 0 04/25/99 2" 6 10805-10840 0 04/25/99 ` 3-3/16"LNR,6.2#,L-80, —I 10845' .0087 bpf,D=2.786" TD —I 10934' DATE REV BY CORMENTS DATE REV BY COMUENTS PRUDHOE BAY LUT R 10/76 ORIGINAL COMPLETION 05/12/06 KSB/PAG GLV C/O(05/05/06) WELL: 09-07A 11/18/94 LAST WORKOVBZ 10/13/08 PJRPJC POSSBLE LNR DMS 11/06/06 PERMT No: 1990220 04/27/99 SIDETRACKED(09-07A) 03/18/10 JCMSV TRDP LOCKED OPEN(12/19/07) AR No: 50-029-20223-01 04/21/02 BC/KAK LINER CORRECTION SEC 2 T1 ON R15E 1038.53 FEL 5193.89 FNL 09/18/02 /tlh LEVER CORRECTION j 04/20/06 JGMPJC GLV C/O BP Exploration(Alaska) • • 71--) q-oz.s_ Loepp, Victoria T (DOA) From: Mclaughlin, Sean M <Sean.McLaughlin@bp.com> Sent: Friday, February 26, 2016 2:11 PM To: Loepp, Victoria T (DOA) Cc: Lastufka,Joseph N Subject: 09-07A suspension Attachments: 09-07 suspension plan.docx;09-07A Suspension.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, After pulling tubing on well 09-07A the 9-5/8" production casing failed a 3500 psi pressure test. The PC leak was determined to be somewhere between 2200'—3750' MD. A casing repair is not planned or justified at this time and 09- 07A will be suspended. BP requests verbal approval to suspend operations on 09-07A. A Sundry will be submitted ASAP. The suspension plan and revised schematic is attached. Regards, sean Sean McLaughlin BP Workover Engineer 564-4387 Office 223-6784 Cell scANNED APR 2 1 ?.016 1 BF. OP 3167' • 09-0714 W�-z ANG E>70":9478. CHRDM E TBG"m' Max Angle= 101 010120' Suspend Datum MD= 9453' Datum TVD= 8800'SS Operations Production casing leak between 2200' - 3750' 13-3/8"CSG,72#,M-80,D=12.347" H 2740' Ili ; Minimum ID =2.80" @ 9079' 3-3/16" LINER I I 3-1/2" L-80 TC-Il Kill String 8850' r - - 9-5/8" EZSV-B at -8900' RCT cut of 5-1/2" tubing- 8920' ►-♦ oro 8951' H9-518"X 5-1/2"TFw FBBP PKR Top of 4-1/2" deployment sleeve- 9006' noII 9025' HI 5-1/2"FES X NP,D=4.56" I 9041' H 5-112"HES X NP,D=4.45" BEHIND CT LNR 5-1/2'TBG,17#,13-CR-80,.0232 bpf,D=4.892" H 9053' 9053' -15-1/2"WLEG,D=4.892" 3-112"LNR 8.8#,L-80,.0087 bpf,D=2.992" --I 9079" 9105' Jet cut 3-3/16" tubing ??? --I3-1/2"X3-3/16"XD,ID=2.786" 9132'CT m I POSSIBLE LNR DAMAGE(TAGGED 11/06/05) 9-5/8"CSG,47#,MN-80,D=8.681" —I 9658' I (00. l.�.�.�. X1111111 1/ ..4"1 Pre-rig P&A X1 111111 11111111 PERFORATION SUMMARY '1111111' 1111111 REE LOG:RESISTNTIY ON 04/23/99 1111111111 X4111 MLLOUT WINDOW (09-07A) 9257' ANGLE AT TOP PERF:65 9504' 1111111111111 ,1 Note:Refer to Roduction DB for historical pert data 111111111111111 INTERVAL SIZE SPF 4...4/1.opn/Sgz DATE 111111111111111111 2" 4 9504-9509 0 04/04/00 111111111111111111111 N 2" 4 9554-9564 0 04/03/00 X111111111111111111111 2" 4 9590-9600 0 04/03/00 ►1Q1Q1Q11/111111111 41114.4.44644 2" 4 9654-9674 0 04/02/00 14, 9719' —1 GBP 2.562" 2" 4 9684-9704 0 04/02/00 2" 4 9788-9798 0 04/01/00 ` 2" 6 9910-10135 0 04/25/99 2" 6 10805-10840 0 04/25/99 ` 3-3/16"LNR,6.2#,L-80, --I 10845' • .0087 bpf,D=2.786" TD H 10934' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHDE BAY UNIT ' 10/76 ORIGINAL COMPLETION 05/12/06 KSB/PAG GLV C1O(05/05/06) WELL 09-07A 11/18/94 LAST WORKOVB 10/13/08 PJP/PJC FOSSBLELNR DMG11/06/06 PERMIT Pb: 1990220 04/27/99 SIDETRACF®(09-07A) 03/18/10 JCMSV TRDP LOCKED OPEN(12/19/07) API Pb: 50-029-20223-01 04/21/02 BC'KAK LI B2 CORRECTION SBC 2 T1ON R15E 1038.53 FE.5193.89 FTL 09/18/02 /tlh LFE R CORRECTION 04/20/06 JGMFPJC GLV C1O BP Exploration(Alaska) • • 09-07B Suspension of Workover operations Reference Documents: • GP 10-65 Well Barriers Verify Start-up Checklist: ❑ BP Alaska has verbal approval from the commission to proceed with workover suspension operations on 09-07B. ❑ A Sundry request for shut down of operations has been filed with the state. ❑ Primary and secondary well barriers shall be installed in the wellbore prior to temporary abandonment of a well, Issues and Potential Hazards: • 9-5/8" production casing leak between 2200' - 3750'. This is a non-hydrocarbon bearing no flow to surface zone. The well is currently static with seawater KWF. • HgS: DS-09 is a high H2S Pad, weekly H2S drills need to be performed. If H2S is encountered in excess of 20ppm, the WSL or Superintendent shall notify the commission within 24 hours after the encounter. Follow requirements of the"Hydrogen Sulfide" SOP Well Name H2S Level Date of Reading H2S level on RWO well 09-07A 600 Dec-13 Highest H2S on adjacent well (SHL) 09-43 200 Jan-13 Highest H2S level well on pad 09-03 1000 Sep-11 DS-09 is a high H2S pad. Historical highs in Other relevant H2S the 1400 ppm range. Suspension Plan: 1. Set a 9-5/8" EZSV-B bridge plug at 8,900', -20' above the 5-1/2"tubing stub • 9-5/8" HES EZSV-B • Hydraulic setting tool • 1 joint of 4" DP • 9-5/8" RTTS • 4" DP to surface 2. Lay down 1 stand and set RTTS per HES representative. Test EZSV to to 250 psi low/ 1500 psi high for 30 minutes Pass/Fail Criteria lb and 3b in section 6.0 of the wellplan. Release RTTS and POOH LDDP. ➢ DPZ 3 (TSAD-BSAD) 9224' -9601' MD ➢ Barriers to the reservoir include EZSV and KWF 3. Run 3-1/2" L-80 TC-II condition B killstring with mule shoe on bottom to-8850' (-50' above EZSV) ➢ The BOPE has been tested to 3-1/2". ➢ Hanger(preferred option) - Reuse old Gen 1 retro fit hanger and THA. Bottom thread on hanger is expected to be 7" NSCC. Crossover to 3-1/2"TC-II required. Reinstall 7-1/16" dryhole tree. ➢ Hanger(back up plan) - Run Jigsaw hanger with 4-1/2" TC-Il bottom connection. FMC is looking for an THA. Will need to get a 4-1/16 tree to location. 4. Land Tubing Hanger • ➢ Run in lock down screws ➢ Lay down landing joint. 5. Circulate Completion Fluid ➢ Rig up to reverse circulate down the IA valve. ➢ Close the blind rams. ➢ Heat all seawater to 120°F. ➢ Reverse circulate the well with 620-bbl seawater w/MI KI-3869 corrosion inhibitor at maximum rate. 3000 psi max pressure. 6. Freeze Protect Wellbore ➢ RU jumper between the IA and the tubing. ➢ Reverse in 175-bbls diesel into inner annulus. Allow IA and tubing to U-tube for 1- hour. 7. Set TWC by opening the blind shear rams and dry rod in the TWC ➢ Verify there is no pressure underneath the blind shears by opening the choke. Test TWC from below by"rolling" the pumps to 1500 psi for 5-min. Confirm no flow past the TWC. ➢ Test TWC from above to 250-psi low/3,500-psi high for 5 minutes on both tests. Pass/Fail Criteria lb and 2b located in section 6. 8. ND BOP and NU Tree ➢ ND BOPE and NU 13-5/8" 5K x 7-1/16" 5K adapter flange and 7-1/16"dry hole tree ➢ Barriers for ND are the kill weight fluid and TWC. ➢ Test tubing hanger void and seals to 4,500-psi for 15 charted minutes. (Pass/Fail Criteria 1 b and 3a located in section 6.0) ➢ Perform a 5 minute 250 psi low/5,000 psi high visual leak tight test of the tree. ➢ Consider dressing BOPE for the next well. 9. Secure the tree and cellar. ➢ A revised schematic is attached for reference. • • pn2 gq-vzZ. Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, February 23, 2016 10:28 AM To: 'Mclaughlin, Sean M' Subject: RE: change to BOPJ on 09-07A(PTD 199-022, Sundry 315-710) Follow Up Flag: Follow up Flag Status: Flagged Sean, The change has been made to the approved PTD/Sundry. Please include this approval with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave ;SCANNEDAPR 2 J. 2016 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(aialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Mclaughlin, Sean M [mailto:Sean.McLaughlinftbp.com] Sent: Monday, February 22, 2016 7:36 AM To: Loepp, Victoria T(DOA) Cc: AK, D&C Rig 272 Well Site Leader Subject: change to BOPE on 09-07A(PTD 181-178, Sundry 315-710) Victoria, The workover on well 09-07 will be performed with Parker Rig 272. Over the weekend some BOP rams were swapped out and a revised BOPE schematic is attached. 3-1/2" x 6" Variable bore rams are not available for this equipment so a ram change will be made after pulling the tubing. An updated operation summary is below. Regards, Sean Operational overview: • MIRU Rig. Pull BPV, Circulate, Set TWC. ND tree. NU and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross and 5-1/2"fixed). • Pull 7"x 5-1/2"tubing from 8,920' MD. w,Ning test plug,test above and below. Change both rams to 2-7/8' x 5" VBR's 1 • • Set RBP,test casing, SettTTS, change out tubing spool and IC pack off • Fish TIW latch from packer. • Mill and retrieve packer from 8,951'. • Fish 3-1/2" liner • Mill liner and cement in 9-5/8"production casing to 9,350' ELMD. • Run 4-'/2" 12.6# l3Cr-85 VamTop tubing with HES TNT packer. • Set TWC. ND BOPE. NU and test tree. RDMO. Sean McLaughlin BP Workover Engineer 564-4387 Office 223-6784 Cell 2 dNCER1if0 _ _ _ ____ _ _ _ _ 2 ILS \11 40 _ __„. DS 9-7 �' Rotary Table Flow Line 2/21/2016 • All measurements are taken from the rig floor to the center of the element listed. am ^3- , --a•Qf , Bolted Cover Spherical'° Annular Preventer . =5/8"5k Cameron CIW 11.111.111111.1111.1 -.- a Ill Type U Double BOP S' I .1ammunin a Top Pipe Ramill - /$' k SBR Blin�Ihe R• Lar a Bore Bo is nd - �• Tandem Booster ; 1111 '; Blind Shear Rams lik Choke it ,41.1.1:114b, L.'1 X5/8°x 3-1/8' ,4 Kill _- II " CR 'raffle Mud • s ti 1 Mud Cross lnlllww "111111■ t3- 1 5/8"5k Cameron CIW 1 k TypeI P Bottom Pipe Ram I I Function Volumes(gallons) Annular Pre11;:4 - Open= 18.48 pose= 28.35 Pipe Rams 411 - Open= 5.5 Close= 5.8 IIIIIIIIIF: Blind-Shear Rams Open= 10.5 Close= 10.9 ow Bottom Pipe Rams r Open= 5.5 Close= 5.8 Mr' HCR Valves -g Open= 0.50 Close 0.50 Manual Choke and Kill Valves.require: YI-. ® Tubing Spool Lock Downs IA IS:. :R Casing Spool Lock Downs OA 1:-Z. :" �� 46.95 Ground Level LASKA 4 OF T� • • �w��\1%% s, THE STATE Alaska Oil and Gas � �,,; I, of//�� Conservation Commissi®n -itiC-=_ == 333 West Seventh Avenue � h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALASIQ' Fax: 907.276.7542 www.aogcc.alaska.gov Dave Bjork Engineering Team Lead BP Exploration(Alaska), Inc. 5CANNED JAN 2 9 2 'f O�� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-07A Sundry Number: 315-710 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0.1 --- Daniel T. Seamount, Jr. Commissioner rd DATED this?day of December, 2015 Encl. STATE OF ALASKA IDALASKA OIL AND GAS CONSERVATION COMM.N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations o Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing 0 Change Approved Program 0 Plug for Redrill p'. Perforate New Pool ❑ Re-enter Sti Well lit yet., Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc • 4. Current Well Class: 5. Permit to Drill Number 199-022 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development p. 6. API Number 50-029-20223-01-00 • 99519-6612 Stratigraphic ❑ Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? °r Will planned perforations require a spacing exception? Yes ❑ No II / PBU 09-07A - •� C t I V LI 9. Property Designation(Lease Number): 10. Field/Pools: NOV 2 0 2015 ADL 028327&028324 • PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY A�`/,-�) GCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(M): 10934. 9009 ' 10847 " 9002 - 2490 None 9719 Casing Length Size MD TVD Burst Collapse Structural Conductor 75 20" 35-111 35-111 1530 520 Surface 2740 13-3/8" 35-2775 35-2775 4930 2670 Intermediate 9216 9-5/8" 32-9248 32-8708 8150/6870 5080/4760 Production Liner 1929 3-1/2"x 3-3/16" 8918-10847 8403-9002 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9504-10840 / 8876-9002 7",26#x 5-1/2",17# 13Cr80 9063 Packers and SSSV Type: 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8961/8442 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch RI Exploratory 0 Stratigraphic ❑ Development p '- Service ❑ 14.Estimated Date for Commencing Operations: DE,—LE4A61421,2015 15. Well Status after proposed work: Oil ❑ WINJ 0 WDSPL ❑ Suspended RI ' , 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact McLaughlin,Sean M be deviated from without prior written approval. Email Sean.McLaughlin@bp.com Printed Name Dave Bjork / Title Engineering Team Lead // Signature Phone +1 907 564 5683 Date ///9,ph COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: �// 316 - 110 Plug Integrity ❑ BOP Test Sd Mechanical Integrity Test ❑ Location Clearance 0 Other: 3 ©C Ali;),. i3 P /(-,,,f--- Post -,.yfPost Initial Injection MIT Req'd? Yes❑ No 0 Spacing Exception Required? Yes 0 No IA// Subsequent Form Required: / 6 ._ y /�� Approved by: ,t % COMMISSIONER APPROVED BYTHE COMMISSION Date: 'Z / / iM R/23/6- c„,_e::„.?„, ,i 5 C! ORIGINAL o „ 1 RBDM$� � � DEC 072015 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,.......--S... ) / ' t/ ' • • bp Sundry Request for Plug and Re-entry Well: 09-07A Date: 10/28/2015 Engineer: Sean McLaughlin MASP: 2490 psi Well Type: Producer Q B'Z `` Estimated Start Date: January 2016 , iv 5 z History: 09-07A was side-tracked in 1999 and was a 100% on time producer throughpo7. In 2008 oil !jL production declined to the point the well was no longer competitive, and the well has been almost 100% shut-in since. The well is very high water rate. WSO and Ad-perf attempts have been made various times, but a restriction has been encountered 1 2' M that has made it impossible to do any work down hole near the perfs. Scope of Work: The RWO scope will be to remove the damaged liner and abandon all lower perfs (A wellbore). This should shut-off a considerable amount of water. Perfs will then be added through the 9- 5/8" intermediate casing (Parent bore) to get access to the MI benefit. Pre Rig Prep Work / r.� C 1 Perform injectivity test. Pump 40 bbls of 15.8 ppg cement to plug liner✓ �+�(— 3/Z De E r *�/'' C 2 Pick up on liner to verify it is free. Release and leave in place. F 3 CMIT-TxIA to 3,500 psi. MIT-OA to 1,200 psi E 4 If 3-1/2" liner is stuck,jet cut as deep as possible. E 5 Jet cut the 5-1/2"tubing as close to the 3-1/2" liner as possible but leaving at least 15' of liner stub above collar to fish. F 6 Circulate well with seawater and Diesel F/P to 2500'.Bleed TBG to—200 psi C 7 Hang 3-1/2" liner on the 5-1/2"tubing W 8 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage(check one at a time). PPPOT-T&IC. ✓ 9 Set TWC,ND Tree,NU Dry Hole Tree, PB I/A&upper 0/A valves F 10 Bleed WHP(s)to zero Proposed RWO Procedure: • MIRU Rig. ND tree. NU and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross and 3-1/2" x 6"VBR's). ( A • Pull 7"x 5-W tubing x 3-1/2" liner from -9,060' MD. • Fish TIW latch from packer. Mill and retrieve packer from 8,951'. • Mill liner and cement in 9-5/8" production casing to 9,350' ELMD. - r t ca.s;t. 7 • • Run 4-W 12.6# 13Cr-85 VamTop tubing with HES TNT packer. Po' • Set TWC. ND BOPE. NU and test tree. RDMO. Je.0 Get-c?�'i Post rig Work ✓ 1 ND dry hole tree, NU upper tree. Pull TWC. ND PB IA& OA valves. F 2 Assist Slickline: Circ well S 3 Circ well with completion fluid and FP. Drop Ball n Rod. Set TNT packer, MIT-T, MIT- IA. Set generic gas lift design. Pull ball n rod, pull RHC-M. E 4 Perforate per PE Wi atr- J Cotor • i hP welt itaf do rPed bebv IXg,1I2 �'' aq PIU y, rti'r welt for I'd 510101 5lwf l Qlkw f•- 114W +' CWr Ove' reCpverp fro' T�►' p001 . �O /�� cA rem" KB.ELEV= 54' O ppm. KOP El/ 3167' • 09-07)k 'L 70° 8. CHROME TBG"' Max Angle= 101 @ 10120' Datum M3= 9453' Datum ND= 8800'SS 1— 2051' H 7"X 5-1/2"XO,D=4.892" /—� 2102' 5-1/2"CAM SSSV,D=4.56" I LL P 7) 7"TBG,26#,13-CR-80,.0371 bpf,I0=6.184" H 2051' ST MD TVD DEV TYPE VLV LATCH FORT DATE 7 8819 8312 25 LB-SPM SO RM 24 04/20/06 6 8257 7800 26 LB-SPM DIN RA 0 lidi 5 7711 7308 26 LB-SPM DMY RA 0 13-3/8"CSG,72#,M-80,D=12.347" —{ 2740• 4 7157 6811 26 LB-SPM DMt' RA 0 3 6604 6315 26 LB-SPM DONE RM 16 05/05/06 Minimum ID =2.80" @ 9079' L 2 5951 5725 25 LB-SPM DM' RA 0 3-3/16" LINER 1 3948 3906 25 LB-SPM DONE RM 16 05/05/06 1 1 f 8888• H5-1/2"FES X NP,D=4.56" TOP OF 3-1/2"LNR --j 8917' ' 1 I 8917' H4-1/2"DEPLOY SLV,D=? S 8951' 1-19-5/8"X 5-1/2"11W I-BBP PKR I 1 9025' H5-1/2"FES X NP,D=4.56" BEHIND CT LNR I 1 9041' H5-1/2"FES X NP,D=4.45" 5-1/2"TBG,17#,13-CR-80,.0232 bpf,D=4.892" H 9053• —/ l 9053" H5-1/2"WLEG,D=4.892" H ELMD TT NOT LOGGED 3-1/2"LNR,8.8#,L-80,.0087 bpf,13=2.992" H 9079• . 9079• H3-1/2"X 3-3/16"XO,D=2.786" (.i__-f�) 4.4 9132'CTM H POSSIBLE LNR DAMAGE(TAGGED 11/06/05) ♦,,• ..,.,.y' ��1 WO X111111 111111 *1111111*1 4111 111/11111111 1,1 M LO4JI VWIJOW (09-07A) 9248'-9257' 111111111111'' 9-5/8"CSG,47#,MN-80,13=8.681" H 9658' 1----y 111111111111111 I 111111111 1111111111 PERFORATION SUMMARY l111111111111111111111 11116.11111 REF LOG:RESISTIVITY ON 04/23/991111 111111 s X1111111/11/1111111111 ANGLE AT TOP PERE:65 @ 9504' •!l44e44e•1. Note:Refer to Production 06 for historical perf data 9719' —)CEP 2.562" SIZE SPF INTERVAL Opn/Sgz DATE ` 2" 4 9504-9509 0 04/04/00 2" 4 9554-9564 0 04/03/00 2" 4 9590-9600 0 04/03/00 ` 2" 4 9654-9674 0 04/02/00 2" 4 9684-9704 0 04/02/00 2" 4 9788-9798 0 04/01/00 2" 6 9910-10135 0 04/25/99 3-3/16"LNR,6.2#,L-80, H 10845' 2" 6 10805-10840 0 04/25/99 .0087 bpf,D=2.786" TO H 10934• DATE REV BY COMMENTS DATE REV BY CONVENTS FRIAHOE BAY UNIT r 10/76 ORIGINAL COMPLETION 05/12/06 KSB/PAG GLV C/O(05!05/06) WELL 09-07A 11/18/94 LAST WORKOVBR 10/13/08 PJP/PJC FOSSBLELWR DAG 11/06/06 FEFMTN>: 1990220 04/27/99 SIDETRACK(09-07A) 03/18/10 JCMSV TRDP LOCKED OPEN(12/19/07) AH No: 50-029-20223-01 04/21/02 BCIKAK LINER CORRECTION SEC 2 T1ON R15E 1038.53 FEL 5193.89 FNL 09/18/02 /tlh LIVER CORRECTION 04/20/06 JGMPJC GLV C/0 BP Exploration(Alaska) I 12 B.ELEV= • 09-07B yj► NG E>70°@ 9478.. CHROME TBG"" KOP= 3167' Proposed RWO Max Angle= 101 @ 10120' Datum MD= 9453' Datum TVD= 8800'SS I • 2,700' -14-1/7"HFS'X'NP,D=3.813" 13-3/8"CSG,72#,M-80,ID=12.347" H 2740' ill - ' I 4 II II8909. H4-1/2"HES'X'NP,D=3.813" I Z1 g 8,941' —19-5/8"X 4-1/2"HES'TNT PKR ' , 8,960' —j4-1/2"HES'X'NP,D=3.813" ' , 9,015' —14-1/2"HES'Xt'I NP,ID=3.725" I 4-1/2"TBG,12.6,13-CR-85,VamTop,D=3.958" H 9,032' —/ \ 9,032' 1-14-112"WLEG,ID=3.958" post rig pert -1 9285-9295 I I cleanout to 9,350ft —I 9,351! ��M��fi�fi��1111�f'1 11111111111111111114 AAA a5M-csG,47#,n14.eo,0=61".66 -H fits' — j111110,2e21111111� 4''g o 7 t3 3-3/16"LNR,6.2#,L-80, —I 10845' .0087 bpf,ID=2.786' TD — 10934' / , DATE REV BY CO1vINE TS DATE REV BY CONVENTS FRWHOE BAY UNIT - 10176 ORIGINAL COMPLETION 05/12/06 KSB/PAG GLV GO(05/05/06) WELL 09-07A 11/18/94 LAST WORKOVB2 10/13/08 PJP/PJC POSSIBLE LNR DIv1G 11/06/06 FERMT No:1990220 04/27/99 SIDETRACI®(09-07A) 03/18/10 JCM'SV TRDP LOCKED OPEN(12/19/07) AR No: 50-029-20223-01 04/21/02 BGKAK LINER CORRECTION SEC 2 T1 ON R15E 1038.53 FEL 5193.89 RI_ 09/18/02 /tlh LINER CORRECTION 04/20/06 JGM'PJC GLV GO BP Exploration(Alaska) s u -I CI u u � � Am - O . o o CD = gN LO D N a: � m 9m Q K 0 ci i .'iir4 _ i iA , 41[LJII'IISI o hIhIhU 73 Z Z A I, ir / Ill/ /v c m m A• ■ ■ n F o O $ N O z cn m 1m u u zu m r N u w o pp O hIii1II5 \§I a II II O-N m os pE rg m C ;g o A,. 1 0 f- 33m yti D fill 2 _74 4miiimillmrsn •z 1— v, „_ c., _ D o� I- c c rI= 4 0• aio.m- „ —_ y �sn -- W v O0/11 (Q. pl- N � z� �� owl As o 0 II MEM' D hlj ■ r 1111 I]i 1 1 o000000 D o r n 7c W D C 13 W * 0 r D fArl o v m r b 6Q . \ m a r-Oi 0 u� cpm • 1.N ti N 8 31 k �sa w:1 II 0 NN u., i @ IT1 n• O 2 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or'Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both / copies of the Form 10-403 (AOGCC's and operator's copies). �/ /;1) 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia ` r Steve work) the initial reviewer will cross out that erroneous entry and initial it on 7. both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, ✓ then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for J.mi Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Je4R-i--ifikikJ.14- in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change .fie nt-' rkteci�'- the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. 1110 • PTD 14q - 'z z Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 10, 2015 9:28 AM To: Lastufka,Joseph N Cc: Loepp, Victoria T(DOA); Davies, Stephen F (DOA) Subject: (DS 9-07A re-drill to DS 9-07) PTD 199-022 Follow Up Flag: Follow up Flag Status: Flagged Joe, Here is what should happen to re-enter abandoned DS 9-07. 1. Will need to submit 10-403 to abandon lateral 9-07A(plug for redrill) 2. Submit 10-401 PTD to re-enter abandoned wellbore DS9-07 per 20 AAC 25.005(a) 3. The well will have a new PTD#and will have a -95 suffix on API. Nottotally sure what to call the well... a suggestion might be DS 09-07RE (for re-enter??) -that will flag it as unusual. Guy Schwartz Sr. Petroleum Engineer AOGCC SEP $ p 2016 907-301-4533 cell s`AMED 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Lastufka, Joseph N [mailto:Joseph.Lastufka@lbp.com] Sent: Wednesday, November 04, 2015 2:22 PM To: Schwartz, Guy L(DOA) Subject: FW: Attached Image Your thoughts are appreciated... Please let me know if you have any questions. Thanks! Joe From: ancp007@bp.com [mailto:ancp007@bp.com] Sent: Wednesday, November 04, 2015 3:20 PM To: Lastufka, Joseph N Subject: Attached Image XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project.. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages' Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Daretha~ Lowell Date: 2/_~' /si ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /s/ PG/A . 09-07A • • N90uo Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] � #//3 Friday, February 01, 1 \ Sent: y, y , 2013 8:39 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; AK, OPS EOC Specialists; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer; Arend, Jon Subject: OPERABLE: Producer 09 -07A (PTD #1990220) IAxOA Manageable by Bleeds All, Producer 09 -07A (PTD# 1990220) passed a PPPOT-IC confirming the integrity of the wellhead seals. An Outer Annulus Repressurization Test was performed from 01/19- 01/25/2013 with a build up rate of ^' 135 psi /day making the well manageable by bleeds. At this time the well has been reclassified as Operable and may remain on production. Regards, Laurie Climer SCANNED APR 2 3 3 BPXA Well Integrity Engineer 907 - 659 -5102 From: AK, D &C Well Integrity Coordinator Sent: Saturday, January 19, 2013 6:23 AM To: 'Schwartz, Guy L (DOA)' (quy.schwartz(&alaska.gov); 'jim.regg @alaska.gov'; AK, OPS FS OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Tea • ead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Op - ngr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; AK, OPS EOC Specialists; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer KD &CDHDWeIIIntegri(abo.com); Clingingsmith, Mike J; Ryan P Holt (Ryan.Holtftp.com) Subject: UNDER EVALUATION: Producer 09 -07A (PTD #1990220) Sus ned Casing Pressure Above MOASP All, Producer 09 -07A (PTD #1990220) has confirmed sustained o A casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/1980/1100 on 01/17/20 The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt • restore integrity. Plan forward: 1. DHD: Outer Annulus Repressurization est (DART) 2. Wellhead: Positive Pressure Packo est on Inner Casing (PPPOT -IC) A TIO plot and wellbore schematic hay: •een included for reference. Please call if you have any questio s or concerns. Thank you, Gerald Murphy 1 • • P66k b cr -0 7A, PNJ 1 19 oZz a Regg, James B (DOA) From:. AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 2�J� 1 f 5 Sent: Saturday, January 19, 2013 6:23 AM �� ``77 � To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; AK, OPS EOC Specialists; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AKD &CDHDWelllntegri @bp.com; Clingingsmith, Mike J; Ryan.Holt @bp.com Subject: UNDER EVALUATION: Producer 09 -07A (PTD #1990220) Sustained Casing Pressure Above MOASP Attachments: 09 -07A (PTD #1990220) TIO Plot.docx All, Producer 09 -07A (PTD #1990220) has confirmed sustained OIA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/1980/1100 on 01/17/2013. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: Outer Annulus Repressurization Test (OART) 2. Wellhead: Positive Pressure Packoff Test on Inner Casing (PPPOT -IC) A TIO plot and wellbore schematic have been included for reference. rub S c'CtF, �� c ct,p) Please call if you have any questions or concerns. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator SCANNED APR 11 2013 G VV Global Wells Organizatior WIC Office: 907.659.5102 WIC Email: AKDCWe1lIntecritvCoordinator (k.:BP.com 1 ti PBU 09 -07A PTD #1990220 1/19/2013 TIO Pressures Plot Weil: O O7 • 4.0(10 3.000 Tbg �. IA 2.000 - OA OOA OOOA On • 102012 1027112 1103112 11110/2 11,'1712 11/24112 12101112 1208/12 12/15112 12122112 12129!12 01/05113 01(1213 0119113 09-07 A (PTD # 1990220) Classified as Problem Well All, Well 09-07A (PTO #1990220) is capable of unassisted flow up the IA and has been classified as a Problem well. Wellhead pressures on 4/07/06 were 1730/2160/1150. We are currently evaluating the following plan: 1. SL: C/O OGLV 2. OHO: Re-TIFL Attached is a well bore schematic. Please call if you have any questions. «09-07 A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com ...d~.^~\t..'ç:G l\PH 1 ~ \i.,~""",f'~~, '\;~tp~ ~ Content-Description: 09-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/l0/2006 4:22 PM FMC GEN 1 CIW AXELSON 54' e 09-07 9453' 8800' S8 17" TBG, 26#, 13-CR-80, .0371 bpf,ID'-' 6.184" I ¡TOP OF 5-1/2" TBG I 113-3/8" CSG, 72#, Mo80, ID'-' 12.347" I Minimum ID :: 2.80" @ 9079' 3-3/16" UN ER ITOP OF 3-1/2" LNR 1 8917' 15-1/2" TBG. 17#, 13-CR-80, .0232 bpf, ID = 4.892" 9053' 13-1/2" LNR, 8.8#, L-80, .0087 bpf, ID = 2.992" I TOP OF 3-3/16" LNR I I 9-5/8" CSG, 47#, MN-80, ID'" 8.681" H 9658' ~ORATIONSUMMARY REF LOG: RESISTIVITY ON 04/23/99 ANGLE AT TOP PERF: 65 @ 9504' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9504 - 9509 0 04/04/00 2" 4 9554 - 9564 0 04103iOO 2" 4 9590 - 9600 0 04/03/00 2" 4 9654 - 9674 0 04/02/00 2" 4 9684 - 9704 0 04/02/00 2" 4 9788 - 9798 0 04/01/00 2" 6 9910 - 10135 0 04/25/99 2" 6 10805 - 10840 0 04/25/99 3-3/16" LNR, 6.2#, L-80, .0087 bpf, ID = 2.786" DATE 10/76 11/18/94 04/27/99 03/01/02 04/21/02 09/18/02 REV BY e SAFETY NOTES: CAUTION: H2S OVER 300 ppm. 700 @ 9478' AND 900 @ 9999' ***CHROM E TBG*** 2051' --{ 7" X 5-1/2" XO I 2102' --{ 5-1/2" CAM TRDP-1A SSSV, ID = 4.56" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3948 3906 25 LB-SPM DOME T2 16 01/19/05 2 5951 5725 25 LB-SPI\t DMY RA 3 6604 6315 26 LB-SPM DOME T2 16 01/19/05 4 7157 6811 26 LB-SPl\t1 DMY RA 5 7711 7308 26 LB-SPf\1 DMY RA 6 8257 7800 26 LB-SPM DMY RA 7 8819 8312 25 LB-SPf\1 SO T2 8888' 8917' 8951' 9025' 9041' 9053' 9079' COMMENTS GL V C/O RNlTP BC/KAK /tlh -1 5-1/2" HES X NIP, ID = 4.56" I -14-112" DEPLOYMENT SLEEVE -19-5/8" X 5-1/2" TIW HBBP PKR I -15-1/2" HES X NIP, ID = 4.56" I -15-1/2" HES X NIP, ID = 4.45" I -15-1/2" TUBING TAIL WLEG I H ELMD TT NOT LOGGED I --{ 3-1/2" X 3-3/16" XO I MILLOUT WINDOW 9257' 9719' --{ CIBP 2.562" I PRUDHOE SA Y UNIT WELL: 09-07 A PERMIT No: 1990220 API No: 50-029-20223-01 SEC 2 T10N R15E 1038.53 FEL 5193,89 FNL BP Exploration (Alaska) 199-022-0 PRUDHOE BAY UNIT 09-07A 50- 029-20223-01 Roll #1: Start: Stop MD 10934 TYD 09009 Roll #2: St~arf Stop Completion Da .1~r~4127/99 Completed Status: 1-OIL BP EXPLORATION ()m^s~,~) r~c Current: T Name- Interval c 9686 I SCHLUM RST D 914(~~ I PDS INDUCTION D 9290 J I BH GR L GR-MD ~F~IAL 9264-10932 L GR-TVD ~.~hhXFAL 8642-8953 L INDUCTION ~AL 8900-10935 L RST ~ 8800-11830 R SRVY LSTNG ~I~0.-10931 Sent Received T/C/D : CH 7/17/00 7/19/00 OH 5/5/99 5/5/99 OH 9/1/99 9/7/99 OH 9/1/99 9/7/99 OH 9/1/99 9/7/99 OH 5/5/99 5/5/99 CH 5 7/17/00 7/19/00 OH 5/12/99 5/12/99 Wednesday, March 28, 2001 Page 1 of 1 Schlumberger NO. 344 7/17/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-i'N: 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 Color CD D.S. 2-3A 20285 SCMT 000627 1 D.S. 9-07A 20102 RST ~ ~'~;,g to 000225 1 1 1 ,, ~ f"~ ~"' r" 1% ~ ~ KbLblVbU SIGNED .~_ DATE: JUL 3 9 2000 Alaska 0ii & 6as rco~is. ~u~Im~ssi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you, r .. STATE OF ALASKA :-: ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 54 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3346' FNL, 47' FEL, Sec. 2, T10N, R15E, UM (asp's 718315, 5943399) 09-07A At top of productive interval 9. Permit number / approval number 910' FNL, 1541' FEL, Sec.2, T10N, R15E, UM (asp's 716750.5, 5945792) 199-022 At effective depth 10. APl number 50-029-20223-01 At total depth 11. Field / Pool 5194' FNL, 1039' FEL, Sec. 35, T11 N, R15E, UM (asp's 717224, 5946800) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10934 feet Plugs (measured) PBTD Tagged @ 10847' MD on 4/26/1999. true vertical 9009 feet Effective depth: measured 10847 feet Junk (measured) 0 ~' true vertical 9002 feet [ {-,~ l [ ~ Casing Length Size Cemented Measured Depth True vertical Depth Conductor 71' 20" 300 Sx AS 71' 71' Surface 2723' 13-3/8" 6700 Sx AS 2777' 2777' Production 9194' 9-5/8" lOOO Sx Class G & 300 Sx AS 9248' 8708' Liner 1929' 3-3/16" 16 bbls 15.6 ppg LARC 10847' 9002' Perforation depth: measured 9504' - 9509'; 9554' - 9564'; 9590' - 9600'; 9654' - 9674'; 9684' - 9704'; 9788' - 9798'; 9910'- 10135'; 10805'- 10835'. true vertical 8876' - 8878'; 8892' - 8896'; 8904' - 8908'; 8929' - 8937'; 8941' - 8948'; 8977' - 8980'. 9011' - 9007'; 8999' - 9001' "' Tubing (size, grade, and measured depth) 7", 26#, 13CR-80 Tbg @ 2051' MD; 5-1/2", 17#, 13CR-80 Tbg @ 9053' MD. .. Packers & SSSV (type & measured depth> 9-5,8" X 5-1,2" TIW HBBP PACKER @ 8951' MD.APR_2 02000 5-1/2" CAMCO TRDP-1A SSSV @ 2102' MD. 13. Stimulation or cement squeeze summary AJa~ki~ 0i! & Gas Cons. Commission Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 111 1257 3907 - 268 Subsequent to operation 393 2740 9534 - 307 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 "~1~ '~. ~ Title ARCO EngineeringSupervisor Date Zo Z Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-07A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/01/2000 - 4/04/2000: MIRU CTU#3. PT'd equip to 4000 psi. RIH w/ CT nozzle & tagged liner top for tie-in to logs. POOH. RIH w/Coiled Tubing conveyed 2" carriers & shot 75' of Add Perforations as follows: 9504' - 9509' MD (Zone 2B) Reference Log: PDS 4/23/1999. 9554'- 9564' MD (Zone 2B) 9590'- 9600' MD (Zone 2B) 9654' - 9674' MD (Zone 2A) 9684' - 9704' MD (Zone 2A) 9788' - 9798' MD (Zone lB) All shots @ 4 SPF, random orientation, balanced pressure & 60° phasing. POOH w/TCP guns. ASF. RD CTU. Brought well BOL. Placed 09-07A on production & obtained a valid welltest. Page 1 APR 20 2.000 ~_~ ~! ~ ~as ~5o,ns. Commission ~ch0rage STATE OF ALASKA ALASi~,/~ OIL AND GAS CONSERVATION COMMTsSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Servi~_~ Oil ~ Gas ~ Suspended ~ ~andonod ~ Se~i~ ~ 2. Name of Operator 7. *e~it Number '"(L.:*; "~. ARCO Alaska, Inc. 99-2~,,, ¢,~/ P. O. Box 100360, Anchorage, AK 99510-0360 50-029-20223-~-~-~n~ 4. Location ol well at sudace -' : ................ 9. Unit or Lea~ Na~¢¢C~o~ ' Prudhoe Bay Unit AtTop Producing Inte~al ~~~~ ..... ~' 10. Well Number 910' FNL, 1541' FEL, SEC 02, T10N, R15E, UM ¢~ ~_~ ..... '~:~ 09-07A At Total Depth j .~_~_ ~ ~. [ 11. Field and Pool 5196' FNL, 1039' FEL, SEC 35, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial~L~ RKB 54 feet~ ADL 28324 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or ~and. ~15. Water Depth, if offshore 16. No. of Completions April 11, 1999 April 23, 1999 April 27, 1999 ~ N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thic~e~ of Permafrost 10934' MD /9009' ~D 10847' MD /9002' ~D YES ~ No ~~ 2102' feet MD 1900' (approx) 22. T~e Electric or Other Logs Run Resistivi~, GR, CCL, Tamp Logs, MWD. 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 20" 94¢ H-40 Surface 70.5" 30" 3o0 Sx AS 13-3/8" 72¢ N-80 S u rfa~ 2~ 17-1/2" 6700 Sx AS 9-5/8" 47¢ N-80 Surfa~ 9248' 12-1/4" 1000 Sx Cla~ G & 3OO Sx AS 3-3/16" 6.2¢ L-80 8918' 10847' 4-1/8" 16 bbls of 15.6 p~ ~RC 24. Pedorations open to Production (MD + TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 2051' 8951' 5-1/2" 9053' 9910' - 10135' MD; 9011' -9007' ~D; ~ 6 SPF 10805' - 10835' MD; 89~' - 9001' ~D; ~ 6 SPF 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Su mmaw for details) Data First ~roduction Uethod ol Oporation (Flowing, ~as Ii,, otc.) I ~ I ~ I Dato o~ lost Hours lostod ~roduct~on ~or OIk-BBk ~S-MCF ~I[~-BBk GHOK~ SIZ[ I~s-olk ~TIO Flow lubino Gasin~ ~rossuro Calculated OIk-BBk ~S-MGF W~Tfi~-BBk OIk G~VI~ - A~l {co~) ~ro~. 272 psi 24-Hour Bate > 455 17~7 ~4 28. GO~[ Briel doscfiption oI Iilholo~, pomsi~, ~ractums, ~pamnt dips and pmsson~ ol o~1, Oas or wator. Submit coro chips. ~ /h~s 10-407 is submittod as ~iroclod pot ~o 10-401 form approvo0 March ~7, 1~ (~ormit ~-22) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Sadlerochit Top of Zone lB Top of Zone lA GEOLOGIC MARKERS MEAS. DEPTH 9222' TRUE VERT. DEPTH 8684' 8978' 9791' 9963' 8933' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Fr ~aaka OJJ'& Gas 0or~s~ Anchorage 31. LIST OF A'I-rACHMENTS Summary of 09-07A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. 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. Item 28: If no cores taken, indicate "none". Form 10-407 09-07A DESCRIPTION OF WORK COMPLETED ...... COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 4/10/1999: 4/11/1999: 4/12/1999: 4/13/1999: 4/14/1999: 4/15/1999: 4/16/1999: 4/17/1999: 4/18/1999: 4/19/1999: 4/20/1999: 4/21/1999: 4/22/1999: 4/23/1999: 4/24/1999: 4/25/1999: 4/26/1999: 4/27/1999: MIRU CTU. Tested BOPE. RIH & milled pilot hole to 9243' MD. POOH w/BHA. RIH w/window mill. Time milled window to 9247.5' MD. Milled window to 9249' MD & POOH. RIH & milled window to 9252.7' MD. POOH. RIH & completed window. TOW=9248' & BOW = 9257'. Reamed window & POOH. RIH w/ bi-centered bit & drilled to 9291' Performed LOT to EMW of 9.2 ppg. Drilled to 9303'. POOH w/BHA. RIH w/Tri-cone Bit & reamed to BTM. Drilled to 9415' & POOH w/BHA. Performed CTU maintenance. RIH & drilled to 9430' MD. POOH. RIH & drilled to 9779'. POOH & PT'd BOPE. RIH & reamed to BTM. Drilled to 9958' & POOH. RIH & disconnect parted. BHA left in hole as fish. POOH. RIH & latched fish @ 9334'. POOH w/fish. RIH & tagged BTM @ 9391'. Lost 500 psi. POOH. Disconnect sheared again, leaving motor, orienter, & bit in hole as fish. RIH w/ fishing tools and recovered fish from wellbore. RIH & drilled f/9958' to 10026' MD. POOH. RIH & drilled to 10135'. Circulated new mud. Drilled to 10571' w/periodic short trips to window. Drilled to 10584' & POOH. RIH & drilled to 10807' MD. PUH to window. Circulated new mud. RIH & drilled to TD @ 10934'. POOH w/BHA. RIH w/logging tools. Ran Resistivity, GR, CCL, & Temp logs. POOH w/logging tools. MU 3-1/16" liner. RIH w/ liner & landed it @ 10847'. TOL = 8918'. Released f/liner & prep'd for cement task. Pumped 16 bbls of 15.6 ppg LARC to cement liner in place. Plug did not bump. Unstung f/ liner. Contaminated Cement w/Biozan & cleaned out wellbore. POOH while displacing wellbore to KCL Water. RIH & cleaned liner to 10814'. Milled landing collar & float collar. POOH w/BHA. PT'd BOPE to 4000 psi. Tested liner lap to 2000 psi - lost 270 lbs in 30 min. RIH w/2" perf guns & shot 255' of initial perforations @: 9910'- 110135' MD (Zone lB) 10805' - 10835' MD (Zone lB) Shot all Perfs @ 6 SPF. Tagged PBTD @ 10847'. POOH w/guns. ASF. FP well. RDMOL. Rig released @ 1800 hrs. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page I 7800 8000 8200 8400 8600 8800 9000 AP CO Alaska, Inc. Structure : D.S. 9 Field : Prudhoe Boy Well : 09-07A, 50-029-20223-01 Location : North Slope, Alaska <- West (feet) 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 I I I f I I I I I I I I t I I I I I I I I I I I I I I I I I I I I RECEIVED & Gas Cons, Commission 9-07ihs Projected to TD Io,-o,,I o o~,,, · 9-07ehs · 9-07bhs Projected to TD OR 9200 I I I I I I i I i I I I I I t I I I I I I I I i I I i I I I i I I I 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 Vertical Section (feet) -> Azimuth 9.00 with reference 0.00 S, 0.00 E from 9-07 GINA,L 4000 3800 3600 3400 3200 3000 2800 2600 24O0 2200 20O0 1800 16OO Created bi planner Date plotted: 11-May-gg Plot Reference Is 9-07A. Cc~rdinatee are in feet reference g-07. rue Vortical Depthm ore reference rkb - MSL - 54ft. --- Baker Hughel INI£G --- ARCO ALaska, Inc. D.S. 9 09-07A 9-07 Prudhoe Bay North SLope, ALaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 9-07A Our ref : svy135 License : 50-029-20223-01 Date printed : lO-May-99 Date created : lO-May-99 Last revised : lO-May-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 718421.270,5941468.860,999.00000,N Slot location is n?O 14 52.613,w148 14 10.147 Slot Grid coordinates are N 5943399.190, E 718315.080 Slot local coordinates are 1932.68 N 50.21 ~ Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 9,09-07A Prudhoe Bay,North SLope, ALaska Measured [nc[in Azimuth Subsea Depth Degrees Degrees Depth RECTANGULAR COOED[NATES 9220.00 21.50 330.00 8628.41 1984.33N 1496.18W 9243.00 21.30 330.30 8649.82 1991.61N 1500.36W 9299.00 32.60 336.90 8699.67 2014.40N 1511.35W 9329.00 39.00 352.50 8724.04 2031~25N 1515.7714 9361.00 45.70 351.40 8747.68 2052.58N 1518.80W SURVEY LISTING Page 1 Your ref : 9-07A Last revised : lO-May-99 Dogleg Vert G R [ D C 0 0 R O S Deg/lOOft Sect Easting Northing 0.59 1725.85 716762.10 5945339.25 0.99 1732.38 716757.72 5945346.40 20.84 1753.17 716746.06 5945368.86 37.01 1769.12 716741.16 5945385.57 21.06 1789.71 716737.51 5945406.80 9392.00 52.90 353.40 8767.88 2075.86N 1521.88~ 23.73 1812.22 9431.00 59.50 349.60 8789.57 2107.88N 1526.71~ 18.76 1843.09 9478.00 65.10 0.50 8811.46 2149.24N 1530.1914 23.72 1883.40 9545.00 72.50 7.70 8835.70 2211.44N 1525.63~ 14.90 1945.55 9588.00 69.50 12.80 8849.70 2251.43N 1518.42W 13.21 1986.18 9622.00 65.90 19.70 8862.62 2281.61N 1509.65W 21.55 2017.36 9653.00 66.90 9.20 8875.06 2309.07N 1502.58~ 31.20 2045.59 9699.00 70.50 354.00 8891.85 2351.75N 1501.46~ 31.75 2087.91 9748.00 68.00 7.70 8909.28 2397.42N 1500.83~ 26.63 2133.13 9794.00 71.50 12.20 8925.21 2439.91N 1493.35W 11.92 2176.26 716733.76 5945429.98 716728.00 5945461.85 716723.33 5945503.09 716726.08 5945565.40 716732.13 5945605.58 716740.03 5945636.00 716746.29 5945663.65 716746.18 5945706.34 716745.49 5945752.01 716751.72 5945794.69 9829.00 72.90 13.60 8935.91 2472.39N 1485.91W 5.52 2209.50 716758.22 5945827.37 9868.00 74.90 16.60 8946.72 2508.56N 1476.15W 9.00 2246.75 716766.93 5945863.81 9915.00 76.70 15.30 8958.25 2552.37N 1463.63~ 4.68 2291.98 716778.18 5945907.96 9964.00 79.50 18.30 8968.36 2598.25N 1449.7714 8.28 2339.47 716790.70 5945954.23 9999.00 87.60 12.90 8972.29 2631.71N 1440.44~ 27.75 2373.98 716799.06 5945987.94 10033.00 98.60 9.30 8970.45 2664.97N 1433.91W 34.03 2407.85 716804.62 5946021.37 10068.00 99.50 9.90 8964.95 2699.05N 1428.15W 3.08 2442.41 716809.39 5946055.60 10120.00 101.40 17.50 8955.50 2748.70N 1416.06~ 14.83 2493.33 716820.04 5946105.58 10165.00 97.20 27.50 8948.21 2789.65N 1399.07~/ 23.83 2536.44 716835.83 5946147.00 10201.00 95.80 28.50 8944.14 2821.23N 1382.2714 4.77 2570.26 716851.70 5946179.06 10246.00 95.90 36.10 8939.55 2859.04N 1358.3714 16.80 2611.35 716874.50 5946217.54 10300.00 91.00 36.60 8936.30 2902.44N 1326.43~ 9.12 2659.21 716905.17 5946261.85 10338.00 92.30 49.00 8935.20 2930.26N 1300.68W 32.80 2690.71 716930.11 5946290.40 10379.00 96.10 45.90 8932.20 2957.90N 1270.56W 11.95 2722.72 716959.41 5946318.90 10410.00 97.20 42.00 8928.60 2980.06N 1249.19~ 12.99 2747.95 716980.12 5946341.67 10447.00 97.10 40.70 8924.00 3007.62N 1224.94~ 3.50 2778.97 717003.56 5946369.92 10481.00 90.10 37.30 8921.86 3033.97N 1203.60~ 22.88 2808.33 717024.13 5946396.88 10521.00 87.60 36.90 8922.67 3065.87N 1179.48~ 6.33 2843.61 717047.31 5946429.45 10560.00 87.70 36.80 8924.27 3097.05N 1156.11W 0.36 2878.06 717069.77 5946461.30 10595.00 87.60 32.80 8925.70 3125.76N 1136.16W 11.42 2909.54 717088.88 5946490.57 10635.00 84.20 30,70 8928.56 3159.68N 1115.17~ 9.98 2946.33 717108.88 5946525.08 10684.00 83.30 29.60 8933.90 3201.80N 1090.70W 2.89 2991.75 717132.11 5946567.89 10720.00 85.30 24.70 8937.47 3233.66N 1074.37i4 14.64 3025.78 717147.52 5946600.22 10776.00 85.10 23.50 8942.16 3284.60N 1051.58~ 2.17 3079.66 717168.82 5946651.79 10818.00 84.80 23.90 8945.86 3322.91N 1034.76~ 1.19 3120.12 717184.52 5946690.57 10865.00 85.60 20.60 8949.79 3366.25N 1017.03~ 7.20 3165.71 717200.98 5946734.40 10908.00 85.50 20.90 8953.13 3406.34N 1001.84~ 0.73 3207.68 717215.00 5946774.91 10931.00 85.00 20.00 8955.03 3427.81N 993.84~ 4.46 3230.14 717222.39 5946796.61 All data in feet un[ess otherwise stated. Calculation uses minimum curvature method. Coordinates from 9-07 and TVDss from rkb - MSL = 54ft. Bottom hole distance is 3568.98 on azimuth 343.83 degrees from wellhead. Vertical section is from wellhead on azimuth 9.00 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. 9,09-07A Prudhoe Bay,North Stope, ALaska SURVEY LISTING Page 2 Your ref : 9-07A Last revised : lO-May-99 Co~ents in we[Lpath ND TVDss Rectangular Coords. Co~ent 9220.00 8628.41 1984.33N 1496.18W Tie on 10931.00 8955.03 3427.81N 993.84W Projected to TD Targets associated with this weLLpath Target name Geographic Location TVDss Rectangular Coordinates Revised 9-07ihs 716983.000,5946382.000,~.00 8910.00 3020.29N 1245.15W 5-Mar-99 9-07ehs 717062.000,5946924.000,999.00 8955.00 5559.80N 1150.47Y 2-Mar-99 9-07bbs 71684~.000,5945910.000,999.00 8970.00 2552.53N 1398.77W 2-Mar-99 TRANSMITTAL. ProActive Diagnostic Services, Inc. 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: Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG DIGITAL MYLAR / BLUE WELL A~\v~O DATE TYPE DATA SEPIA FILM L~NE © ~- ~ PRINT(S) Ci- C',,~' o- ~'~- ~ 5- ~ c~ Open Hole 1 1 1 Res. Eval. CH i I I ProActive Diagnostic Services, Inc., l'qA-¥ i-; 5 1999 Date: Alast(a Oil & Gas Cons. C~mimion Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Pouch 340112, Pruclhoe Bay, AK 99734 Website: www.memorylog.com C:kMy DocumentskExcel_Word_DocumentskDistribution_FormskArco_pb_form.do, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Robert Christenson;/~ Chairman Blair Wondzell, P. I. Supervisor DATE: April 1 6, 1999 FILE ,,NO: af81dpgf.doc FROM: John H Spaulding~ SUBJECT: Petroleum InspeCFor BOPE Test Nabors / Dowell CTD ARCO, PBU, 9-07a PTD 99-22 April 16, 1999: I witnessed the BOPE Test on the Nabors / Dowell coiled tubing drilling unit located on ARCO's PBU drillsiite 9 well 7a. The AOGCC BOPE test report is attached for reference. The test went well with no failures observed. Roger Smith the operator did an excellent job of testing and was quite enjoyable to work with. SUMMARY: I witnessed the BOPE Test on; Nabors / Dowell CTD, 0 failures, 3.5 hrs. test time Not Confidential Attachment: afSIdpgf.xls STATE OF ALASKA .... OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors 3S / Dowefl Operator: ARCO Well Name: 9o07a Casing Size: Set @ Test: Initial Weekly DATE: Rig No. 3S PTD # 99-22 Rig Ph.# Rep.: Rig Rep.: Location: Sec. X Other TEST DATA 4/16/99 Paul Haynes 2 T. 10N R. 15E Meridian Urn/at BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 250/3500 P 250/3500 P 250/3500 P 25O/350O P 1 1 1 1 250/3500 P 1 250/3500 P 1 250/3500 P 1 250/3500 P 2 250/3500 P 1 250/350o P 1 250/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan. Pressure P/F 250/3500 P 250/3500 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@2000 avg. Functioned Functioned P MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank ok ok Location Gen.: ok Pit Level Indicators ok ok Housekeeping: ok Meth Gas Detector ok ok Permit to drill: ok H2S Gas Detector ok ok Standing Order Posted ok 3,150 P 1,800 P X minutes 9 sec. minutes 45 sec. Remote: X Psig. Well Sign ok Drl. Rig ok Hazard Sec. ok TESTRESULTS: :: : : : Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 7 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES x NO 24 HOUR NOTICE GIVEN YES x NO Waived By: Witnessed By: John H. Spaulding Form Revised 2/20/97 L.G. af81dpgf.xls 4/21199 TONY KNOWLE$, GOVERNOR ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 16, 1999 Bruce E. Smith, P.E. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 09-07A ARCO Alaska, Inc. Permit No: 99-022 Sur Loc: 3346'FNL, 47'FEL Sec. 02, T10N, RI5E, UM Btmhole Loc. 339'FNL. 767'FEL? Sec. 02, T10N, RI5E, UM Dear Mr. Smith: Enclosed is thc approved application for permit to rcdrill thc above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to v,:itness a test of BOPE installed prior to drilling new hole. Notice ma.,,' be given by contacting thc Commission pctrolcum ficld inspector on thc North Slope pager at 659-3607. Robert N. lristcnson, P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. ~ _~ STATE OF ALASKA ~_~, ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill D Redril, [] I ,b. Type of well. Exploratory D Stratigraphic Test D Development Oil [] Re-entry III Deepen DI Service Development Gas D Single Zone I~l Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 54 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28327 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 3346' FNL, 47' FEL, SEC. 02, T10N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1362' FNL, 1544' FEL, SEC. 02, T10N, R15E, UM 09-07A #U-630610 At total depth 9. Approximate spud date Amount 339' FNL, 767' FEL, Sec 02, T10N, R15E, UM March 18, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I-VD) feetI No Close Approach feet 10685' MD /9014' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AA¢ 25.035 (e)(2)) KickolI depth: 9240' MD Maximum hole angle 91 o Maximum surface 2600 psig At total depth (TVD) 3500 psis! @ 8800' 18. Casing program Settin~ Depth size Specifications Top Bottom Quantib,/of Cement Hole Casin~t Wei~lht Grade Couplin~l Len~h MD TVD MD TVD /include stage datat 4-1/8" 3-3/16" 6.2 L-80 TCII 1685' 9000' 8425' 10685' 9014' 18 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9720 feet Plugs (measured) PBTD tagged @ 9329' MD (9/08/1998) tmevertical 9150feet 0 R I C I ~iAL Effective Depth: measured 9329 feet Junk (measured) tree vertical 8784 feet Casing Length Size Cemented ? } ;" : · ~ , . = .-Measured depth True Vertical depth Surface 2723' 13-3/8" 6700 Sx AS 2777' 2777' Production 9637' 9-5/8" 1000SxClassG&300SxAS ii"i i'.: ii!i.;'i.!~ 9691' 9123' Perforation depth: measured 9254' - 9274'; 9282' - 9348'; 9398' - 9408'; 9424' - 9429'; 9437' - 9446'; 9453' - 9458'; 9466'- 9472'; 9480' - 9509'; 9528' - 9534'; 9539' - 9564'. tme vertical 8714' - 8732'; 8740' - 8802'; 8848'- 8858'; 8872'- 8877'; 8885' - 8893'; 8899'- 8904'; 8911'- 8917'; 8924' - 8951'; 8969' - 8975'; 8980' - 9003'. 20. Attachments Filing fee ~ Property Plat ~] BOP Sketch ~] Diverter Sketch ~] Drilling program L~ Drilling fluid program Time vs depth plot [~ Refraction analysis D Seabed report [~ 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Stephen Ward @ 265-1305. Signed (~~ ~.~~ 'l'itle: AAI Coil Tubing Ddlling Supervisor Date ',~/'~bv~l~lRf2634990 Bruce E. Smith, P.E. '"~)~'~ Prepare /)?t-'au au - Commission Use Onl~ Perm, Number I ^~'n,m~e~ I ~rov~'e Isee c°ver letter ~ - ~_ ...~, 5o-~.2. ~-.. ,,% ~ ~.. 2.. ~' - ~ ! ~ -- / ? -- ~' ~ Ifor other requirements Conditions of approval Samples required I~l Yes i~ No Mud log required U Yes ~ No Hydrogen sullide measures ~ Yes D No Directional survey required I~ Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 10M;D {1~3500psifOrCTU Other: .JFIlGINAL SIGNED BY by order of / ? Approved by :~obert N. Christens0n Commissioner the commission Date ~ "~ / / Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 9-07A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate and produce. Intended Procedure: Cement squeeze and plugback the existing completion to - 9210' md. Mill window in 9-5/8" casing at -9240' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. Directionally drill 4.125" x 1700' horizontal well to access Lower Romeo reserves. Build angle to -90° at TD. · Run and cement 3-3/16" liner to TD. · Perforate selected intervals. ° Place well on production. NOTE: Drill cuttings will be disposed of at CC2A and drilling mud will be disposed at Pad 3. March 4, 1999 Tubing 5-1/2" X Nipple 4.562" ID 8888' Packer 8951' 5-1/2" TT @ 9053' DS 9-07A Proposed CT Sidetrack Horizontal 2051' 5-1/2" BaI-O SSSV Nipple ID = 4.562" 5-1/2" Tubing 5-1/2" X Nipple @ 9025' ID- 4.562" 5-1/2" XN Nipple @ 9041' ID 4.455" Top of 3-3/16" Liner in 5-1 " Tbg tail Initial Perfs- 1000' 9-5/8" Casing shoe @ 9658' Window cut in 9-5/8" at ~ -9240 - 9245' / 3-3/16" liner 4.125" Open hole Current perforations cement squeezed TD @ - 11685' 1 ARCO Alaska, Inc. Slmelure : ID.S. !t Field · Prudt~oe Bay lot: 9-07 No~th Slope, Alaska <- west IN'rlg I~CO 1.rOD I~[X} I~,DD 141210 13;DD 12(X:, IIDD 1CCO gCX:' BDD TOD 6oa 50{3 I I i I I I ! II I i I i I I I i I i I I I I I I I I I [ 5, - ~§01,3g T~d, 2 1BIJ55 U. 1504,04 W \'\'~{~2. ~0,a - §O4B,~g ltd, 1991,621 I~L 1500.~5 W 'I'.IX & E~= or BuflrJ - 6~60,00 ';vd, 30(~,l;~0 ~ T21,~ W g- D.ret,.: 9-6 re~ 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 I i I ~ aaa 7~ aaa ~ 1~ I 1oo 1~ 1~ qaDD ~ q6DD I ~ qBDD I~ 2DDD Vedical Section (feet) -> A=lmu}h 3~.$~ ~l~h reEeren~e 0.00 S. 0.00 E From 9-07 2~ 260. Z 2~ ]~~ Proposal Calculations B~G~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Alaska, Inc, Rig: CDR - Nabors/Trans Job No: Well: 9-07A Version #12 Field: Prudhoe Bay, Alask~ AFE No: Calculation Method Minimum Curvatur Mag. Declination: API No: Vertical Sect. Plane: 38.550 TRUE Grid Correction 1.660 BHI Rep: Vertical Sect. Plane: 36.890 GRID Total Correction Job Start Date: Measured Depth from RKB Dip: Job End Date: True Vertical Depth Sea level RKB Height: 54.00 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi, TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Conm~ent~, (de~) (de~) (de~) (ft) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) (°/100ft) (°/100ft) (°/100ft) 9220.00 21.50 330.00 328,34 8628,41 1984,33 -1496,18 5945339.25 716762.10 1940,06 -1552,98 0,00 143.00 619,46 0.00 0.00 1. Tie in Positon 9243,00 21,31 330,38 328,72 8649,82 1991,61 -1500.35 5945346,41 716757,72 1947,22 -1557.36 1,02 31.00 622,56 -0.83 1,65 2. Kick off Point 9245.00 21.81 331121 329.55 8651,68 1992,25 -1500,71 5945347,04 716757,34 1947.85 -1557.74 29.38 30.00 622,83 25.00 41,50 9270.00 28.36 339.13 337,47 8674.32 2001,89 -1505,07 5945356.54 716752.71 1957.35 -1562,37 29,38 23.00 627,65 26.20 31.68 9295,00 35,20 344,23 342,57 8695,56 2014,39 -1509.15 5945368,92 716748.27 1969,73 -1566,81 29,38 19.00 634,89 27,36 20.40 9300,00 36,59 345,05 343.39 8699.61 2017,21 -1509.92 5945371,72 716747,41 1972,53 -1567.67 29.38 18.00 636.61 27,80 16,40 9320.00 42.19 347,84 346.18 8715.07 2029,55 -1512,88 5945383.96 716744,10 1984.77 -1570.98 29.38 16,00 644,42 28.00 13,95 9345,00 49.27 350.58 348,92 8732.51 2047.12 -1516,20 5945401.44 716740.27 2002.25 -1574,81 29,38 14,00 656,09 28.32 10.96 9350,00 50,69 351,05 349,39 8735,72 2050,90 -1516.81 5945405,20 716739.55 2006,01 -1575,53 29,38 14.00 658.67 28,40 9,40 9370,00 56,40 352,79 351,13 8747,60 2066,82 -1519.06 5945421,05 716736,83 2021,86 -1578.25 29.38 13.00 669.71 28,55 8,70 9395,00 63.56 354.66 353.00 8760.10 2088,33 -1521,42 5945442.47 716733.86 2043.28 -1581,22 29.38 12.00 685,061 28.64 7.48 9400.00 65.00 355.00 353.34 8762.27 2092.81 -1521,82 5945446.94 716733.33 2047.75 -1581.75 29,38 86,00 688.32 28,80 6.80 9420,00 65.47 1,57 -0.09 8770,66 2110,95 -1522.36 5945465,06 716732,26 2065,87 -1582,82 29.91 84.00 702.17 2,35 32,85 9445,00 66,44 9,69 8.03 8780.86 2133,65 -1520.12 5945487,81 716733,84 2088,62 -1581.24 29.91 80,00 721,31 3.88 32.48 9470.00 67.83 17.66 16,00 8790.58 2156.00 -1514,67 5945510.31 716738.64 2111.12 -1576,44 29,91 77,00 742.19 5,56 31,88 9495,00 69.60 25,46 23,80 8799.67 2177.64 -1506.11 5945532,19 716746.57 2133,00 -1568,51 29.91 74.00 764.45 7,08 31,20 9500,00 70,00 27.00: 25.34 8801.40 2181,85 -1504,04 5945536,46 716748,52 2137,27 -1566.56 29.91 147.00 769,04 8.00 30.80 3. DLS change 9520.00 68.24 28.22 26,56 8808.53 2198.41 -1495,38 5945553.26 716756.70 2154.07 -1558,38 10.49 146,00 787.38 -8.80 6,10 9545.00 66.05 29.79 28.13 88i8.24 2218.56 -1484.2i 5945573.72 716767.28 2174,53 -1547,80 10.49 146,00 810.10 -8.76 6,28 9570.00 63.88 31.41 29.75 8828.82 2238.05 -1472.69 5945593.55 716778.24 2194.36 -1536.84 10.49 145.00 832,53 -8,68 6.48 9595.00 61.73 33.10 31.44 8840.24 2256.86 -1460.82 5945612.69 716789.55 2213.50 -1525.53 10.49 144.00 854.63 -8.60 6.76 9600.00 61.30 33.44 31.78 8842.63 2260.53 -1458.41 5945616.43 716791.85 2217.24 -1523.23 10.49 144.00 859.01 -8.60 6.80 9620.00 59.60 34.85 33.19 8852.49 2274.93 -1448.65 5945631.10 716801.19 2231.91 -1513.89 10.49 143.00 876.35 -8,50 7.05 9645.00 57.49 36.69 35.03 8865.54 2292.23 -1436.19 5945648.76 716813.15 2249.57 -1501.93 10.49 142.00 897.65 -8.44' 7.36 9670.00 55,41 38.60 36.94 8879.35 2308.73 -1423.47 5945665.62 716825.39 2266.43 -1489.69 10.49 141.00 918.48 -8.32 7.64 9675,00 55.00 39,00 37.34 8882.21 2311,93 -1420.89 5945668,89 716827.87 2269.70 -1487.21 10.49 0.00 922.59 -8.20 8.00 9686,11 56,25 39.00 37.34 8888.48 2319.06 -1415,12 5945676.18 716833.43 2276.99 -1481,65 11,25 0.00 931.76 11.25 0.00 9695.00 57.25 39.00 37.34' 8893,35 2324,83 -1410.44 5945682.101 716837.94 2282.91 -1477,14 11.25 0.00 939.19 11.25 0.00 9720,00 60.06 39.00 37.34 8906.36 2341,43 -1397.01 5945699.07 716850.89 2299.88 -1464. i9 11,25 0.00 960.54 11.24 0.0C 9745.00 62,87 39.00 37,34 8918.30 2358.49 -1383,19 5945716,53 716864.21 2317.34 -1450,87 11.25 0.00 982.50 11.24 0.00 9755.00 64.00 39.00 37.34 8922.77 2365.44 -1377,56 5945723.64 716869,63 2324.45 -1445.45 11.25 0,00 991.44 11,30 0.00 9770.00 65.84 39.00 37.34 8929.13 2376.00 -1369.01 5945734,44 716877.87 2335.25 -1437.21 12,27 0.00 1005.03 12.27 0.00 9795.00 68,91 39.00 37,34 8703.00 2393.93 -1354.49 5945752.79 716891.87 2353.60 -1423.21 12.27 0.00 1028.10' 12.28 0,00 9820.00 71.98 39.00 37.34 8947.11 2412.24 -1339.67 5945771.51 716906.15 2372.32 -1408.93 12,27 0.00 1051,65 12.28 0.00 9833.60 73.65 39,00 37.34 8951.13 2422.34 -1331.49 5945781,84 716914.03 2382.65 -1401.05 12,27 0.00 1064.65 12.28 0.00 9845.00 75,05! 39.00 37.34 8954.20 2430.87 -1324.58 5945790.57 716920.69 2391.38 -1394.39 12.27 0.00 1075.62 12.28 0.00 9870.00 78.12 39.00 37.34 8960,00: 2449.76 -1309.28 5945809.90 716935.44 2410.71 -1379.64 12,27 0.00 1099.94 12.28 0.00 9895.00 81.18 39.00 37.34 8964.49 2468.87 -1293.80 5945829.45 716950.35 2430,26 -1364,73 12,27 0.00 1124,53 12.24 0.00 9920.00 84,25 39.00 37,34 8967.66 2488,14 -1278,20 5945849.17 716965,39 2449.98 -1349.69 12.27 0,00 1149.32 12.28 0,00 Meas. Iacl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Tun~ Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Conm~ent~, (de~) (de~) (de~) (ft) Lat. (Y) Der. (X) Lat. (Y) Der. (X) Lat. (Y) Der. (X) (°/100ft) (°/100ft) (°/100ft) 9933.60 85.92 39,00 37.34 8968,83 2498.67 -1269,67 5945859.94 716973,61 2460.75 -1341,47 12,27 0,00 1162,87 12.28 0.00 9945.00 87.32 39,00 37.34 8969,50 2507.52 -1262.51 5945868.99 716980,51 2469.80 -1334,57 12.27 0,00 1174.25 12.28 0.00 9966.82 90,00 39.00 37.3z 8970.01 2524.47 -1248,78 5945886.33 716993.74, 2487.14 -1321.34 12,27 84.00 1196,06 12.28 0.00 4. Landat 90°, 9970,00 90.01 39.08 37,42 8970.01 2526.94 -1246,78 5945888.85 716995.68 2489,66 -1319.40 2.38 84.00 1199.24 0.31 2.52 9974,86 90.02 39.19 37.53 8970.01 2530.71 -1243.71 5945892.71 716998.63 2493.52 -1316.45 2.38 84.00 1204.10 0,21 2.26 9995.00 90.06 39,67 38.011 8970,00 2546.26 -1230.92 5945908.63 717010.97 2509.44 -1304.11 2.38 84,00 1224,24 0,20 2.38 10000,00 90.07 39,79 38.13 8969.99 2550.11 -1227.73 5945912.57 717014,05 2513.38 -1301,03 2.38 84.00 1229,24 0.201 2.40 10020.00 90.12 40.26 38.60 8969.96 2565.42 -1214,86 5945928.25 717026.46 2529.06 -1288.62 2.38 84.00 1249.23 0.25 2.35 10045.00 90,17 40,85 39,19 8969.89 2584.42 -1198,61 5945947.71' 717042.16 2548.52 -1272.92 2.38 84.00 1274.22 0.20 2.36 10070.00 90.23 41.44 39.78 8969.81 2603.24 -1182.16 5945967.00 717058.06 2567.81 -1257.02 2.38 84.00 1299.19 0.24 2,36 10095.00 90.29 42,03 40.37 8969169 2621.90 -i165.52 5945986.13 717074,15 2586.94 -1240,93 2,38 84,00 1324.15 0.24 2.36 10100.00 90,30 42.15 40.49 8969.67 2625.61 -1162.17 5945989.94 717077.40 2590.75 -1237.68 2',38 84.00 1329.i4 0.20 2.4~3 10120.00 90.34 42.63 40.97 8969.55 2640.38 -1148.68 5946005,09 717090.44 2605.90 -1224.64 2.38 84.00 1349.10 0120 2.4(3 10145.00 90,40 43,22 41.56 8969.39 2658.69 -1131,66 5946023.88 717106,93 2624.69 -1208.15 2.38 84.00 1374.02 0,24 2.36 10170100 90.45 43,81 42.15 8969,21 2676,82 -1114.45 5946042.50 717123.61 2643.31 -1191,47 2.38 84,00 1398,93 0.20 2,36 10195,00 90.51 44.40 42,74 8969,00 2694.77 -1097,05 5946060.95 717140,49 2661.76 -1174.59 2,38 84.00 1423,81 0,24 2.36 10200.00 90,52 44.52 42.86 8968.95 2698.34 -1093,55 5946064,62 717143.88 2665.43 -1171.20 2.38 84,00 1428.78 0.20 2.4C 10220,00 90,57 44,99 43.33 8968.76 2712.54 -1079.46 5946079.22 717157,55 2680,03 -1157,53 2.38 84,00 1448,66 0.25 2.35" 10245,00 90.62 45,59 43.93 8968.50 2730,12 -1061.70 5946097.32 717174,79 2698.13 -1140.29 2,38 84.00 1473.49 0.20 2.40 10270,00 90.68 46.18 44.52 8968,22 2747,53 -1043,75 5946115.23 717192.23 2716.04 -1122.85 2,38 84.00 1498.28 0,24 2.36 10295.00 90.73 46.77 45.11 8967.91 2764.74 -1025,63 5946132,96 717209.85 2733,77 -1105.23 2.38 84,00 1523.04 0.20 2,36 10300.00 90,74 46,89 45.23 8967.85 2768.16 -1021,98 5946136.49 717213,40 2737,30 -1101,68 2.38 84,00 1527,99 0.20 2,40 10320,00 90,79 47,36 45.70 8967,58 2781,77 -1007.32 5946150.52 717227.65 2751.33 -1087,43 2,38 84.00 1547,77 0.25 2.35 10345,00 90.84 47,951 46.29 8967,23 2798,61 -988.85 5946167,88 717245.63 2768.69 -1069.45 2,38 84'.00 1572.45 0.20 2,36 10370,00 90.90 48.55 46.89 8966,85 2815.25 -970,20 5946185,06 717263.79 2785,87 -1051.29 2.38 8~t,00 1597.09 0.24 2,40 10395.00 90,95 49.14 47.48 8966.44 2831.70 -951,38 5946202.05 717282,13 2802,86 -1032,95 2,38' 84,00 1621.68 0.20 2.36 10400,00 90.96 49,26 47.60 8966,36 2834.97 -947.59 5946205,42 717285,81 2806.23 -1029.27 2.38 84.00 1626.60 0,20 2.40 10420,00 91,01 49.73 48,07 8966.02 2847,96 -932.39 5946218,85 717300,64 2819.66 -1014.44 2,38 84,00 1646.23 0.25 2,35 10445,00 91.06 50,32 48,66 8965.56 2864.02 -913.23 5946235.45 717319.32 2836.26 -995.76 2.38 84,00 1670,72 0.20 2.36 10470.00 91.12 50.91 49.25 8965.09 2879.88 -893,92 5946251.87 717338,17 2852,68 -976,91 2,38 84,00 1695.17 0,24 2.36 10495,00 91,17 51.51 49,85 8964.59 2895,53 -874.43 5946268.08 717357.19 2868.89 -957,89 2.38 84.00 1719,56 0.20 2,40 10500.00 91,18 51,62 49,96 8964,49 2898,64 -870,52 5946271.30 717361.01 2872,11 -954,07 2.38 84,00 1724.43 0.20 2.20 10520,00, 91.23 52.10 50.44 8964,07 2910.99 -854.79 5946284,10 717376.38 2884191 -938.70 2,38 84.00 1743.88 0.25 2.40 10545.00 91.28 52.69 51.03 8963.52 2926.24 -834.99 5946299.92 717395,73 2900,73 -919.35 2,38 84.00 1768.15 0.20 2,36 10570.00 91,33 53.28 51.62 8962,95 2941.29 -815.03 5946315,54 717415.24 2916.35 -899.84 2.38 84,00 1792,36 0,201 2.36 10595,00 91.39 53,87 52.21 8962.36 2956.13 -794,92 5946330,96 717434.91 2931.77 -880.17 2,38 84.00 1816.49 0.24 2.36 10600.00 91.40 53.99 52.33 8962.23 2959.07 -790188 5946334.01 717438,86 2934,82 -876,22 2,38 84.00 1821.31 0.20 2,4~3 10620.00 91.44 54,47 52.81 8961.74 2970,76 -774.66 5946346,17 717454,74 2946.98 -860.34 2.38 84,00 1840,56 0.20 2.4~3 10645,00 91.50 55,06 53.40 8961,10 2985.18 -754.25 5946361,17 717474.73 2961.98 -840.35 2.38 84,00 1864.56 0.24 2.36 10670,00 91.55 55.65 53.99 8960.43 2999.38 -733,69 5946375.97 717494.87 2976,78 -820,21 2.38 84.00 1888.49 0.20 2.36 10685.34 91.58 56.01 54.35 8960,01 3008.00 -721.00 5946384.94 717507,30 2985.75 -807.78 2.38 0.00 1903,13 0.20 2.35:T.D. 1442' from KOP. CDR: Rig #1 Alaska LAY~OUT C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I-- 7" Riser Methanol Injection ~ I Otis 7" WLA Quick ' ' I Connect I 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 Man--- 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 Hydraulic over Electric 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 ri II 9-5/8" Annulus I I13-3/8" Annulus ~ i04 PAUL RAUF 015412452359 ARCO ALASKA INC. ~. o. ~ox ~oo~,o~o.,~o, ~,,z,/~ ~, /q~k ~_~o Ai~ilCHORAGE, AK 99510--0360 , _ay' to the OFIRST CHICAGO The First National Bank of Chicago Chicago, Illinois 60670 / ~:O ? iOOOO i t~: qO . NOT VALID FOR OVER $1000.00 O~Oh WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. ?~R DATE, 12. · ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27. 28. 20. COMPANY Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... PROGRAM: exp~dev ,~ redrll ~ serv~ GEOL AREA ~>'..~'~) UNIT# N Conductor string provided ................... /'~ N Surface casing protects all known USDWs ........... ~.,~.J N CMT vol adequate to circulate on conductor & surf csg ..... N CMT vol adequate to tie-in long string to surf csg ........ Y N CMT will cover all known productive horizons .......... (:~ N Casing designs adequate for C, T, B & permafrost ....... ~ N Adequate tankage or reserve pit ................. (~ N If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Y N Drilling fluid program schematic & equip list adequate ..... (~ N BOPEs, do they meet regulation ................ (~ N BOPE press rating appropriate; test to _.qS'O0 psig. (~ N Choke manifold complies w/APl RP-53 (May 84) ........ ~ N Work will occur without operation shutdown ........... ~ N wellbore seg ann. disposal para req ~ ON/OFF SHORE Y N ~ ?~-~'"~'~ >' .~9 9' GEOLOGY Is presence of H2S gas probable ................. (~ N / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N /'/ 31. Data presented on potential overpressure zones ....... y/,~N//~ ~,_.' 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. / 34. Contact name/phone for weekly progress reports [exploratorY~hly] Y N ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, th[,s-plan (A) will contain waste in a suita,.ble/receiving zo/Ce; ....... Y U (B) will not contaminate fre,sJ'~water; or cause/drilling waste... Y N to surface; ~ ~ (C) will not impair m_,.edhanical integrity o/[,{he well used for disposal; Y N (D) will not dam/8~J~ producing formati/efl or impair recovery from a Y N pool; and r_,. , (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLO, C-~¢ ENGINEERING: UIC/Annu/lald' COMMISSION: BEW JDH ----,_..-- Comments/Instructions: O Z O m c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS . **** REEL HEADER MWD 99/ 9/ 1 BHI 01 LIS Customer Format Tape. **** TAPE HEADER MWD 99/ 9/ t 104367 01 3/4" NaviGamma, Gamma Ray data LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ---- Remark File Version 1.000 Extract File: Header.las -Version Information VERS i ~: ~Well Information Block #MNEM.UNIT Data Type STRT F STOP F STEP F NULL COMP WELL ELD LOC CNTY STAT SRVC TOOL REF DATE API CWLS iog ASCii Standard -~RSiON i.gu~^ One line per frame Information 9230.0000: Starting Depth 10935.0000: Ending Depth 0.5000: Level Spacing -999.2500: ~bsent CO~ZmnNv- ~u'~ Alaska, WELL: v~-v r, FIELD: Prudhoe Bay Unit LOCATION: 33'46' FNL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1 3/4" NaviGamma - Gamma Ray JOB REFERENCE: 104367 LOG DATE: 22 Apr 99 API NUMBER: 500292022301 ~Parameter Information Block ~MNEM. UNiT Value Description FL SECT TO~.~ N P DAT LM F FAPD F DM F EKB F EDF F EGL F CASE. F OSi . ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Well 09-07A is represented by Runs 5, 6, 8, 9, 10, 13, 14 and 15, which are all Directional with Gamma Ray. 47' FEL : F{~l~ Location ~ : Sectlon !0i'.~ : To~,m~ship 1SE : Range MSL : Permanent Datura RKB : Log Measured From 54 : Feet Above Perm. Datum RKB : Drilling Measured From ~4' : Elevation Of Kelly Bushing N/A : Elevation Of Derrick Floor N/A : Elevation Of Ground Level 9264 : Casing Depth DiRECTiONAL : Other Services Line i ('5 Well 09-07A was kicked off @ 9264' MD (8670' SSTVD), from the wellbore . · of Well 09-07 on Run 4. 6 Well 09-07A was drilled to TD @ 10932' MD (8953' SSTVD) on Run 15. 7 The interval from 10907' MD (8953' SSTVD) to 10932' MD (8953' SSTVD) was not logged due to sensor to bit depth. 8 The Gamma Ray log has been depth shifted to match the PDS' open hole Gamma Ray, logged on 23 April 1999. 9 A Magnetic Declination correction of 27.97 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 -> True Vertical Depth, feet ~Sensor Offsets RUN GAMMA 5 26.44 ft. 6 25.69 ft 8 25.57 ft 9 ~ 25.76 ft 10 25.74 13 26.12 ft 1~ 26.10 ft 1~ 26.12 ft DIRECTIONAL 21.46 ft. 20.71 ft. 20.59 ft. 2~.78 ft. 20.76 ft. 21.14 ft. 21.12 ft. 21.14 ft. Tape Subfile: i 71 records... Minimum record length: Maximum record length: Tape Subfile 2 is t.vpe: LIS 14 bytes 132 bytes FILE HEADER MWD .001 1024 INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 09-07A 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 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 PDS' open hole Gamma Ray data, dated April 23, 1999. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP I GR G F~'~< O. 0 2 ROP ROPS 0.0 * '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( ~8~'- ' Number ~ frames, per' recor~ 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: i Entry Block terminator. Summary of entry types 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 i'~D 68 i 4 [] * DATA RECORD (TYPE# 0) 1014 BYTES API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 . 1 4 99 995 99 Total Data Records: 41 Tape File Start Depth = 9230.000000 Tape File End Depth = 10935.000000 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 10237 datums Rep Code: 79 2 datums Tape Subfile: 2 48 records... Mi'nimum record length: 54 bytes Maximum record length: . fO14 bytes Tape Subfile 3 is type: LIS ~'** FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CO~S MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 09-07A 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 G?~ G9~4 0.0 2 RO?S 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= O) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 '1 1 1 1 1 O 0 1 Rep Code Count Bytes 68 2 8 1 0 1 0 1 0 0 1 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 i GRAfK ~4WD 68 1 ~° ROPS M~.F~D 68 _1 ~-~4l.f'" '' APL-API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 99 995 99 i 4 4 99 995 99 i DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 41 Tape File Start Depth = 9230.000000 Tape File End Depth = 10935.000000 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 10237 datums Rep Code: 79 2 datums Tape Subfile: 3 48 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD 99/ 9/ 1 104367 01 **** REEL TRAILER ~D 99/ 9/ 1 BHI O1 Tape Subfile: 4 2 records... . · Minimum record length: ' 132 bytes Maximum record length: 132 bytes End of execution: Wed 1 SEP 99 3:33p Elapsed execution time = 1.32 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: L~I~ [] Tape Subfile 2 is type: LIS DEPTH 9230.0000 9230.5000 9300 0000 9400 0000 9500 0000 9600 0000 9700 0000 9800 0000 9900 0000 10000 0000 10100 0000 10200 0000 10300~0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 10935.0000 -999 -999 30 33 140 46 33 46 57 58 58 51 41 62 116. 74. 39. 67. 83. -999. ROP 2500 -999.2500 2500 -999.2500 4780 11.1000 8240 12.0000 9320, 41.9290 8100 77.9430 9750 108.7670 8100 81.0000 2830 76.5000 5000 50.9910 2130 58.0000 4800 lOO. QQ~O 22~0 121!7~0 5640 88.6250 4940 39.5000 8800 13.0000 5200 71.5670 4220 51.4000 4600 9.0000 2500 -999.2500 Tape File Start Depth = 9230.000000 Tape File End Depth = 10935.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH 9230.0000 9230.5000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 10935.0000 GRAX -999.2500 -999 2500 29 6970 33 7230 141 9400 52 8500 36 9950 47 1210 64 9300 63 6000 54 6000 51 4800 43 6800 52 4110 127 1400 112 3200 57 7200 7O 2O00 87 3600 -999.2500 ROPS -999.2500 -999.2500 4.5000 27.6000 38.2000 65 4000 92 3000 80 0000 78 2000 39 8470 59 4560 100.0000 109.5950 85.4500 13.8000 50.0000 75.0000 38.1640 10.4000 -999.2500 Tape File Start Depth = 9230.000000 Tape File End Depth = 10935.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS