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Home My WebLink About219-092MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 S-201A 50-029-22987-01-00 219-092-0 N SPT 4001 2190920 3650 540 3690 3510 3468 285 286 286 287 REQVAR P Josh Hunt 12/24/2025 2-Year MIT-T every 2 years to greater of the max anticipated header injection pressure per AIO 25A.002 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 598 600 600 598IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH251224151328 BBL Pumped:0.8 BBL Returned:0.8 Friday, January 16, 2026 Page 1 of 1           Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] [AOGCC_Public_Notices] Are Injection Order 25A.021 and 25A.022 Amended (Hilcorp) Date:Monday, September 29, 2025 12:02:26 PM Prudhoe Bay Unit S-210 (PTD 2190570), Polaris Oil Pool Prudhoe Bay Unit S-201A (PTD 2190920), Polaris Oil Pool From: Wallace, Chris D (OGC) Sent: Monday, September 29, 2025 11:59 AM To: 'Oliver Sternicki' <oliver.sternicki@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] [AOGCC_Public_Notices] Are Injection Order 25A.021 and 25A.022 Amended (Hilcorp) Oliver, I did carry over the 2 year testing frequency as that is our standard on injectors with high set packer AA’s. WFL schedule sounds fine. For the MIT schedules, for S-201A I itemized the April 2026 MITIA in the AA. I would be OK with both the MITT both being completed in April 2026 rather than the MITT for December 2025 if that is more operationally efficient. You could request a delay for the MITT as it approaches with this email as justification, otherwise keep them on different schedules. Yes – from AOGCC standpoint you are approved for re-start of Polaris water only injection in S-201A and S-210. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Monday, September 29, 2025 11:21 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] [AOGCC_Public_Notices] Are Injection Order 25A.021 and 25A.022 Amended (Hilcorp) CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Chris, Planning on doing the initial WFLs on S-201A, S-23 and S-24B ~30 days after injection starts back up. Giving it a couple weeks just to make sure that if there are any flow paths they would be established at that point. Other than that the MIT-T and MIT-IA’s are cueing off the preexisting schedules. S-201A MIT-IA due in April 2026, S-201A MIT-T due in December 2025. S-210 MIT-T and MIT-IA due in January 2026. Are we good from an AOGCC perspective on restart of injection into S-201A and S-210? Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Coldiron, Samantha J (OGC) <samantha.coldiron@alaska.gov> Sent: Monday, September 29, 2025 9:00 AM To: AOGCC_Public_Notices <AOGCC_Public_Notices@list.state.ak.us> Subject: [EXTERNAL] [AOGCC_Public_Notices] Are Injection Order 25A.021 and 25A.022 Amended (Hilcorp) Docket Number: AIO-25-021 Request for Administrative Approval to Area Injection Order 25A; Water Injection Prudhoe Bay Unit S-210 (PTD 2190570), Polaris Oil Pool Docket Number: AIO-25-022 Request for Administrative Approval to Area Injection Order 25A; Water Injection Prudhoe Bay Unit S-201A (PTD 2190920), Polaris Oil Pool Samantha Coldiron AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: oliver.sternicki@hilcorp.com Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/oliver.sternicki%40hilcorp.com 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/11/2024 S-201A 50-029-22987-01-00 219-092-0 G SPT 4001 2190920 3500 2422 2426 2427 2429 400 421 420 420 OTHER P Sully Sullivan 4/24/2024 MIT post patch on sliding sleeve leak. Test to 3500 per Sundry 324-145 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 499 3876 3726 3675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240424155603 BBL Pumped:8.2 BBL Returned:6 Tuesday, June 11, 2024 Page 1 of 1         AIO 25A.022   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 S-201A Install Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-092 50-029-22987-01-00 7169 Conductor Surface Intermediate Production Liner 5492 80 3162 5723 7110 6822 20" 9-5/8" 7" 3-1/2" 5227 47 - 127 47 - 3209 44 - 5767 43 - 7153 47 - 127 47 - 2864 44 - 4317 43 - 5480 None 3190 5410 10530 6822 5750 7240 10160 6519 - 6876 None N/A N/A 4987 - 5268 Structural No Packer No SSSV Installed None N/A Torin Roschinger Operations Manager Leslie Reavis leslie.reavis@hilcorp.com 907.777.8326 PRUDHOE BAY, Polaris Oil Pool 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 0028257, 0028258 N/A N/A N/A 1649 3297 1550 500 2345 2515 324-145 13b. Pools active after work:Polaris Oil No SSSV Installed No Packer 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 8:59 am, May 01, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.01 05:14:02 -08'00' Torin Roschinger (4662) RBDMS JSB 051324 WCB 7-30-2024 DSR-5/1/24 ACTIVITY DATE SUMMARY 3/22/2024 ***WELL S/I ON ARRIVAL*** (profile modification) BRUSHED 3 1/2" HP DEFENDER SLIDING SLEEVE W/ 3 1/2" BRUSH, 2.50" GAUGE RING @ 4,936' MD SET 3 1/2" ISO SLEEVE IN SLIDING SLEEVE @ 4,936' SLM (1.81" min id, 95" oal) PERFORMED PASSING MIT-IA TO 3581psi (see log) ***CONT WSR ON 3/23/24*** 3/23/2024 ***CONT WSR FROM 3/22/24*** (proflie modification) R/D HES 759 SLICKLINE UNIT ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 3/25/2024 T/I/O1900/1222/367 Temp= On Inj AOGCC MIT IA PASSED to 3624 psi. (Witnessed by AOGCC Inspector Bob Noble) Pumped 2.7 bbls of 110*f diesel down the IA to achieve test pressure. IA lost 217 psi 1st 15 mins and 49 psi in 2nd 15 mins for a total loss of 266 psi in 30 mins Bled back 2 bbls. Final WHPs 1890/294/350. Pad Op notified of well status per LRS departure. Well on injection. IA, OA=OTG ***Tag hung on IA*** 3/27/2024 T/I/O = 2620/1180/320. Temp = 98*. POT-T (PASS) (eval TxIA). On MI. Stung into TBG hanger test port (0+ psi), bled void to 0 psi. Monitor test void for 1 hr, no increase in pressure. SV = C. WV, SVV, MV = O. IA & OA = OTG. 12:00. 4/8/2024 ***WELL INJECTING ON ARRIVAL*** (LDL) DRIFTED W/ 5' x 1.69" & BULL NOSE TO 6,750' SLM ***CONTINUE ON 4/9/24 WSR*** 4/9/2024 ***CONTINUED FROM 4/8/24 WSR*** (LDL) RAN REED LDL PER PROGRAM (good data, appears ssd is leaking) ***WELL LEFT S/I ON DEPARTURE, OAD-OP NOTIFIED OF STATUS*** 4/12/2024 ***WELL S/I ON ARRIVAL*** PULLED 2.81'' ISO SLEEVE FROM 4936' MD DRIFTED 30' x 2.78'' DMY GUNS, DRIFT FREELY TO 5100' SLM BRUSH w/ KJ, 3-1/2'' BLB, 2.75'' G-RING, BRUSH X-NIP @ 6413' SLM/ 6429' MD & BRUSH AREA FROM ~4900' SLM TO ~4960' SLM ***WSR CONT ON 4-13-24*** 4/13/2024 ***WSR CONT FROM 4-12-24*** PERFORMED WELL CONTROL DRILL w/ NIGHT CREW, SAFETY MEETING w/ WSL SET 2.81'' NIPPLE REDUCER (2.81'' x 1.781'', lih 30'') IN X-NIP @ 6429' MD RAN 3-1/2'' CHECK SET TO NIP-REDUCER @ 6429' MD (sheared) RAN 3-1/2" (2.813") 42B0 (Self releasing keys) TO CLOSE SLD SLV @ 4936' MD ***JOB COMPLETE, WELL LEFT S/I*** Daily Report of Well Operations PBU S-201A Daily Report of Well Operations PBU S-201A 4/17/2024 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP ATTEMPT TO SET 3-1/2" NS SOLUTION STRADDLE PACKER FROM 4923' - 4955' MD ELEMENT TO ELEMENT. CCL STOP DEPTH 4908.5' MD, CCL TO ELEMENT=14.5'. CORRELATED TO TUBING TALLY DATED:1-5-2020' MD. SETTING TOOL APPEARS TO HAVE SET PATCH BUT NOT RELEASED. WORKED CABLE FOR 10 MINS. PULLED OUT OF WEAKPOINT AND LEFT TOOLS IN HOLE. ***TOOLS LEFT=1-7/16" CHD(1" FN), 1-11/16" GUN GAMMA, BAKER#10, NS 2.72" STRADDLE PACKER*** OAL=54', MAX OD=2.72" 4/18/2024 ***WELL S/I ON ARRIVAL*** (Profile modification) RU POLLARD UNIT #60 ***CONTINUED ON 4/19/24 WSR*** 4/19/2024 ***CONTINUED FROM 4/18/24 WSR*** (Profile modification) FISHED E-LINE TOOLSTRING FROM 4,881' SLM JARRED DOWN ON PATCH AT 4,894' SLM FOR 15MIN. ***WELL S/I ON DEPARTURE*** 4/19/2024 T/I/O= 1267/639/293. MIT-IA PASSED to 3654 psi. (Profile modification). Pumped 19.3 bbls of diesel down IA to achieve test pressure. IA lost 181 psi 1st 155 mins and 55 psi 2nd 15 min for a total loss of 236 psi in 30 mins. . IA lost 236 psi during the 30 minute test. Bled back 10.5 bbls. Final WHPs= 1250/418/295. 4/24/2024 T/I/O= 2422/499/400 Temp= 112*F. AOGCC MIT-IA PASSED to 3675 psi (Witnessed by AOGCC Inspector Sully Sullivan) Pumped 8.2 bbls of diesel down IA. IA lost 150 psi 1st 15 mins and 51 psi 2nd 15 mins for a total loass of 201 psi in 30 minute test. Bled back 6 bbls to Final T/I/O= 2423/498/399. ( FISHED E-LINE TOOLSTRING FROM 4,881' SLM JARRED DOWN ON PATCH AT 4,894' SLM FOR 15MIN MIT-IA PASSED to 3654 psi ATTEMPT TO SET 3-1/2" NS SOLUTION STRADDLE PACKER FROM 4923' - 4955' MD ELEMENT TO ELEMENT. CCL STOP DEPTH 4908.5' MD, CCL TO ELEMENT=14.5'. CORRELATED TO TUBING TALLY DATED:1-5-2020' MD. SETTING TOOL APPEARS TO HAVE SET PATCH BUT NOT RELEASED. W ORKED CABLE FOR 10 MINS. PULLED OUT OF WEAKPOINT AND LEFT TOOLS IN HOLE From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG Injector S-201A (PTD #2190920) MIT-IA passed post patch Date:Monday, April 22, 2024 3:14:47 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 19, 2024 5:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: WAG Injector S-201A (PTD #2190920) MIT-IA passed post patch Mr. Wallace, E-line set a tubing patch across the sliding sleeve on 04/17/24. A subsequent MIT-IA passed to 3654 psi. The well will now be classified back to OPERABLE. An AOGCC MIT-IA will be scheduled when the well is on injection and thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, April 11, 2024 5:20 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) LDL ID tubing leak Mr. Wallace, Injector S-201A (PTD #2190920) online leak detect logging indicates a tubing leak at the sliding sleeve. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 25, 2024 1:07 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was determined to have IA re-pressurization not consistent with thermal trends. On 03/22/24 Slickline set an ISO sleeve in the sliding sleeve and performed a passing offline MIT-IA to 3,592 psi in accordance with Sundry #324-145. On 03/25/24 an online AOGCC witnessed MIT-IA passed to 3,624 psi. The Under Evaluation period will be extended for up to 28- days to monitor the well for IA re-pressurization after the ISO sleeve was set. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 5, 2024 12:30 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was put on injection on 02/27/24 and an AOGCC witnessed MIT-IA passed on 02/29/24. On 03/01 and 03/02 the operator bled the IA pressure. Since those bleeds the IA pressure has slowly climbed to ~800 psi. At this time, it is not clear if the slow increase in IA CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. pressure is from thermal effects from the warming of fluids pumped during the offline and online MITs or from TxIA communication. Sundry #324-108 was approved to set an isolation sleeve across the sliding sleeve in the event the MIT-IA failed. Our plan is to bleed the IA pressure one more time and if the IA pressure continues to increase then we can rule out thermal effects. In that case, the well will be shut-in and the isolation sleeve will be set. Plan Forward: 1. DHD: Bleed IAP 2. Well Integrity: Monitor 3. Slickline (pending): Set isolation sleeve 4. Well Integrity (pending): Resume injection and continue to monitor Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online 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. Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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, please immediately 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. 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) LDL ID tubing leak Date:Thursday, April 11, 2024 8:57:37 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, April 11, 2024 5:20 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) LDL ID tubing leak Mr. Wallace, Injector S-201A (PTD #2190920) online leak detect logging indicates a tubing leak at the sliding sleeve. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 25, 2024 1:07 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was determined to have IA re-pressurization not consistent with thermal trends. On 03/22/24 Slickline set an ISO sleeve in the sliding sleeve and performed a passing offline MIT-IA to 3,592 psi in accordance with Sundry #324-145. On 03/25/24 an online AOGCC witnessed MIT-IA passed to 3,624 psi. The Under Evaluation period will be extended for up to 28- days to monitor the well for IA re-pressurization after the ISO sleeve was set. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 5, 2024 12:30 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was put on injection on 02/27/24 and an AOGCC witnessed MIT-IA passed on 02/29/24. On 03/01 and 03/02 the operator bled the IA pressure. Since those bleeds the IA pressure has slowly climbed to ~800 psi. At this time, it is not clear if the slow increase in IA pressure is from thermal effects from the warming of fluids pumped during the offline and online MITs or from TxIA communication. Sundry #324-108 was approved to set an isolation sleeve across the sliding sleeve in the event the MIT-IA failed. Our plan is to bleed the IA pressure one more time and if the IA pressure continues to increase then we can rule out thermal effects. In that case, the well will be shut-in and the isolation sleeve will be set. Plan Forward: 1. DHD: Bleed IAP 2. Well Integrity: Monitor 3. Slickline (pending): Set isolation sleeve 4. Well Integrity (pending): Resume injection and continue to monitor Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 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 hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately 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. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240412 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU G-18 50029231940000 204020 3/21/2024 READ CaliperSurvey MPU L-07 50029220280000 190037 3/30/2024 READ CaliperSurvey PBU 01-19C 50029208000300 213171 2/22/2024 BAKER MRPM PBU 01-28B 50029215970200 223089 1/21/2024 BAKER MRPM PBU 11-42 50029237750000 223117 3/5/2024 HALLIBURTON RBT PBU N-11D 50029213750300 223083 2/14/2024 BAKER MRPM PBU N-21A 50029213420100 196196 3/28/2024 BAKER SPN PBU S-201A 50029229870100 219092 4/8/2024 READ LeakPointSurvey Please include current contact information if different from above T38705 T38706 T38707 T38708 T38709 T38710 T38711 T38712 T38713PBU S-201A 50029229870100 219092 4/8/2024 READ LeakPointSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 11:46:27 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, April 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/12/2024 S-201A 50-029-22987-01-00 219-092-0 G SPT 4001 2190920 3500 1900 1909 1903 1902 355 366 366 367 OTHER P Bob Noble 3/25/2024 MIT-IA per Sundry #324-145 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 1222 3890 3673 3624IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240325164252 BBL Pumped:2.7 BBL Returned:2 Friday, April 12, 2024 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 S-201A 50-029-22987-01-00 219-092-0 G SPT 4001 2190920 3500 1704 1713 1709 1708 276 287 286 287 OTHER P Kam StJohn 2/29/2024 AIO 25A.022 - packerless completion. MIT-IA to 3500 psi as per sundry 324-108 (cycle closed sliding sleeve to correct TxIA communication) 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 980 3823 3642 3592IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240229104237 BBL Pumped:2.5 BBL Returned:2.3 Thursday, April 11, 2024 Page 1 of 1          From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request to keep WAG Injector S-201A (PTD #2190920) online for continued diagnostics Date:Wednesday, March 27, 2024 12:56:22 PM From: Wallace, Chris D (OGC) Sent: Wednesday, March 27, 2024 12:55 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: Request to keep WAG Injector S-201A (PTD #2190920) online for continued diagnostics Andy, Continued injection and the plan forward as detailed below is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, March 27, 2024 12:41 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to keep WAG Injector S-201A (PTD #2190920) online for continued diagnostics Mr. Wallace, After the AOGCC MIT-IA passed on 03/25/24, the IA pressure has exhibited sporadic re- pressurization. We would like to keep the well online to see if the current re-pressurization is due to MI that migrated to the IA and became entrained in the completion fluid before the ISO sleeve was set. If the IA re-pressurization does not stabilize, Hilcorp is planning to execute a leak detect log. Due to the passing MIT-IA, we do not have confidence a leak could be activated by conventional pumping methods. It is preferable that the leak detect log would be executed while the well is still on MI injection. If you approve continued injection, this added diagnostic work would be completed during the current 28-day Under Evaluation period. Plan Forward: 1. DHD/OPS: Bleed as needed and monitor for stabilization. 2. E-line (Pending): If re-pressurization does not stabilize, execute online LDL 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 25, 2024 1:07 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was determined to have IA re-pressurization not consistent with thermal trends. On 03/22/24 Slickline set an ISO sleeve in the sliding sleeve and performed a passing offline MIT-IA to 3,592 psi in accordance with Sundry #324-145. On 03/25/24 an online AOGCC witnessed MIT-IA passed to 3,624 psi. The Under Evaluation period will be extended for up to 28- days to monitor the well for IA re-pressurization after the ISO sleeve was set. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 5, 2024 12:30 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. online Mr. Wallace, Injector S-201A (PTD #2190920) was put on injection on 02/27/24 and an AOGCC witnessed MIT-IA passed on 02/29/24. On 03/01 and 03/02 the operator bled the IA pressure. Since those bleeds the IA pressure has slowly climbed to ~800 psi. At this time, it is not clear if the slow increase in IA pressure is from thermal effects from the warming of fluids pumped during the offline and online MITs or from TxIA communication. Sundry #324-108 was approved to set an isolation sleeve across the sliding sleeve in the event the MIT-IA failed. Our plan is to bleed the IA pressure one more time and if the IA pressure continues to increase then we can rule out thermal effects. In that case, the well will be shut-in and the isolation sleeve will be set. Plan Forward: 1. DHD: Bleed IAP 2. Well Integrity: Monitor 3. Slickline (pending): Set isolation sleeve 4. Well Integrity (pending): Resume injection and continue to monitor Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris 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 S-201A Close Sliding Sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-092 50-029-22987-01-00 7169 Conductor Surface Intermediate Production Liner 5492 80 3162 5723 7110 6822 20" 9-5/8" 7" 3-1/2" 5227 47 - 127 47 - 3209 44 - 5767 43 - 7153 47 - 127 47 - 2864 44 - 4317 43 - 5480 None 3190 5410 10530 6822 5750 7240 10160 6519 - 6876 None N/A N/A 4987 - 5268 Structural No Packer None N/A Kirsty Glasheen for Torin Roschinger Operations Manager Leslie Reavis leslie.reavis@hilcorp.com 907.777.8326 PRUDHOE BAY, Polaris Oil Pool 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 0028257, 0028258 N/A N/A N/A 3327 1548 550 950 2363 1856 324-108 13b. Pools active after work:Polaris Oil No SSSV Installed 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 11:30 am, Mar 05, 2024 Digitally signed by Kirsty Glasheen (4474) DN: cn=Kirsty Glasheen (4474) Date: 2024.03.05 10:38:01 - 09'00' Kirsty Glasheen (4474) DSR-3/5/24 RBDMS JSB 031324 WCB 2024-07-08 ACTIVITY DATE SUMMARY 2/23/2024 ***WELL S/I ON ARRIVAL*** R/U POLLARD #61 RAN KJ, 2.71" CENT, 2' x 1-7/8", 3-1/2" (2.813") 42B0 (Self releasing keys) (cont on next day) ***WSR CONT ON 2-24-24*** 2/24/2024 T/I/O = 915/1157/354 Temp= SI MIT IA PASSED to 3321 psi. (INTEGRITY) Pumped 1.6 bbls of diesel down IA to achieve test pressure of 3501 psi. IA lost 139 psi 1st 15 mins and 41 psi 2nd 15 mins for a total loss of 180 psi in 30 mins. Bled back 1.1 bbls. Final WHPs = 897/1122/352 Valve Positions: SV/WV = Closed, SSV/MV = Open, IA/OA = OTG 2/24/2024 ***WSR CONT FROM 2-23-24*** RAN 2.71" CENT, 2' x 1-7/8", 3-1/2" (2.813") 42B0, 1-1/2'' R.S (Self releasing keys) SHIFT DEFENDER SLD SLV "UP" TO CLOSE @ 4919' SLM/ 4936' MD PERFORMED PASSING MIT-IA (see log) ***JOB COMPLETE, WELL LEFT S/I*** 2/29/2024 T/I/O= 1,700/970/275 (ANN-COMM) *St John* AOGCC MIT-IA to 3,592 psi ***PASSED*** Target Pressure= 3,500 psi - Max Pressure= 3,888 psi - Pumped 2.5 bbls of Diesel down IA to reach 3,823 psi. 1st 15-minute loss of 181 psi, 2nd 15- minute loss of 50 psi, for a total loss of 231 psi in 30 minutes. Bled back ~2.3 bbls. Pad Op notified of well status upon departure. Well injecting on departure. FWHPs= 1,695/990/275 Daily Report of Well Operations PBU S-201A ()( SHIFT DEFENDER SLD SLV "UP" TO CLOSE @ 4919' SLM/ 4936' MD PERFORMED PASSING MIT-IA (see log) The MIT-IA was a stipulation of the sundry. -WCB *St John* AOGCC MIT-IA to 3,592 psi ***PASSED*** 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. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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, please immediately 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. 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Date:Tuesday, March 26, 2024 3:43:21 PM Attachments:Sundry_324-145_031224.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 25, 2024 1:07 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was determined to have IA re-pressurization not consistent with thermal trends. On 03/22/24 Slickline set an ISO sleeve in the sliding sleeve and performed a passing offline MIT-IA to 3,592 psi in accordance with Sundry #324-145. On 03/25/24 an online AOGCC witnessed MIT-IA passed to 3,624 psi. The Under Evaluation period will be extended for up to 28- days to monitor the well for IA re-pressurization after the ISO sleeve was set. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 5, 2024 12:30 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was put on injection on 02/27/24 and an AOGCC witnessed MIT-IA passed on 02/29/24. On 03/01 and 03/02 the operator bled the IA pressure. Since those bleeds the IA pressure has slowly climbed to ~800 psi. At this time, it is not clear if the slow increase in IA CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. pressure is from thermal effects from the warming of fluids pumped during the offline and online MITs or from TxIA communication. Sundry #324-108 was approved to set an isolation sleeve across the sliding sleeve in the event the MIT-IA failed. Our plan is to bleed the IA pressure one more time and if the IA pressure continues to increase then we can rule out thermal effects. In that case, the well will be shut-in and the isolation sleeve will be set. Plan Forward: 1. DHD: Bleed IAP 2. Well Integrity: Monitor 3. Slickline (pending): Set isolation sleeve 4. Well Integrity (pending): Resume injection and continue to monitor Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online 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. Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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. 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 S-201A Set Isolation Sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-092 50-029-22987-01-00 484A ADL0028257, 0028258 7169 Conductor Surface Intermediate Production Liner 5492 80 3162 5723 7110 6822 20" 9-5/8" 7" 3-1/2" 5227 47 - 127 47 - 3209 44 - 5767 43 - 7153 1500 47 - 127 47 - 2864 44 - 4317 43 - 5480 None 3190 5410 10530 6822 5750 7240 10160 6519 - 6876 None N/A N/A4987 - 5268 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Kirsty Glasheen for Torin Roschinger Operations Manager Leslie Reavis leslie.reavis@hilcorp.com 907-777-8326 PRUDHOE BAY 3/12/2024 Current Pools: POLARIS OIL Proposed Pools: POLARIS 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 Samantha Coldiron at 3:13 pm, Mar 06, 2024 324-145 Digitally signed by Kirsty Glasheen (4474) DN: cn=Kirsty Glasheen (4474) Date: 2024.03.05 14:03:44 - 09'00' Kirsty Glasheen (4474) 10-404 DSR-3/6/24A.Dewhurst 08MAR24 MGR11MAR24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.12 11:21:42 -08'00'03/12/24 RBDMS JSB 031324 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/04/2024 S-201A 50-029-22987-01-00 219-092-0 N SPT 4001 2190920 1500 1266 1290 1287 354 369 367 OTHER F Kam StJohn 1/18/2024 Diagnostic MIT-IA Under Evaluation to 3200psi. Pressure dropped 300psi in 5 min after that Ryan Holt called it a fail well to remain Shut in. 15 Min pressure is a 5 min pressure 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 599 3483 3153IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240119124025 BBL Pumped:2.9 BBL Returned:2.1 Monday, March 4, 2024 Page 1 of 1            IA remedial cement Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Well Name:S-201A Permit to Drill:219-012 Current Status:Under Eval, WAG API Number:50-029-22987-01-00 Estimated Start Date:March 2024 Estimated Duration:2days Regulatory Contact:Abbie Barker First Call Engineer:Leslie Reavis (907) 777-8326 (O)(907) 440-7692 (M) Second Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Current Bottom Hole Pressure:2,000 psi @ 5,000’ TVDss 8.46 ppg | Based on offset wells Max Anticipated Surface Pressure:1,500 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:1,100 psi 4/25/2021 Min ID:2.813” @ 2,087’ MD X-Nipple Max Angle:63 deg @ 3,686’ MD Last Tag:6,822’ MD SL Tag 4/25/2021 Brief Well Summary: WAG well S-201A (PTD# 219-012) currently operates under an AA due to the packerless completion. Slickline set a tubing plug 12/2/23 and the well passed an AOGCC witnessed MIT-T a day later. The plug was pulled and an AOGCC witnessed MIT-IA passed on 12/16/23. Shortly after the MIT-IA the well started showing signs of TxIA comm. A subsequent MIT-IA that was performed on 1/18/24 failed, losing 330 psi in the first 5 min of the test. An LDL was run on E-line 2/13/24 and found a leak at the sliding sleeve at 4,936' MD. During the December slickline rig-up it was noted that a 3.5” brush and 2.80” gauge ring sat down in the sliding sleeve while performing a drift run. The sliding sleeve is functioned down to open. There is a potential that the sleeve was partially shifted open when the tools sat down leading to the TxIA communication. Slickline shifted Baker Defender SSD closed on 2/24/24 & well passed AOGCC Witnessed MIT-IA to 3592 psi on 2/29/24; however, the well is still exhibiting IA repressurization. Note: there is a known tight spot at 6758' MD. Objective: - Attempt to cycle sliding sleeve closed and perform an MIT-IA. - If MIT-IA still fails after cycling sleeve, a contingent isolation sleeve will be set across the leaking sliding sleeve. - Return well to injection - Set isolation sleeve across leaking sleeve - Return well to injection Current Status: Under Eval WAG (on MI), Shrader Bluff (Polaris Pool), Online Recent Integrity: 02/29/24: AOGCC MIT-IA passed to 3592 psi 02/13/24: LDL ID Leak @ 4937' MD SS MIT-IA Failed 01/18/24: AOGCC MIT-IA Failed lost 330 psi in 5 minutes 01/10/24: PPPOT-T Passed 12/16/23: AOGCC MIT-IA Passed to 3433 psi 12/03/23: AOGCC MIT-T passed to 3547 psi 12/02/23: Set TTP @ 6429' MD Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 WBL Steps: 1 S ATTEMPT TO CYCLE SLIDING SLEEVE CLOSED AND MIT-IA TO 3200 PSI. CONTINGENT ISOLATION SLEEVE SET AND MIT-IA TO 3200 PSI.Complete on 2/24/24 2 F PERFORM MIT-IA TO 3,200 PSI.Complete on 2/24/24 3 F PERFORM AOGCC MIT-IA TO 3,200 PSI Complete on 2/29/24 1 S ISOLATION SLEEVE SET AND MIT-IA TO 3200 PSI. 2 F PERFORM MIT-IA TO 3,200 PSI 3 F PERFORM AOGCC MIT-IA TO 3,200 PSI Procedural Steps: Slickline Complete on 2/24/24 – MIT-IA to 3,500 psi passed after cycling sleeve 1. MIRU SL and FB. 2. RIH with shifting tool and cycle Baker Defender SSD closed (Up to Close). a. On the previous SL rig up in December 2023 SL set down in the SSD while running a 3-1/2" brush and 2.80" G-ring. There is a possibility that the sleeve was partially shifted during this set down leading to the TxIA communication. 3. Perform MIT-IA to 3,500 psi. a. If MIT-IA passes rig down slickline. 4. If MIT-IA fails, RIH with isolation sleeve. Set isolation sleeve in the lock profile of sliding sleeve. 5. Perform MIT-IA to 3,500 psi. Fullbore Complete on 2/29/24 – AOGCC Witnessed MIT-IA to 3,592 psi passed 1. Place well on injection and perform AOGCC MIT-IA to 3,500 psi. Slickline – Well is exhibiting IA repressurization after shifting sleeve closed and passing MIT-IA 1. MIRU SL and FB. 2. RIH with isolation sleeve. Set isolation sleeve in the lock profile of sliding sleeve. 3. Perform MIT-IA to 3,500 psi. Fullbore 1. Place well on injection and perform AOGCC MIT-IA to 3,500 psi. Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Current Wellbore Schematic: Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Proposed Wellbore Schematic: Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d R i g W o r k o v e r S u n d r y P r o c e d u r e Da t e : M a r c h 5 , 2 0 2 4 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l S - 2 0 1 A Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a ng e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Date:Tuesday, March 5, 2024 12:33:34 PM Attachments:Sundry_324-108-108_022724.pdf S-201A.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, March 5, 2024 12:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, Injector S-201A (PTD #2190920) was put on injection on 02/27/24 and an AOGCC witnessed MIT-IA passed on 02/29/24. On 03/01 and 03/02 the operator bled the IA pressure. Since those bleeds the IA pressure has slowly climbed to ~800 psi. At this time, it is not clear if the slow increase in IA pressure is from thermal effects from the warming of fluids pumped during the offline and online MITs or from TxIA communication. Sundry #324-108 was approved to set an isolation sleeve across the sliding sleeve in the event the MIT-IA failed. Our plan is to bleed the IA pressure one more time and if the IA pressure continues to increase then we can rule out thermal effects. In that case, the well will be shut-in and the isolation sleeve will be set. Plan Forward: 1. DHD: Bleed IAP 2. Well Integrity: Monitor 3. Slickline (pending): Set isolation sleeve 4. Well Integrity (pending): Resume injection and continue to monitor Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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 AA SH 3000 642' REF �H/ 62..4 RF R FV 1 Max An91e = 630 0 3686'� �Da4im M)= 6636' W"' YwF, LroVv I U' U=O.0A I- ±!-O MILLOUT WNDOW(S-201A) 5767'-5778' 3-02"TOC 5267- .0383 hot ID = 6.276" Minimum ID = 2.813" @ 2087' 3-1/2" HES X NIPPLE INJECTION STATIONS "2A' FROM BOTTOM OF GLM'• NO DEPTH ID GAUGEADDRESS DATE ZONE 9 6519 2.96" 9 0110520 Nb 8 6637 2.96" 8 0110520 OA 7 6657 2.96" 7 01/0520 OA 6 6686 2.96" 6 0110520 OBa 5 6706 2.96" 5 01/0520 OBa 4 6735 2.96" 4 01/0520 OBb 3 6790 2.96" 3 0110520 OBc 2 6854 2.96" 2 01/0520 OBd 1 6875 2.96" 1 01l0520 OBd RESTRICTION, POSSIBLE BUCKLED TBG, FULL OD WILL PASS BUT NOT LONGER THAN -3', 10' X 2.25- WILL, 10' X 2.50' WONT (11/1021) PBTD 7061' 3-12" TBG, 929, L-80 VT, .0087 W ID = 2.992" 71153' n 7169' SAFETY NOTES: MAX DLS: 12.6' @6417'. S-201A 3-12" HES X NIP, ID=2.813" 4936' 3-12" HP DENDER SLD SLV, =2.960" SLD SLEEVE CFEDLOSED (022424) ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 6515 4983 31 BGLO DMY BK 0 0310820 8 6632 5080 38 BGLO DMY BK 0 03/08/20 7 6652 5095 39 BGLO RWF BK 10 042521 6 6681 5118 39 BGLO DMY BK 0 0310820 5 6701 5134 39 BGLO RWF BK 12 042521 4 6730 5156 39 BGLO RWF BK 14 042521 3 6785 5199 40 BGLO RWF BK 14 042521 2 6850 5248 40 BGLO FLWSL BK �- 042521 1 6870 5264 40 BGLO DMY BK 0 0310820 6429' 3-12' HES X NIP, D=2.813' 6515' �1" BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #9 6571' 3-12' HES X NIP, D = 2.813' 66 I- BKR SIDE POCKET MANDREL w/ (GAUGE CLAMP #8 6652' 1' BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #7 6687' l'BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #6 6701' 1' BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #5 6730' 1'BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #4 6758' 3-12- HES X NIP, D=2.813' 6785' 1'BKR SIDE POCKET MANDRELw/ GAUGE CLAMP #3 68� 342' HES X NIP, D = 2.813" 6822' MODIFIED RMX PLUG BODY(042421) 6850' 1' BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #2 6870' 1' BKR SIDE POCKET MANDREL w/ GAUGE CLAMP #1 693W 312'HESX NIP. D=2.813- DATE REV BY COM 13M DATE REV BY COMMENTS 12113100 PGS ORIGINAL COMPLETION 11/1021 BSUJMD EDITED D N RESTRICTION 0110620 P-272 SIDETRACK(S-201A) 09/1123 RB/JMO TREE CJO(09/07/23) 012720 KR/JMJ FINAL ODE APPROVAL 09/1123 CK/JM) SET XX PLUG (09/0623) 042721 BSE/JMD WFR CJO (04/2421) 09/1523 CK/JM) PULLED XX PLUG (09/1023) 042721 BSE/JNID SET RMX RUG BODY (042521) 042721 BSE/JNID RESTRICTUIN N TBG (042521) POLARIS UNIT WELL: S-201A PERMIT No: 219-092 AR No: 50-029-22987-01 SEC 35, T12N, R12E, 4587' FSL & 4496' FEL Hloorp North Slope, LLC 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Date:Tuesday, February 27, 2024 9:11:03 AM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, February 26, 2024 2:46 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Andy, The plan forward as below is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 25, 2024 8:38:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request to put WAG Injector S-201A (PTD #2190920) under evaluation and bring online Mr. Wallace, WAG Injector S-201A (PTD #2190920) was shut-in last month when it was flagged for anomalous IA re-pressurization. It was classified to not operable after it failed an offline MIT-IA, losing more than 10% of the total test pressure in 5 minutes. On 02/13/24 an E-line LDL identified a leak in the sliding sleeve at 4936’ MD. On 02/24/24 Slickline discovered that the sliding sleeve was partially open and shifted it closed. A subsequent offline MIT-IA passed to 3,321 psi. Hilcorp is requesting permission to resume injection, perform an AOGCC witnessed MIT-IA and monitor for any signs of communication. Plan Forward if you approve: 1. Well Integrity: classify as under evaluation 2. Operations: put on injection 3. Fullbore: AOGCC witnessed MIT-IA 4. Well Integrity: Monitor for TxIA communication 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: PB Wells Integrity Sent: Friday, January 19, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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. TRff= 4"CMVFLS 1AR l PFAD= FLn OKB. EDEV = 64.42' REF ELBf = 82.64' BF. ELEV = 37.68' KOP= 1800, Mar Annla = 83^ Gil 3RR8' 19-5/8' CSG, 40#, L-80-13TG D = 8.835• J— 3190' — MILLOUT WNDOW(S-201A) 5767'-5778' 3-1rz•Toc 526-r WHIPSTOCK(12/31M9) 576T 7• CSG, 26#, L-8O, BTC-M, .0383 bpf, ID = 6.276' ^5767' Minimum ID = 2.813" @ 2087' 3-1/2" HES X NIPPLE INJECTION STATIONS "-2A' FROM BOTTOM OF GLM'• NO DEPTH ID GAUGEADDRESS DATE ZONE 9 6519 2.96" 9 01/05/20 Nb 8 6637 2.96" 8 0110520 OA 7 6657 2.96" 7 0110520 OA 6 6686 2.96" 6 0110520 OBa 5 6706 2.96" 5 0110520 OBa 4 6735 2.96" 4 01/0520 OBb 3 6790 2.96" 3 01/0520 OBc 2 6854 2.96" 2 01/0520 0' 1 6875 2.96" 1 01/0520 OBd RESTRICTION, POSSIBLE BUCKLED TBG, FULL OD WILL PASS BUT NOT LONGER THAN —3', 10' X 2.25• WILL, 10' X 2.50' WON'T (1111021) PBTD 7061' L-80 VT, .0087 bpf, ID = 2.992' 7153' n SAFETY NOTES: MAX DLS: 12.60 @6417'. S-201A 2087' H3-12" HES X NIP, ID=2.813" 3-112' HP DEFENDER SLD SLV, D=2.960' SLD SLEEVE CLOSED (03/0820) 9 6515 4983 31 BGLO DMY BK 0 03/08/20 8 6632 5080 38 BGLO DMY BK 0 03/08/20 7 6652 5095 39 BGLO RWF BK 10 0425/21 6 6681 5118 39 BGLO DMY BK 0 0310820 5 6701 5134 39 BGLO RWF BK 12 042521 4 6730 5156 39 BGLO RWF BK 14 0425/21 3 6785 5199 40 BGLO RWF BK 14 0425/21 2 6850 5248 40 BGLO FLWSL BK — 0425/21 1 6870 5264 40 1 BGLO DMY BK 0 03/08/20 6429' —�3IWHESXNP,D=2.813- 6515' l' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #9 6571' 342- HES X NP, D = 2.813- 6632' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #8 6652' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #7 6681' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #6 6707' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #5 6T30' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #4 6758' 3-12'HESX NIP, D=2.813' 6785' 1"BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #3 6822' 3-1/2'HES X NIP, D = 2.813' 6822' MODIFIED RMX PLUG BODY(D42421) 6850' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #2 68T0' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #1 3-12'HESXNIP, 1)=2.813' DATE REV BY COMVB'TTS DATE REV BY OOMVENTS 12/13/00 PGS ORIGINAL COMPLEFION 11/10/21 BSEfJMD EDITED D IN RESTRICTION 0110620 P-272 SIDEFRACK(S-201A) 09/11/23 RB/JMD TRUE C/O(09107/23) 012720 IMJMD FINAL ODEAPPROVAL 09/11/23 CK/JMD SLTXX PLUG (09/06/23) 042721 BSEfJrAD WFR C/O (042421) 09/15/23 CK/JMD PULLEDXX PLUG (09110/23) 0427/21 BSE/JMD SET RMX PLUG BODY(042521) 042721 BSE/JrvU RESTRICTION IN TBG (042521) POLARIS UNIT WELL S-201A PERMT No: 219-092 AR No: 50-029-22987-01 SEC 35, T12K R12E, 458T FSL & 4496' FE L Hlcorp North Slope, LLC 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 S-201A Set Isolation Sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-092 50-029-22987-01-00 484A ADL0028257, 0028258 7169 Conductor Surface Intermediate Production Liner 5492 80 3162 5723 7110 6822 20" 9-5/8" 7" 3-1/2" 5227 47 - 127 47 - 3209 44 - 5767 43 - 7153 1500 47 - 127 47 - 2864 44 - 4317 43 - 5480 None 3190 5410 10530 6822 5750 7240 10160 6519 - 6876 None N/A N/A4987 - 5268 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY 2/24/2024 Current Pools: POLARIS OIL Proposed Pools: POLARIS 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 12:41 pm, Feb 23, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.02.23 12:24:31 -09'00' Torin Roschinger (4662) 324-108 23-FEB-2024 DSR-2/26/24 Mel Rixse 10-404 Yes SFD 2/23/2024 AOGCC to witness MIT-IA to 3500 psi within 10 days of stabilized injection. MGR23FEB24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 12:47:29 -09'00'02/27/24 RBDMS JSB 022824 Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Well Name:S-201A Permit to Drill:219-012 Current Status:Not Operable, WAG API Number:50-029-22987-01-00 Estimated Start Date:February 2024 Estimated Duration:2days Regulatory Contact:Abbie Barker Revision:0 First Call Engineer:Leslie Reavis (907) 777-8326 (O)(907) 440-7692 (M) Second Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Current Bottom Hole Pressure:2,000 psi @ 5,000’ TVDss 8.46 ppg | Based on offset wells Max Anticipated Surface Pressure:1,500 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:1,100 psi 4/25/2021 Min ID:2.813” @ 2,087’ MD X-Nipple Max Angle:63 deg @ 3,686’ MD Last Tag:6,822’ MD SL Tag 4/25/2021 Brief Well Summary: WAG well S-201A (PTD# 219-012) currently operates under an AA due to the packerless completion. Slickline set a tubing plug 12/2/23 and the well passed an AOGCC witnessed MIT-T a day later. The plug was pulled and an AOGCC witnessed MIT-IA passed on 12/16/23. Shortly after the MIT-IA the well started showing signs of TxIA comm. A subsequent MIT-IA that was performed on 1/18/24 failed, losing 330 psi in the first 5 min of the test. An LDL was run on E-line 2/13/24 and found a leak at the sliding sleeve at 4,936' MD. During the December slickline rig-up it was noted that a 3.5” brush and 2.80” gauge ring sat down in the sliding sleeve while performing a drift run. The sliding sleeve is functioned down to open. There is a potential that the sleeve was partially shifted open when the tools sat down leading to the TxIA communication. Note: there is a known tight spot at 6758' MD. Objective: - Attempt to cycle sliding sleeve closed and perform an MIT-IA. - If MIT-IA still fails after cycling sleeve, a contingent isolation sleeve will be set across the leaking sliding sleeve. - Return well to injection Current Status: Not Operable WAG (on MI), Shrader Bluff (Polaris Pool), Shut-in Recent Integrity: 02/13/24: LDL ID Leak @ 4937' MD SS MIT-IA Failed 01/18/24: AOGCC MIT-IA Failed lost 330 psi in 5 minutes 01/10/24: PPPOT-T Passed 12/16/23: AOGCC MIT-IA Passed to 3433 psi 12/03/23: AOGCC MIT-T passed to 3547 psi 12/02/23: Set TTP @ 6429' MD WBL Steps: 1 S ATTEMPT TO CYCLE SLIDING SLEEVE CLOSED AND MIT-IA TO 3200 PSI. CONTINGENT ISOLATION SLEEVE SET AND MIT-IA TO 3200 PSI. 2 F PERFORM MIT-IA TO 3,200 PSI. 3 F PERFORM AOGCC MIT-IA TO 3,200 PSI Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Procedural Steps: Slickline 1. MIRU SL and FB. 2. RIH with shifting tool and cycle Baker Defender SSD closed (Up to Close). a. On the previous SL rig up in December 2023 SL set down in the SSD while running a 3-1/2" brush and 2.80" G-ring. There is a possibility that the sleeve was partially shifted during this set down leading to the TxIA communication. 3. Perform MIT-IA to 3,500 psi. a. If MIT-IA passes rig down slickline. 4. If MIT-IA fails, RIH with isolation sleeve. Set isolation sleeve in the lock profile of sliding sleeve. 5. Perform MIT-IA to 3,500 psi. Fullbore 1. Place well on injection and perform AOGCC MIT-IA to 3,500 psi. Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Current Wellbore Schematic: Tubing Integrity Repair Sundry Well: S-201A PTD: 219-012 Proposed Wellbore Schematic: Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d R i g W o r k o v e r S u n d r y P r o c e d u r e Da t e : F e b r u a r y 2 3 , 2 0 2 4 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l S - 2 0 1 A Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a ng e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Date:Friday, January 19, 2024 11:33:10 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 19, 2024 9:56 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) Offline MIT-IA failed Mr. Wallace, WAG Injector S-201A (PTD #2190920) failed offline diagnostic MIT-IA on 01/18/24 with IA casing pressure losing 330 psi in 5 minutes with no surface pressure change observed on the tubing or OA. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Date:Tuesday, January 9, 2024 8:49:02 AM Attachments:S-201A.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 4, 2024 8:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-201A (PTD #2190920) Possible TxIA communication Mr. Wallace, WAG Injector S-201A (PTD #2190920) operates under AA AIO 25A.022 for continued WAG Injection with a cement packer design. The well recently passed an AOGCC witnessed MIT-IA on 12/16/23. However, since the passing MIT-IA, multiple IA bleeds have been performed and the IA pressure continues to increase. The IA pressure trend continuing to increase after multiple IA bleeds suggests the IA re-pressurization is not due to thermal effects. Operations has been instructed to shut the well in as per approval conditions in the AA. The well will now be classified as UNDER EVALUATION for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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, please TRff= 4"CMVFLS 1AR l PFAD= FLn OKB. EDEV = 64.42' REF ELBf = 82.64' BF. ELEV = 37.68' KOP= 1800, Mar Annla = 83^ Gil 3RR8' 19-5/8' CSG, 40#, L-80-13TG D = 8.835• J— 3190' — MILLOUT WNDOW(S-201A) 5767'-5778' 3-1rz•Toc 526-r WHIPSTOCK(12/31M9) 576T 7• CSG, 26#, L-8O, BTC-M, .0383 bpf, ID = 6.276' ^5767' Minimum ID = 2.813" @ 2087' 3-1/2" HES X NIPPLE INJECTION STATIONS "-2A' FROM BOTTOM OF GLM'• NO DEPTH ID GAUGEADDRESS DATE ZONE 9 6519 2.96" 9 01/05/20 Nb 8 6637 2.96" 8 0110520 OA 7 6657 2.96" 7 0110520 OA 6 6686 2.96" 6 0110520 OBa 5 6706 2.96" 5 0110520 OBa 4 6735 2.96" 4 01/0520 OBb 3 6790 2.96" 3 01/0520 OBc 2 6854 2.96" 2 01/0520 0' 1 6875 2.96" 1 01/0520 OBd RESTRICTION, POSSIBLE BUCKLED TBG, FULL OD WILL PASS BUT NOT LONGER THAN —3', 10' X 2.25• WILL, 10' X 2.50' WON'T (1111021) PBTD 7061' L-80 VT, .0087 bpf, ID = 2.992' 7153' n SAFETY NOTES: MAX DLS: 12.60 @6417'. S-201A 2087' H3-12" HES X NIP, ID=2.813" 3-112' HP DEFENDER SLD SLV, D=2.960' SLD SLEEVE CLOSED (03/0820) 9 6515 4983 31 BGLO DMY BK 0 03/08/20 8 6632 5080 38 BGLO DMY BK 0 03/08/20 7 6652 5095 39 BGLO RWF BK 10 0425/21 6 6681 5118 39 BGLO DMY BK 0 0310820 5 6701 5134 39 BGLO RWF BK 12 042521 4 6730 5156 39 BGLO RWF BK 14 0425/21 3 6785 5199 40 BGLO RWF BK 14 0425/21 2 6850 5248 40 BGLO FLWSL BK — 0425/21 1 6870 5264 40 1 BGLO DMY BK 0 03/08/20 6429' —�3IWHESXNP,D=2.813- 6515' l' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #9 6571' 342- HES X NP, D = 2.813- 6632' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #8 6652' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #7 6681' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #6 6707' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #5 6T30' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #4 6758' 3-12'HESX NIP, D=2.813' 6785' 1"BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #3 6822' 3-1/2'HES X NIP, D = 2.813' 6822' MODIFIED RMX PLUG BODY(D42421) 6850' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #2 68T0' 1' BKR SIDE POCKET MANDREL W/ GAUGE CLAMP #1 3-12'HESXNIP, 1)=2.813' DATE REV BY COMVB'TTS DATE REV BY OOMVENTS 12/13/00 PGS ORIGINAL COMPLEFION 11/10/21 BSEfJMD EDITED D IN RESTRICTION 0110620 P-272 SIDEFRACK(S-201A) 09/11/23 RB/JMD TRUE C/O(09107/23) 012720 IMJMD FINAL ODEAPPROVAL 09/11/23 CK/JMD SLTXX PLUG (09/06/23) 042721 BSEfJrAD WFR C/O (042421) 09/15/23 CK/JMD PULLEDXX PLUG (09110/23) 0427/21 BSE/JMD SET RMX PLUG BODY(042521) 042721 BSE/JrvU RESTRICTION IN TBG (042521) POLARIS UNIT WELL S-201A PERMT No: 219-092 AR No: 50-029-22987-01 SEC 35, T12K R12E, 458T FSL & 4496' FE L Hlcorp North Slope, LLC TIO PIW �iu. —a a..a ♦ aP..a. aE Uninp • wa.em �xnx_u +nux_w —._ anx oon � rux anon �u.x=wrcr aen a= MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/25/2024 S-201A 50-029-22987-01-00 219-092-0 G SPT 4001 2190920 3410 1990 1991 1990 1990 409 431 428 428 REQVAR P Guy Cook 12/16/2023 2 year MITIA per AA AIO 25A.022. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 0 3754 3485 3433IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC231215133651 BBL Pumped:5.3 BBL Returned:3.4 Thursday, January 25, 2024 Page 1 of 1           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 18, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/18/2024 S-201A 50-029-22987-01-00 219-092-0 N SPT 4001 2190920 3410 1667 3675 3578 3547 374 373 373 371 REQVAR P Austin McLeod 12/3/2023 Two year MITT to 1.1x MAIP. AIO 25A.022. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM231203133637 BBL Pumped:0.4 BBL Returned:0.5 Thursday, January 18, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 25A.022.MITT James B. Regg Digitally signed by James B. Regg Date: 2024.01.18 14:01:32 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-201A PRUDHOE BAY UN POL S-201A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 S-201A 50-029-22987-01-00 219-092-0 W SPT 4001 2190920 3410 1277 1279 1278 1279 519 566 564 562 REQVAR P Guy Cook 5/28/2022 2 year MITIA to 1.1 times max anticipater header injection pressure (MI header pressure = 3100 psi.) per AA AIO 25A.022. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-201A Inspection Date: Tubing OA Packer Depth 710 3752 3523 3474IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220527181408 BBL Pumped:2.6 BBL Returned:2.6 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 MITIA 1.1 times max anticipater header injection pressure AA AIO 25A.022. James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 14:14:02 -08'00' 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG Injector S-201A (PTD #2190920) will need AOGCC witnessed MIT-IA Date:Wednesday, May 25, 2022 9:25:49 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, May 22, 2022 4:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector S-201A (PTD #2190920) will need AOGCC witnessed MIT-IA Mr. Wallace, Drilling on M-pad is complete and injection on S-201A (PTD # 2190920) is ready to resume. The well is now classified as OPERABLE and an AOGCC witnessed MIT-IA will be scheduled when on stabilized injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, April 28, 2022 1:39 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) will lapse on AOGCC MIT-IA Mr. Wallace, WAG Injector S-201A (PTD #2190920) is due for its 2-year AOGCC MIT-IA by the end of April. The well is currently shut-in for reservoir management due to drilling on M-pad. It will not be online before it lapses on the required MIT-IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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 hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately 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 the onward 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. 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) will lapse on AOGCC MIT-IA Date:Thursday, May 5, 2022 12:22:17 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, April 28, 2022 1:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector S-201A (PTD #2190920) will lapse on AOGCC MIT-IA Mr. Wallace, WAG Injector S-201A (PTD #2190920) is due for its 2-year AOGCC MIT-IA by the end of April. The well is currently shut-in for reservoir management due to drilling on M-pad. It will not be online before it lapses on the required MIT-IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 the onward 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. MEMORANDUM To: Jim Regg '-q �C- ) 7-12.4 J'40-2AP.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 15, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-201 A PRUDHOE BAY UN POL S-201 A Sre: Inspector Reviewed By: P.I. Supry I�I� Comm Well Name PRUDHOE BAY UN POL S -201A API Well Number 50-029-22987-01-00 Inspector Name: Bob Noble Permit Number: 219-092-0 Inspection Date: 12/2/2021 Insp Num: initRCN211204141816 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S -201A Type Inj N . TVD 4001 Tubing 1054 - 3600 3455 3433 ' PTD 2190920 Type Test SPT Test psi 3300 IA 0 0 0 0 BBL Pumped: 0.7 - BBL Returned: 0.7 OA 56 246 245. 246 Interval OTHER P/F P Notes: MIT -T every 2 years to 1.1 max anticipated injection pressure for WAG injector with cement packers. Wednesday, December 15, 2021 Page I of I MEMORANDUM State of Alaska Insp Num: mitRCN211204142703 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Wednesday, December 15, 2021 TO: Jim Regg P.I. Supervisor (ZtJL( SUBJECT: Mechanical Integrity Tests Well Hilcorp North Slope, LLC Type Inj S -201A FROM: Bob Noble PRUDHOE BAY UN POL S-20 IA Petroleum Inspector 906 3654 - Src: Inspector 3447 . Reviewed By: p P.I. Supry �1TJF� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S -201A API Well Number 50-029-22987-01-00 Inspector Name: Bob Noble Permit Number: 219-092-0 Inspection Date: 12/3/2021 Insp Num: mitRCN211204142703 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S -201A - Type Inj N -TVD 4001 Tubing 906 3654 - 3507 3447 . PTD 2190920 Type Test SPT/ Test psi 3300 IA 904 3634 3508 3461 BBL Pumped: 2.7 BBL Returned: 2.7 OA 253 266 265 264 Interval OTHER - P/F P Notes: MIT Combo every 2 years to 1.1 max anticipated injection pressure for WAG injector with cement packers. ✓ C- LUT -T X*A Wednesday, December 15, 2021 Page 1 of 1 From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector S-201A (PTD # 2190920) Passed 2-year AOGCC MIT-T and CMIT-TxIA Date:Monday, December 6, 2021 11:08:42 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 3, 2021 3:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector S-201A (PTD # 2190920) Passed 2-year AOGCC MIT-T and CMIT-TxIA Mr. Wallace, Injector S-201A (PTD #2190920) passed an AOGCC witnessed MIT-T and CMIT-TxIA on 12/03/21. The well will now be classified back to Operable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Tuesday, November 30, 2021 4:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector S-201A (PTD # 2190920) Lapse on 2 year required AOGCC MIT-T and CMIT Mr. Wallace, Injector S-201A (PTD # 2190920) has a unique completion design and is due for required 2 year AOGCC MIT-T and CMIT-TxIA in the month of November. The well has been shut in and is now classified as NOT OPERABLE. Slickline is arriving to secure and AOGCC testing will be conducted prior to putting the well back on injection. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately 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 the onward 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/16/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 13-20 500292070500 182009 05/08/2021 RCBL HALLIBURTON E-34A 500292243701 214096 06/06/2021 RCBL READ CH G-18B 500292062002 214071 05/23/2021 RCBL HALLIBURTON S-201A 500292298701 219092 05/29/2021 IPROF-WFL and ANALYSIS HALLIBURTON S-210 500292363000 219057 04/27/2021 IPROF-WFL and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 PPROF and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 RCBL HALLIBURTON Z-11A 500292205301 205031 05/18/2021 RCBL HALLIBURTON Z-31 500292187100 188112 06/07/2021 RCBL HALLIBURTON Please include current contact information if different from above. Received By: 06/16/2021 37' (6HW By Abby Bell at 10:04 am, Jun 16, 2021 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22987-01-00Well Name/No. PRUDHOE BAY UN POL S-201ACompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2190920Operator BP Exploration (Alaska) Inc.MD7169TVD5492Current StatusWAGIN6/4/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD/GR/RES/DEN/NEU, Cement EvalNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC2/11/20205696 7169 Electronic Data Set, Filename: S-201A_BH_LTK_MEM_Composite Drilling Depth Data.las32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_2MD_Memory Drilling Log.cgm32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_2TVDSS_Memory Drilling Log.cgm32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_5MD_Memory Drilling Log.cgm32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_5TVDSS_Memory Drilling Log.cgm32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_5TVDSS_Memory Drilling Log.cgm.meta32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_OTK-VSS_RLT-MEM_Composite Drilling Dynamics.cgm32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_MEM_Composite Drilling Depth Data.dls32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_2MD_Memory Drilling Log.pdf32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_2TVDSS_Memory Drilling Log.pdf32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_LTK_5MD_Memory Drilling Log.pdf32032EDDigital DataThursday, June 4, 2020AOGCCPage 1 of 3S-,201A_BH_LTK_MEM_Composite Drilling Depth _Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22987-01-00Well Name/No. PRUDHOE BAY UN POL S-201ACompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2190920Operator BP Exploration (Alaska) Inc.MD7169TVD5492Current StatusWAGIN6/4/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:3/6/2020Release Date:7/1/2019C2/11/2020 Electronic File: S-201A_BH_LTK_5TVDSS_Memory Drilling Log.pdf32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_Final Surveys Report.csv32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_Final Surveys Report.pdf32032EDDigital DataC2/11/2020 Electronic File: S-201A_BH_Final Surveys Report.txt32032EDDigital Data0 0 2190920 PRUDHOE BAY UN POL S-201A LOG HEADERS32032LogLog Header ScansDF5/29/2020 Electronic File: S-201A_RBT_25FEB20.dlis33272EDDigital DataDF5/29/2020 Electronic File: S-201A_RBT_25FEB20.pdf33272EDDigital DataDF5/29/2020 Electronic File: S-201A_RBT_25FEB20_img.tiff33272EDDigital Data0 0 2190920 PRUDHOE BAY UN POL S-201A LOG HEADERS33272LogLog Header ScansThursday, June 4, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22987-01-00Well Name/No. PRUDHOE BAY UN POL S-201ACompletion StatusWAGINCompletion Date3/6/2020Permit to Drill2190920Operator BP Exploration (Alaska) Inc.MD7169TVD5492Current StatusWAGIN6/4/2020UICYesComments:Compliance Reviewed By:Date:Thursday, June 4, 2020AOGCCPage 3 of 3M. Guhl6/4/2020 Date: 5/29/2020 Transmittal Number: 93766 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 The digital zip file for the well log package listed below is being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format S-201A 2/25/2020 Halliburton RBT/SCMT Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ Received by the AOGCC 05/29/2020 PTD: 2190920 E-Set: 33272 Signed for by Abby Bell 05/29/2020 MEMORANDUM TO: Jim Regg 17'9 1 i I ZtrLC P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 13, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. S -201A PRUDHOE BAY UN POL S-201 A Src: Inspector Reviewed By:i P.I. Supry J �� Comm Well Name PRUDHOE BAY UN POL S -201A API Well Number 50-029-22987-01-00 Inspector Name: Austin McLeod Permit Number: 219-092-0 Inspection Date: 4/21/2020 Insp Num: mitSAM200421151437 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min !,i .TVcoot mg 2780 2753 2751 � 2751 - Well - S -201A Type In' � °' D Tub - . -- YP J PTD 2190920 Type Test SPT 'Test psi 1500 IA las 21�15�2032 . 2008 - BBL Pumped: I.2 -IBBL Returned: I O Isa I176 176 Interval INITAL PAF P Notes: Initial after converted to an injector. Packer TVD is TOC. Cement packer (500'). Wednesday, May 13, 2020 Page I of I 1 Winston, Hugh E (CED) From:Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent:Monday, April 20, 2020 4:35 PM To:AOGCC Reporting (CED sponsored) Subject:PBU S-201A / PTD # 219-092 Hello, Please reference the following well: Well Name: PBU S-201A Permit #: 219-092 API #: 50-029-22987-01-00 This well began Injection on: 4/18/2020 Method of Operations on this date: Miscible Gas Injection From:AK, GWO SUPT Well Integrity To:Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek Cc:Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject:OPERABLE: Injector S-201A (PTD #2190920) Converted from development to injector post RWO Date:Wednesday, April 15, 2020 7:47:41 AM All, WAG Injector S-201A (PTD #2190920) has been converted from a jet pump development well to a WAG injection well post RWO completed on 01/12/20. The IA NOL has been lowered from 2900 psi to 2000 psi with this conversion. The well is now classified as OPERABLE and may be put on injection. Plan forward: 1. Operation: Put on injection – Liquid packed annuli, anticipate AFE 2. DHD: AOGCC MIT-IA Please respond with any questions. Ryan Holt Well Integrity BP Global Wells Organization – Alaska Office: 907-659-5102 1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service 5 BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 219-092 12/31/2019 1/2/2020 GL PRUDHOE BAY, POLARIS OIL 4a. Surface: Top of Productive Interval: Total Depth: 4587' FSL, 4496' FEL, Sec. 35, T12N, R12E, UM 2163' FSL, 412' FEL, Sec. 27, T12N, R12E, UM 1861' FSL, 409' FEL, Sec. 27, T12N, R12E, UM Surface: x- y- Zone -618930 5980790 ASP 4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG 5 WDSPL No. of Completions: 3/6/2020 15. 50-029-22987-01-00 16. PBU S-201A Well Name and Number: 7061' / 5409' 35.84 17. TPI:y- Zone -617685 ASP 4x-5983627 Total Depth: x-y-Zone -617963 ASP 45983325 7169' / 5492' 2087' / 2077' (Nipple) DNR Approval Number:19. 83-47 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR / RES / DEN / NEU, Cement Evaluation CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 7" 3-1/2" 91.5# 40# 26# 9.3# L-80 L-80 L-80 47' 44' 43' 5767' 7153' 47' 44' 43'5480' 4317' 6-1/8" 8-3/4" 260 sx Arctic Set (Approx.) 421 sx Class 'G' 296 sx Acid Soluble Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Injection N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 200' Open to production or injection?Yes 5 No 24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 6519' - 6875' 4987' - 5267' H-40 127'30"20" 9-5/8"47'3209'12-1/4"385 sx AS Lite III, 280 sx Class 'G'47'2864' Freeze Protect w/ 7 Bbls Diesel Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 127' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028257 & 028258 Other 12. SSSV Depth (MD/TVD): Injection Stations 3/6/2020 Ref Elevations BF 37.68 (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 82.64 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 5767' / 4317' 1900' (Approx.) Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 8:12 am, Apr 06, 2020 RBDMS HEW 4/8/2020 SFD 4/6/2020 617693 HEW Completion Date 3/6/2020 HEW DSR-4/6/2020 617963 G MGR13APR20 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Raese, J. Kyle Contact Email:john.raese@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 9075644629 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 6269' 6320' 6354' 6363' 6430' 6494' 6513' 6544' 6553' 6632' 6681' 6728' 6787' 6849' 6916' 6972' 7025' 4759' 4807' 4838' 4847' 4908' 4965' 4982' 5008' 5015' 5080' 5118' 5155' 5200' 5247' 5298' 5341' 5382' Schrader Bluff MA Schrader Bluff MB Schrader Bluff MC Schrader Bluff MD Schrader Bluff MF Schrader Bluff NA Schrader Bluff NB Schrader Bluff NC Schrader Bluff NE Schrader Bluff OA Schrader Bluff OBa Schrader Bluff OBb Schrader Bluff OBc Schrader Bluff OBd Schrader Bluff OBe Schrader Bluff OBf Schrader Bluff OBf Base Schrader Bluff OBf Base 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 7025'5382' Top of Productive Interval 6513'4982' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. LOT / FIT Summary, Summary of Daily Drilling Reports, Summary of Post-Rig Work, Survey, Cement Report, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.03 12:06:27 -08'00' o88=û ~8û ß8ZZ8OP=û }[fû OfoÜOom=û [Ofû~8û mÕw8Z8=û ÓgÀûgÌgÝ¸û 3 »}wû8Z8=û mÒ=û [qùOóçíêû=û Pqû[P=û PqÛPû=û FBd*%û:ûz1-:ûB %1B2):û7û% %dû Yp,û Y( ûr]aMKLWtû û ÄàEQÖ)4ûc#*²c«cFuûÅû VHûAû#N-Aû6%1Aû¼)6 ûx1%û¡ûQû7ûNx#VNHû £û UB Uû ,û 3 û û 3 û û13 3 3 °µ6.DHûEûäû!QAûQû7#§%.Hû 6.*#ûEûÁ!ûû:û7û# FN1 Æûûû4û 1*1%D1u 5û '+ &û¾ û9Ñ+ ,û'( & û û ð û Gû ñ û GGû Í>Xû 9&û {Øû û $û û 3û Jû +û û 0û û û û 3û Jû +û û 0û û û û 3û Sâû +û û 0û û û û 3û Jû +û û 0û û û $û û 3û S^û +û û C0û $û û û û 3û S^û +û û C0û û û û $û 3û S^û +û û C0û û û $û $û 3û S^û +û û C0û (û û û û û û $û û û û &*'#"/&+*3./ /&+*3 3$-,)3!,00,)3,$3%(3 9,Xû Âp3 û' & û û 5û û û 5û û û 5û û û 5û û û 5û û û 5û $û û 5û û $û 5û û û 5û û 'û, û ;<û ;<û ;<û ;<û ;<û ;<û ;<û ;<û ;<û "û "û "û "û "û "û "û "û "û F#Hû ( û (û 'û 'û û û û éû û û 3 3±6.DHû)2Aû Fb#-Aû6%1ûÞ)Aûb11%VûAûQ7û#bFû 2 3 3 ', û & Gû Jû > (,û 'Ùû LM¨L³yKû \]û nllWû|nÎ\hÚnû C0û KLy´¯Kû \aM¶Mû ]l¿h×º|Êû r]aMKLWtû $C0û "û +9R û ,& û û "û R û &3ûXû>&& >,(û ""û +ÔR û iÏ¹û û'99&G'û "û 'æªR û ' û( û,û >,(û û & Gû Jû û û 3 3 3 3 3 3 3 3 3 3 3 3 3 3 > (,û $û $û 3û Jû +û û j6.DûEû_û!:ûû7# ·.û /Tû2ûû4)û!û@*û kû?ûû-Fû î¤B/DûEûåû!:û7û# %/û /û2ûû4)û !û@*û Iû?ûû-%û /û2ûû4)û!û@*û kû?ûû-Vû /ûTû2ûû4)û!û@*û Iû?ûû-Nû /û2ûû4)û!û@*û Iû?ûû-dû/ûTû2ûû4)û!û@*û Iû?ûû-zû Ã6.DûEû_û!:ûû7û# %.û Ç ¢ /Tû2ûû4)û!û@*û Iû?ûû-û j6.DE_!:7# %.û /û2ûû4)û!û@*û kû?ûû-#û /Tû2ûû4)û!û@*û Iû?ûû-/û j6.DE_!:7# %.û C0û X¬È û ûGû> ûs"vû 9{&Yûp(û áeû B'û 9 &û(eû ¥ûR9ËÉ ûã&û>©Ðûs®C0vû '9Yû(eû BB¦û >û`û,(`û & `û $Uûiûû$$Uûi û ½\ûhúõïöøëôûWò÷ìèû Test Date Test Type Test Depth (TMD-Ft) Test Depth (TVD-Ft) AMW (ppg) Surface Pressure (psi) Leak Off Pressure (BHP) (psi) EMW (ppg) 12/31/19 FIT 5,767.00 4,317.28 9.40 684.00 2,792.22 12.45 Well Name: S-201A BP AMERICA LOT / FIT Summary Page 1 of 1 !"! # !$ % &'&' (% && 1 2 3 &/ - 4(% & &&5 3 6 && 3 % 77*!/2!72-8 (42-9./:)46;#< 5 $ 3 ;= 0 % #46;$ ( 6> % 6 ;! 6"6 #$ % 6 &'&' 7*% /) * 7*%! 7% 7*0!! 0! 5 7%"7 ?% 7!@ 0! 5% 777! 2 7%70 !!0 7* ?5!@ A8.! %7!7 ! 8/=88 5! /) 5!@ 7*0 !5 ! 5"?% 27 75!%2 5!@5!%2! /=:88 5! /) !5!%2 027! ! 7! !!7* !@ 7*2277?5!%7"%%7 ! 7*252%5!%7"%%7 ! /=.8: 7*2 /) * 7*2 7% 7,5+7*"== 7% 7*0!! !% 77*!77! 7%"2" 7*2 7*0!! 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" #$ % & '' (& ')' 3 4 # 5 '1##6 7(& ' ''! # 5# 8 '' # 5##&#99, 1 4 946/ (746:01)*78;$< ! % 5 /;/ 2 & $78;% ( 8= & 8 ; 8"8 $% & 8 ')' 9, 6.)+1 ##2 ##9,! ?"999, ! &#9 99"& 9 & !4&9 #9,9& #6 @'0>9, E& ! 4" 4#9#&99 # & #2 #! # #&# &#9?. 9"&D49!.& & D49! 010 #4! 9, 6.)+1 #4#2# ! 92 #@!9$% !@9 !#9? #,"0 1+0 #4! 9, 6.)+1 9& " &"9," #4##9# 1@/+ #4! 9, 6.)+1 94# 4",# #!9&9# #D4 #&&# 2, #4#&#? 9& *@ 92 #@!9$%.# ?&E $4& % #4##$?94 9,"% 4#" 4 JJJ##9,2# ! /@+JJJ /1@/ #4! ( /!*'' ACTIVITYDATE SUMMARY 1/8/2020 Initial T/I/O=TWC/0/0. Post Parker well work. Remove Piggy Back valves from IA and OA Install tapped blind flanges and torque to API specs. PT to 2500psi (PASS) RD dry hole tree. RU GE upper tree. Torque to API specs. Torque THA x MV to API specs. RU Grey Lubricator & PT to 350/5000psi. (PASS). RD and pull 4" CIW TWC # 445 @ 102". RD lubricator and pt tree cap to 500 (PASS). RDMO *****Job Complete**** SEE LOG FOR DETAILS Final T/I/O= 0/0/0 1/20/2020 T/I/O= 20/30/35 ( LRS unit 76 , Circ out with diesel) CMIT-TxIA to 4038/4084 psi **PASSED** (Max 4250 psi, target 4250 psi). Pumped 2.7 bbls diesel total down TBG/IA to reach test pressure. 1st 15 min T/IA lost 30/31 psi. 2nd 15 min T/IA lost 29/29 psi. PASS per WSL Erik Dickerman. Bled TBG/IAP, bled back ~ 1.9 bbls. Circulated well with 290 bbls diesel down the TBG taking returns up the IA to production on S-119. RDMO. Caution and info tags hung on MV/IA. AFE sign hung on MV **FLUID PACKED ANNULUS**. Valve position on departure are as follows. Swab/SSV/WV=Shut, IA/OA=OTG. FWHP=300/300/27 2/23/2020 ***WELL S/I ON ARRIVAL***(side track) DRIFTED W/ 20' x 2.70" DUMMY WHIPSTOCK, 1 3/4" SAMPLE BAILER, SD HIGH @ 5,079' SLM (sample of mud) RAN 10' x 2.25" PUMP BAILER, MSFB, SD @ 5,093' SLM (recovered 1/2gal of mud) ***CONT WSR ON 2/24/20*** 2/24/2020 ***CONT WSR FROM 2/23/20*** (sidetrack) RAN 10' x 2.25" PUMP BAILER, MSFB, BREAK THROUGH BRIDGE @ 5,093' SLM. TAG TD @ 6,948' SLM (recovered 1.5gal of hard mud) RAN 3 1/2" BRUSH, 2.80" GAUGE RING TO CLOSED BAKER DEFENDER (up to close) SLIDING SLEEVE @ 4936' MD (bled ia to 50psi, pin unsheared) LRS PERFROMED PASSING MIT-T AND MIT-IA ATTEMPTED TO RUN HES RCBL TOOL, UNABLE TO PASS STA #7 @ 6,630' SLM ***CONT WSR ON 2/25/20*** 2/24/2020 T/I/O= 400/80/140. Temp= SI. LRS Unit #72 Assist Slickline (SIDETRACK). MIT-T to 4730 psi Passed (4800 psi max appiled pressure). TBG lost 49 psi in 1st 15 min, and 21 psi in 2nd 15 min (70 psi total). Pumped 2.7 BBL's of DSL to achieve test pressure, and bled back 1.5 BBL's. MIT-IA to 2633 psi Passed (2750 max applied pressure). IA lost 73 psi in 1st 15 min, and 28 psi in 2nd 15 min (101 psi total). Pumped 2.4 BBL's of DSL to achieve test pressure, and bled back 2.4 BBL's. Pressure the TBG to 1700 psi with 0.5 BBL's of DSL to assist S/L with the next step on the program. Final T/I/O= 1700/180/80. S/L had control of the well and DSO notified upon departure. IA/OA = OTG. WV and kill line = closed. 2/25/2020 T/I/O = /241/92Temp = SI. LRS Unit #42 Assist Slickline (SIDETRACK). Spot in unit, rig up to hard line and start pressure test. ***JOB CONTINUED ON 26-FEB-2020*** 2/25/2020 ***CONT FROM SWCP 4516s 2-25-20 WSR***(Sidetrack) SET X-CSUB AT 6930' MD. ***CONT ON 2-26-20 WSR*** 2/25/2020 ***CONT WSR FROM 2/24/20*** (log-cement bond--scmt/usit) RAN HES RCBL FROM 6,914' SLM TO 2,900' SLM (good data) ------SWAPPED TO 4522----- ***CONT ON SWCP 4522 WSR*** Daily Report of Well Operations PBU S-201A Daily Report of Well Operations PBU S-201A 2/26/2020 ***CONT FROM 2-25-20 WSR***(Sidetrack) PULLED DMY-GLV FROM ST#1 AT 6870' MD. LRS ATTEMPTED TO BREAKDOWN FORMATION @ ST#1 (unsuccessful) SET BK-DGLV IN IN ST#1 (6,870" MD) PULLED BK-DGLV FROM ST#2 (6,850' MD) LRS ABLE TO BREAKDOWN ST#2 @ 2,200psi (.5bpm @ 1,300psi) SET BK-FLOWSLEEVE IN ST#2 (6,850' MD) LRS PERFORM INJ TEST. ***MOVE TO WEATHER TICKET*** 2/26/2020 ********************** Job continued from 2/25/2020 *********************** T/I/O = 406/242/97 Temp - SI. LRS Unit 42 assist SL (SIDETRACK). Initial injection test of Station #1. Pumped 3.8 bbls Diesel into TBG to achieve max applied pressure of 4800 psi. Held pressure for 1 hour, TBG pressure 4752 psi. Pumped .87 to pressure test Station #1 Dummy Valve - passed. Initial injection test of Station #2, passed. SLB set flow sleeve, LRS pumped injectivity test into station #2 (SEE LOG FOR DETAILS). SB for weather. ******************** Job continued to 2/27/2020 ******************************* 2/27/2020 *****Job continued from 02/26/2020******* LRS Unit 42 assist SLB SL (SIDETRACK), weather standby. Rigged down and left location at noon. 2/28/2020 T/I/O= 200/230/126 Temp= SI LRS Unit 42 assist SLB slickline (SIDETRACK). Spot Equipment SB for SSL ***Job continued on 02/29/2020*** 2/28/2020 ****CONT. JOB FROM 2/26/20**** (Sidetrack) PULLED STA #2 BK-FLOWSLEEVE FROM 6,834' SLM / 6,850' MD ****CONT JOB ON 2/29/20**** 2/29/2020 ****CONT. JOB FROM 2/28/20**** (Sidetrack) SET STA #2 BK-DGLV @ 6,850' MD LRS PERFORMED PASSING TBG P/T PULLED STA #3 BK-DGLV FROM 6,768' SLM / 6,785' MD LRS PRESSURE UP TBG TO BREAK DOWN CEMENT @ STA #3 (Successful) SET STA #3 BEK-FLOWSLEEVE @ 6,785' MD LRS PERFORMED INJECTION TEST ON STA #3 (See LRS log) PULLED STA #3 BEK-FLOWSLEEVE FROM 6,785' MD SET STA#3 BK-DGLV @ 6,785' MD LRS PERFORMED PASSING TBG P/T PULLED STA #4 BK-DGLV FROM 6,712' SLM / 6,730' MD LRS PRESSURE UP TBG TO BREAK DOWN CEMENT @ STA #4 (Successful) SET STA #4 BEK-FLOWSLEEVE @ 6,730' MD LRS PERFORMED INJECTION TEST ON STA #4 (See LRS log) PULLED STA #4 BEK-FLOWSLEEVE FROM 6,730' MD ****CONT JOB ON 3/1/20**** 2/29/2020 ***job continued from 02/28/2020*** LRS Unit 42 assist SLB slickline (SIDETRACK) Pumped a total of 140 bbls DSL to assist SSL with injectivity test on stations #3,#4 (See log for details.) ***Job continued on 03/01/2020*** 3/1/2020 ***Job continued from 02/29/2020*** LRS Unit 42 assist SLB slickline (SIDETRACK) Pumped a total of 142 bbls DSL to assist SSL with injectivity test on stations #4, #5, #6 (See log for details.) ***Job continued on 03/02/2020*** Daily Report of Well Operations PBU S-201A 3/1/2020 ****CONT. JOB FROM 2/29/20**** (Sidetrack) SET STA #4 BK-DGLV @ 6,730' MD LRS PERFORMED PASSING TBG P/T PULLED STA #5 BK-DGLV FROM 6,681' SLM / 6,701' MD LRS PRESSURE UP TBG TO BREAK DOWN CEMENT @ STA #5 (Successful) SET STA #5 BEK-FLOWSLEEVE @ 6,701' MD LRS PERFORMED INJECTION TEST ON STA #5 (See LRS log) PULLED STA #5 BEK-FLOWSLEEVE FROM 6,701' MD SET STA #5 BK-DGLV @ 6,701' MD LRS PERFORMED PASSING TBG P/T PULLED STA #6 BK-DGLV FROM 6,663' SLM / 6,681' MD LRS PRESSURE UP TBG TO BREAK DOWN CEMENT @ STA #6 (Successful) SET STA #6 BEK-FLOWSLEEVE @ 6,681' MD LRS PERFORMED INJECTION TEST ON STA #6 (See LRS log) PULLED STA #6 BEK-FLOWSLEEVE FROM 6,681' MD SET STA #6 BK-DGLV @ 6,681' MD LRS ATTEMPTED TBG P/T (Failed, Sta #6 DH gauge tracking) ****CONT JOB ON 3/2/20**** 3/2/2020 ****CONT. JOB FROM 3/1/20**** (Sidetrack) RAN 2.70" CENT, 2.50" LIB TO CATCHER @ 6,909' SLM ****MOVE TO WEATHER STANDBY DUE TO LOW TEMP**** 3/2/2020 ***Job continued from 02/01/2020*** LRS Unit 42 assist SLB slickline (SIDETRACK) Standby for weather ***Job continued on 03/03/2020*** 3/3/2020 ***Job continued from 03/02/2020*** LRS Unit 42 assist SLB slickline (SIDETRACK) Standby for weather ***Job continued on 03/04/2020*** 3/4/2020 ***Job continued from 03/03/2020*** LRS Unit 42 assist SLB slickline (SIDETRACK) Standby for weather. Rig down. SSL incontrol of well @ departure. FWHP= 600/120/150 3/5/2020 ****CONT. JOB FROM 3/2/20**** (Sidetrack) PULLED 3-1/2" X-CATCHER FROM 6,907' SLM / 6,930' MD (Empty) ***BKR SSD OPENED WHILE RIH TO RECOVER CATCHER*** RAN 2.60" BELL GUIDE W/ 1-1/4" JD (Coreless) TO TD @ 6,921' SLM (No recovery) RE-SET 3-1/2" X-CATCHER @ 6,907' SLM / 6,930' MD RAN KJ, 3-1/2" OK-6, 1.25" LIB TO STA #6 @ 6,663' SLM (Impression of bk latch) PULLED STA #6 BK-DGLV FROM 6,663' SLM / 6,681' MD (Upper & lower pkg damage) SET STA #6 BK-DGLV @ 6,681' MD RAN 3-1/2" 42BO (Self releasing) TO BKR SSD @ 4,936' SLM (Closed) LRS PERFORMED PASSING TBG P/T (See LRS log) ****CONT. JOB ON 3/6/20**** 3/5/2020 T/I/O=220/194/190 Temp=SI Pumped 2 bbls DSL down TBG to pressure up. Performed 5 min test on Station #. TBG lost 113 psi during 5 min test. ***WSR Continued on 03-06-2020*** Daily Report of Well Operations PBU S-201A 3/6/2020 ***WSR Continued from 03-05-2020*** On Station #7 pumped 60 bbls of DSL at 1 BPM for 1 hour. Injection pressure at 1 BPM at 1929 psi. Refer to log for details. SL set DGLV in station #7. Pressure tested TBG to 4000 psi On Station #8 pumped 60 bbls of DSL at 1 BPM for 1 hour. Injection pressure at 1 BPM at 2158 psi. Refer to log for details. SL set DGLV in station #8. Pressure tested TBG to 4000 psi. On Station #9 pumped 60 bbls of DSL at 1 BPM for 1 hour. Injection pressure at 1 BPM at 2375 psi. Refer to log for details. SL pulling circ sleeve out of Station #8 and start setting WFR's ***Continue on 03/07/2020*** 3/6/2020 ****CONT. JOB FROM 3/5/20**** (Sidetrack) PULLED STA # 7 BK-DGLV FROM 6,634' SLM / 6,652' MD LRS PRESSURED UP TBG TO BREAK DOWN CEMENT @ STA #7 (Successful) SET STA #7 BEK-FLOWSLEEVE @ 6,652' MD LRS PERFORMED INJECTION TEST ON STA #7 (See LRS log) PULLED STA #7 BEK-FLOWSLEEVE FROM 6,652' MD SET STA #7 BK-DGLV @ 6,652' MD LRS PERFORMED PASSING TBG P/T PULLED STA # 8 BK-DGLV FROM 6,614' SLM / 6,632' MD LRS PRESSURED UP TBG TO BREAK DOWN CEMENT @ STA #8 (Successful) SET STA #8 BEK-FLOWSLEEVE @ 6,632' MD LRS PERFORMED INJECTION TEST ON STA #8 (See LRS log) PULLED STA #8 BEK-FLOWSLEEVE FROM 6,632' MD SET STA #8 BK-DGLV @ 6,632' MD LRS PERFORMED PASSING TBG P/T PULLED STA # 9 BK-DGLV FROM 6,499' SLM / 6,515' MD LRS PRESSURED UP TBG TO BREAK DOWN CEMENT @ STA #9 (Successful) SET STA #9 BEK-FLOWSLEEVE @ 6,515' MD LRS PERFORMED INJECTION TEST ON STA #9 (See LRS log) PULLED STA #9 BEK-FLOWSLEEVE FROM 6,515' MD ****CONT JOB ON 3/7/20**** 3/7/2020 ****CONT. JOB FROM 3/6/20**** (Sidetrack) SET STA #9 BK-DGLV @ 6,515' MD LRS PERFORMED PASSING TBG P/T PULLED STA #7 BK-DGLV FROM 6,634' SLM / 6,652' MD SET STA #7 BK-BKR WFRV @ 6,652' MD PULLED STA #5 BK-DGLV FROM 6,684' SLM / 6,701' MD SET STA #5 BK-BKR WFRV @ 6,701' MD PULLED STA #3 BK-DGLV FROM 6,770' SLM / 6,785' MD SET STA #3 BK-BKR WFRV @ 6,785' MD RAN KJ, 3-1/2" OK-6, 1-1/4" JDC, S/D IN SSD @ 4,926' MD ***SSD DEVICE OPENED WHILE RIH W/ KOT*** RAN 3-1/2" 42BO TO BKR SSD @ 4,913' SLM / 4,926' MD (Closed) PULLED STA #2 BK-DGLV FROM 6,830' SLM / 6,851' MD SET STA #2 BK-BKR WFRV @ 6,851' MD PULLED STA #4 BK-DGLV FROM 6,712' SLM / 6,730' MD MADE 1 ATTEMPT TO SET STA #4 BK-BKR WFRV (Unable to loc or s/d) ****CONT JOB ON 3/8/20**** Daily Report of Well Operations PBU S-201A 3/7/2020 ***Continue from 03/06/20 WSR*** DGLV set in station #9. Pressure tested TBG to 4000 psi. Test Pass, SL setting WFR's. Pumped 4.3 bbls to test DGLV's and to keep TBG up while SL set WFR's. ***Continue on 03/08/2020*** 3/8/2020 ***CONT. FROM 3/7/20 WSR*** (Sidetrack) SET STA #4 BK-BKR WFRV @ 6,730' MD LRS PERFORM SRT @ 800 PSI, 1600 PSI & 2500 PSI (see log for details) RAN 3-1/2" 42BO TO BKR SSD @ 4,936' MD (Closed) DRAW DOWN T PRESSURE & EVALUATE PRESSURE VIA DH GAUGES (see log for details) RAN KJ, 3-1/2" OK-6, 1.21" LIB TO STA #2 @ 6,850' MD (Impression of bk latch) PULLED 3-1/2" X-CATCHER FROM X-NIPPLE @ 6,930' MD (Empty) RAN 3-1/2" 42BO TO BKR SSD @ 4,936' MD (Closed) SET 3-1/2" HES RED SPIDER ISSSV (Serial # RS301) @ 2,062' SLM / 2,087' MD RAN 3-1/2" CHECK SET TO RED SPIDER @ 2,087' MD (Sheared) ****WELL LEFT S/I & PAD-OP NOTIFIED OF STATUS UPON DEPARTURE**** ***NOTE : BKR SSD @ 4,936' MD CAN BE OPENED EASILY WHILE RIH W/ STD TOOLS 3/8/2020 ***Continued from 03/07/2020*** SL set WFR's in stations in 2, 3, 4, 5, and 7. 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Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : Lift pressure model matches gauge hole assumption, minus 19 bbls lost during displacmemntFIRST STAGE7153 7105 Preflush (Spacer) Density (ppg) : Casing Rotated? TBG TO SURFACE 6715.0 ACID SOLUABLE Volume (bbls): Yield : Cement In Place At : 1804 HRS 1/4/2020 Estimated TOC : 5,267 25 bbls. Volume (actual / calculated) : 61.4 FCP (psi) : 713 Pump used for disp : RIG Plug Bumped? Bump press : 1200 7 Sacks : 296.1980315 5 Post Flush (Spacer) N/A Yield : 1.27 Displacement : BRINE Density (ppg) : 9.8 Rate (bpm) : 15 30 Lead Slurry MUDPUSH II Density (ppg) : 12 Volume pumped (bbls) : Sacks : #DIV/0! Mixing / Pumping Rate (bpm) : Tail Slurry Remarks: S-201Ai CEMENT REPORT Completion 4-Jan-20 Hole Size :6.125 Casing Size :3.5 72% mgr (lead spacer) J</ak 3 2-lOL" P-1-6 219 0,� w Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> �nf� '2�21¢�7OZ-o Sent: Sunday, February 23, 2020 4:30 PM To: Regg, James B (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K; McKean, Aaron J Subject: RE: Defeated LPP/SSV on well 3R-106 Mr. Regg, The low pressure pilot on injection well 3R-106 (PTD# 219-097-0) has been returned to normal operation as of 23 -Feb - 20, in accordance with "Administrative Approval No. CO 4068.001". Regards, Rachel Kautz/Kaelin Ellis CPF3 Production Engineer ConocoPhillips Alaska, Inc. 907-659-7871 From: CPF3 Prod Engrs Sent: Friday, February 21, 2020 9:07 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv (n2070@conocophillips.com) <n2070@conocophillips.com>; CPF3 Ops & DOT Pipelines Supt <n1175@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; McKean, Aaron J <Aaron.J.McKean@conocophillips.com> Subject: Defeated LPP/SSV on well 3R-106 Mr. Regg, The low pressure pilot (LPP) on injection well 3R-106 (PTD# 219-097-0) has just been defeated as of 21 -Feb -20. The well was shut in for proximity to the rig. After returning the well to injection at a reduced injection rate, the wellhead pressure has not risen high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 208 psi and an injection rate of 1320 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Baker Hughes PRINT DISTRIBUTION LIST COMPANY BP Exploration Alaska Inc. WELL NAME 5-201 A FIELD Prudhoe Bay Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Paul. CanizaresObakerhughes.com 219092 32 03 2 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1-132-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or GANCPDC@bp365.onmicrosoft.com Ito acknowledge receipt of this data. LOG TYPE GR-RES-DEN-NEU LOG DATE January 2, 2020 TODAYS DATE February 7, 2020 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION .... ............. ..................................... ...................... 1 iBP North Slope. :EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides :Attn: Benda Glassmaker & Peggy O'Neil :900 E. Benson Blvd. :Anchorage, Alaska 99508 Rev. Requested by: --- FIELD / FINAL CD/DVD FINAL PRELIMlas, LOGS (las,dlis, PDF, META, SURVEY REPORT LOGS Final Surveys) (Compass) IT -OF PRINTS 9 OF PKIN I b # OF COPIES J# OF COPIES I# OF COPIES 4 4 4 4 4 -------------------------------- -- 2 2 ConocoPhillips Alaska Inc.0 0 1 0 0 :Attn: Ricky Elgarico :ATO 3-344 700 G Street ;Anchorage, AK 99510 ---- ---- ----------- ----------------- - ------- ....---- - 3 ExxonVlobil Upstream Oil & Gas, US Conventional :c/o ExxonMobil Upstream Integrated Solutions Company :Attn: Technical Data Center (TDC) :22777 Springwoods Village Parkway N2.2A.332 :Spring, Texas 77389 4EState of Alaska - AOGCC :Attn: Natural Resources Technitian :333 W. 7th Ave, Suite 100 :Anchorage, Alaska 99501 FEB 1 1 2020 0 00 0 J V -2019-U SO N S H O R-288 ---------------- - ---------------------------- - ---- ---------------------------------- SDNR- Division of Oil & Gas *** 0 0 1 0 0 :Attn: Rersource Evaluation Section :550 West 7th Avenue, Suite 1100 :Anchorage, Alaska 99501 `*** Stam-p--"--confidentia---- - -l" on..--- ------- ---- - - --- - - - all material deliver to- DNR - E .. - ---------- -- -- ... , ----------------------------------------------------------------------- ....... 6: BP Exploration (Alaska) Inc. 0 0 1 0 0 1 0 Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: Nancy Landi TOTALS FOR THIS PAGE: 0 0 4 0 0 THE STATE GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 199612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S -201A BP Exploration (Alaska), Inc. Permit to Drill Number: 219-092 Surface Location: 4587' FSL, 4496' FEL, SEC. 35, TI 2N, RI 2E, UM Bottomhole Location: 1783' FSL, 128' FEL, SEC. 27, TI 2N, RI 2E, UM Dear Mr. Allen: Enclosed is the approved application for the permit to redrill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this — day of July, 2019. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMIS: PERMIT TO DRILL 20 AAC 25.005 SEI 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 0 Service - Disp❑ 1c. Specify if well is proposed for: Drill 11Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone 0 Coalbed Gas ❑ 'Gas Hydrat st Redrill 0 Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 0 Single Well ❑ 11. Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 PBU S -201A 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 7087' TVD: 5408' PRUDHOE BAY, POLARIS OIL 4a. Location of Well Governmental Section): ( ) 7. Property Designation (Lease Number): ADL 028257 & 028258 g DNR Approval Number: 13. Approximate spud date: Surface: 4587' FSL, 4496' FEL, Sec. 35, T12N, R12E, UM 2069' FSL, 368' FEL, Sec. 27, T12N, R12E, UM Top of Productive Horizon: 83-47 January 15, 2020 ' 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 1783' FSL, 128' FEL, Sec. 27, T12N, R12E, UM 8600 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 83.05 feet 15. Distance to Nearest Well Open • ito Pool: Surface: x- 618930 y- 5980790 Zone - ASP4 GL Elevation above MSL: 35.90 feet 4500me 16. Deviated wells: Kickoff Depth: 5757 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 40 degrees Downhole: 2365 • Surface: 1836 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD I TVD (including staqe data) 6-1/8" 3-1/2" 9.2# L-80 VamToD 7087' Surface Surface 7087' 5408' 223 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 1 Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 1 7245 5613 6610 6610 5020 Unknown x 2 Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 260 sx Arctic Set (ADorox.) 29-109 29-109 Surface 3162 9-5/8" 385 sx AS Lite III, 280 sx Class 'G' 29-3190 29-2846 Intermediate Production 7207 7" 421 sx Class 'G' 26-7233 26-5602 Liner Perforation Depth MD (ft): 6640-6841 Perforation Depth TVD (ft): 5048-5235 Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Gorham. Bradlev M from without prior written approval. Authorized Name Allen, Kenneth W Contact Email Bradley.Gorham@bp.com Authorized Title Fngineerinq Team Lead Contact Phone 907-564-4649 Authorized Signature !'��---" Date Commission We Only Permit to Drill Permit Approval See cover letter for other Number: . O API: 50- 029-22987-01-00 Date: requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, g s hydrates, or gas contained in shales: �✓ Other: Jr -151"t k� �i T6 �CaS t Samples req'd: Yes ❑ No LK Mud log req'd: Yes El No LAS 1-� 1 (gr-�tvsT I`O 3sZd r vx- H2S measures Yes 13K No El Directional svy req'd: Yes Nr No 11 R L® G To Ao�+'C+C � � Spacing exception req'd: Yes ❑ No LX Inclination -only svy req'd: Yes ❑ No R/ sEE P43L.LO" 1%%56 N& JZ�dR A -DD 0-1064,0'1114 tePost initial injection MIT req'd: Yes ❑ No ❑ Cis-r�t� 10.40 A t"APR-a+/-' I - APPROVED BY l/ /) a Approved b � COMMISSIONER THE COMMISSION Date: `G `- . Form 10-401 Revised 5/2017 This permit is valid for 24 mQf, lGal. No ALO AAC 25.005(g)) Submit Form and ^ ' �� l /�� ` � ��I ��j��j� Attachments in Duplicate PBU 5-201A (PTD 219-092) • Additional Conditions of Approval: Variance to 20 AAC 25.412 (b) is granted by the utilization of a cement packer of —500' in length and an approved cement evaluation log demonstrating that injection will be limited to the injection interval with the following stipulations: a. BPXA will provide a cement job summary reports to AOGCC when they become available BPXA will provide a written cement bond log evaluation/interpretation to the AOGCC along with the cement bond log as soon as it becomes available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that BPXA is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. c. BPXA will provide a confinement water flow log to AOGCC after 1 year of injection by To: Alaska Oil & Gas Conservation Commission From: Brad Gorham, ODE Date: June 13, 2019 RE: S -201A Permit to Drill The S -201A well is scheduled to be drilled by Parker 272 in January 2020. This is a rotary sidetrack Schrader Bluff injector. The well will be sidetracked out of the existing 7" casing and a 6-1/8" production hole will be drilled. The well will be completed with a 3-1/2" monobore string with a cement through mandrels. The maximum anticipated surface pressure from the Schrader Bluff with a full column of gas from TD / • to surface is 1,836 psi (assumes 8.6 ppg EMW most likely pore pressure and a 0.1 psi/ft gas ' •/ gradient). The well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack (3 rams and an annular). The BOP rams will be tested to 4,000 psi and annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning information on S -201A, please do not hesitate to use the contact information below. Brad Gorham Office: (907) 564-4649 Cell: (907) 223-9529 Email:Bradley.gorham@bp.com Attachments: Well Bore Schematic BOPE Schematic Proposed Pre -Rig Schematic As -Staked Survey Proposed Completion Area Review Map Directional Package S -201A PTD 1 6/13/2019 Planned Well Summary Well S -201A Well Injector Target Schrader Type Objective I Bluff Current Status Rotary Sidetrack Estimated Start Date: 1 1/15/2020 1 F Time to Complete: 12.5 Days Surface Northing Easting Offsets TRS Location 5980789.92 618929.93 4587' FSL / 4496' FEL 12N 12E Sec 35 Planned KOP: I 5,757' MD Planned TD: 7,087' MD / 5,407' TVD Rig: Parker 272 1 GL -RT: 47.15 1 RTE ref MSL : 1 83.05 Directional - Baker WP05 KOP: 5757' MD Northing Easting TVDss Offsets TRS Target 1 5983534 617731 4878 2069' FSL / 368' FEL 12N 12E Sec 27 BHL 5983251 617976 5324 1783' FSL / 128' FEL 12N 12E Sec 27 Planned KOP: I 5,757' MD Planned TD: 7,087' MD / 5,407' TVD Rig: Parker 272 1 GL -RT: 47.15 1 RTE ref MSL : 1 83.05 Directional - Baker WP05 KOP: 5757' MD Maximum Hole Angle: -400 in the production section Close Approach Wells: None. All offset wells pass BP Anti -collision Scan Criteria. Survey Program: Reference attached directional program Nearest Property Line: -✓81600' Nearest Well within Pool: -4,500' Hydraulic Fracture Planned? No S -201A PTD 2 6/13/2019 Formation Tops and Pore Pressure Estimate (SOR) S -201A PTD 3 6/13/2019 Depth p MLPP Fluid Type Formation (TVDss) (ppg) (For Sands) G1 335 8.4 Fluvial gravels SV6 1540 8.4 Fluvial gravels BPRF 1867 8.6 Fluvial gravels EOCU 2080 8.4 N/A Gas Associated SV5 2180 8.4 with Coals Gas Associated SV4 2354 8.6 with Coals Gas Associated SV3 2691 8.6 with Coals SV2 2832 8 7 Gas Associated with Coals Gas Associated SV1 3167 8,7 with Coals Gas Associated UG4 3505 8.85 with Coals UG4A 3546 8.85 Gas Hydrates UG3 3866 8.85 Gas Hydrates UG1 4382 8.7 Gas Hydrates UG Ma 4670 8.7 N/A Possible Gas / UG_f41b1 4725 8.7 Heavy Oil UG Mb2 4750 8.7 N/A UG Mc 4760 8.7 Heavy Oil SB Na 4885 8.7 Heavy Oil SB Nb 4903 8.7 Water/Heavy Oil SB OA 5001 7.7 Viscous oil SB OBa 5041 7.7 Viscous Oil / Water SB OBb 5079 7.7 Viscous Oil SB OBC 5123 7.7 Viscous Oil SB OBd 5171 7.7 Viscous Oil SB—013e 5221 8.6 Viscous oil SB OBf 5258 8.6 Viscous Oil SB OBf_B 5297 8.6 v N/A ase S -201A PTD 3 6/13/2019 Casing/Tubing Program Hole Size Liner / WVFt Grade Conn Length Top Bottom 1 12-20 Tbg O.D. Oen hole volume + 30% excess + 80 ft shoe track Tail TOC 500 ft MD above 7" window MD / TVDss MD / TVD 6-1/8" 3-1/2" Liner 9.2# L-80 VamTop 7087' Surface 7087'/ 5,407' Temp / Tubing Mud Program Production Mud Properties: Water Based Polymer Fluid Depth Interval Density PV (cp) Ib! P 7" Window - TD 9.2-9.8 <12 1 12-20 Logging Program 6-1/8" Production Sample Catchers - as required by Geology Drilling: Dir/GR//RES/DEN/NEU Oen Hole: None Cased Hole: CBL- GR - CCL- plannedpost-rig Cement Program Casing Size 3-1/2" 9.2# L-80 VamTop Production tubing Lead N/A Lead TOC N/A Basis Tail Oen hole volume + 30% excess + 80 ft shoe track Tail TOC 500 ft MD above 7" window Spacer -40 bbls of Viscosified Spacer weighted to -11.0 Mud Push II Total Cement Lead N/A Volume Tail 59.6 bbls, 335 cuft, 223.3 sks of 15 ppg Class G, Yield: 1.50 cuft/sk Temp BHST 90° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: No pressure management plan is necessary. Anti -Collision: None. All offset wells pass BP Anti -collision Scan Criteria. Offset well ownership information All offset wells identified within 200 ft of the proposed wellbore are operated by BP. S-201 A PTD 4 6/13/2019 Hydrogen Sulfide Reference "Drilling Critical Issues" section. Faults Reference "Drilling Critical Issues" section. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul Class I waste to DS -04 and/or Pad 3 for disposal. Contact the GPB Environmental Advisors (659-5893) for guidance. S -201A PTD 5 6/13/2019 Well Control The 6-1/8" hole section will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP rams will be tested to 4,000 psi while the annular will be tested to 3,500 psi. BOP test frequency for S -201A will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. 6-1/8" Production Interval Maximum anticipated BHP 2,365 psi in the Schrader Bluff at 5,289' TVDss 8.6 ppg EMW Maximum surface pressure 1,836 psi 0.10psi/ft gas gradient to surface Kick tolerance 25 bbls with > 12.4 ppg frac gradient. Assumes an 8.6 ppg max pore pressure in the Schrader Bluff + 0.5 ppg kick intensity and 9.4 ppg MW. Planned BOP test pressure Rams test to 4,000 psi / 250 psi. Annular test to 3,500 psi / 250 psi Integrity Test — 6-1/8" hole FIT after drilling 20'-50' of new hole S-201 A PTD 6 6/13/2019 Variance Requests 1. BP is requesting a variance from 20 AAC 25.412 (b) to utilize a cement packer of —500' in length. This is the same variance request as was submitted and approved on the S- 210 PTD (#219-057). BP will conduct an approved cement evaluation log demonstrating that injection will be limited to the injection interval while also providing the information below: BP will provide a cement job summary report to AOGCC when it becomes available. BP will provide a written cement bond log evaluation/interpretation to the AOGCC along with the cement bond log as soon as it becomes available and prior to injection. The evaluation will outline the intervals of competent cement (and lengths) that BPXA is using to meet the objective requirements for isolation. BP will conduct a provide a confinement waterflow log to the AOGCC after one year of injection. S -201A PTD 7 6/13/2019 Drill and Complete Operations Summary Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test BPV/TWC from below to 3,500 psi psi for 5 minutes. 3. Nipple down tree and nipple up BOPE and test the rams to 4,000 psi and annular to 3,500 psi. (Configured from top to bottom: 13-5/8" annular preventer 2-7/8" x 5" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8" x 5" VBRs in the lower cavity). a. Notify AOGCC 24 hrs in advance of full test. 4. Rig up lubricator and pressure test. 5. Pull BPV/TWC with pressure tested lubricator. 6. RU hard lines to BOP. Circulate out diesel freeze protection. 7. Pull 3-1/2" tubing from the pre -rig cut. 8. Perform 7" cleanout run to tubing stub. Perform only if deemed necessary. 9. Contingency - This step will only be necessary if PC leak is not isolated pre -rig. PU and RIH with EZSV. Set and perform assurance integrity test on existing 7" casing. 10. PU 7" whipstock, bottom trip anchor, and 6-1/8" window milling assembly (to include full gauge string mills). RIH to top of tubing stub, orient and set whipstock. 11. Swap wellbore over to 9.4 ppg milling fluid. ----------------------------------------End of Sundry: Start of Permit to Drill ----------------------------------- 12. Mill window and 20' of new formation. Pull back into casing and perform FIT. 13. MU and RIH with 6-1/8" drilling assembly. 14. Drill ahead to TD. Circulate and condition the hole as necessary. 15. POOH and lay down drilling assembly. 16. RU and run 3-1/2" completion to TD. 17. Cement tubing, bringing cement 500' inside 7" window. a.- CBL and integrity testing to be conducted post rig. + 18. Reverse circulate completion brine with corrosion inhibitor through shear valve. (may be post rig) 19. Circulate freeze protect. Set TWC and test. 20. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 4500 psi. 21. RDMO Parker 272. Post -Rig Operations 1. V: Tree work/pull BPV i�CrC�L 2. E: RU and run CBL to confirm TOC. --N0 -No 3. S: CMIT-TxIA. Pull shear valve. Set dummy. MIT -T. WFRV work/breakdown cement to allow for reservoir communication 4. F: Assist SL with WFRV work and breaking down cement S -201A PTD 8 6/13/2019 S -201A Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Production Hole: The Schrader Bluff is expected to be at a 8.6 ppg EMW. Reservoir pressures will be controlled by using 9.2 - 9.8 ppg water based mud. II. Lost Circulation/Breathing A. Production Hole: There is one expected fault crossing in the production hole. The probability of lost circulation is low. III. Fault Locations Formation Where MD TVDssThrow Direction Lost Circ Fault Encountered Intersect Intersect and Ma nitude Uncertainty Potential Fault #1 5990' 4420' 0-20' Low: ft 200 Low: <25% S -201A PTD 9 6/13/2019 V. Hydrogen Sulfide S -Pad is not considered an H2S site. Recent 1-12S data from the ad is as follows: VI. Anti -Collision Issues None. All offset wells pass BP Anti -collision Scan Criteria. <— 54vaaer weAk CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -201A PTD 10 6/13/2019 Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level S-106 180 ppm 3/9/2012 #2 Closest SHL Well H2S Level S-103 40 ppm 10/31/2018 #1 Closest BHL Well H2S Level S-103 67 ppm 9/2/2018 #2 Closest BHL Well H2S Level S -213A 38 ppm 11/2/2018 Max Recorded H2S on Pad/Facility S-201 500 ppm 6/2/2005 VI. Anti -Collision Issues None. All offset wells pass BP Anti -collision Scan Criteria. <— 54vaaer weAk CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -201A PTD 10 6/13/2019 �N� � s p 8 ZSZ = U p ® 8 O p D C G N m 3 N FO i{� U m U \ o 0 00 ..sss ass s. ii�ss� NN assn YI of N p N elf N \ & Yf �(f n • • � �(3l O Yl N Y] .9m zil Ul U UO YEAR ELEVATION COMMENTS 2016 37.68 MARKED WITH YELLOW PAINT s NOTES 1. VERTICAL DATUM IS BP MSL. 2. BASIS OF VERTICAL ELEVATION: MON S-4; ELEV. = 38.64' 3. BASE FLANGE ELEVATIONS ARE OBTAINED DURING A COMPREHENSIVE WELL—BORE SUBSIDENCE PROGRAM BASED ON LOCAL CONTROL CONFIRMED THROUGH STATIC SATELLITE OBSERVATIONS. AMN: AAH KMD DATE: 12/28/16 ORAMtlC FF�IS SMS -PAD JOB Bell CAL : NO: ize i ISSUED FOR INFORMATION AAH RMS NOT TO SCALE LATE RENSION BT CNN S PAD VICINITY MAP NTS ELEVATION MONITORING POINT SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JUNE 05, 2016. WOA — S PAD SHEET: WELL 201 BASE FLANGE ELEVATIONS 1 OF .S -PAD N 1100 - O M '�!O N N NN I I II tn� N 1010 - #w�sa��sl��✓A� fi11--i-�--: -r- �� I T T T T T T T T T I T T TTI TT i V1tnNN Vlfn (n Ntn (nNVINVIV)fn (nN f/) V] VY to N N 840 LEGEND RENAMED AS -BUILT CONDUCTO ■ EXISTING CONDUCTOR 00. S-201. S-213 & S-216 RENA Z Q d THIS AS -BUILT DRAWING IS A REISSUE OF PREVIOUS AS -BUILT DRAWINGS FOR WELLS S-200, S-201 S-213 AND S-216. S-200 WAS PREVIOUSLY ISSUED AS WELL SB -01 ON 11/13/97, S-201 WAS PREVIOUSLY ISSUED AS SLOT 19 ON 10/05/00. S-213 WAS PREVIOUSLY ISSUED AS SLOT 3 ON 7/04/00. S-216 WAS PREVIOUSLY ISSUED AS SLOT 1 ON 11/29/00. ' ................................ a. c� z TANK ow J X V'rl w Z O a� NOTES: 1. DATE OF SURVEYS: S-200 11/12/1997) (S-201 10/03/2000) (S-213 7/02/2000) (S-216 11/28/2000) 2. REFERENCE FIELD BOOKS: (S-200 Wo97-01 PGS. 45-46) (S-201 WoOO-11 PGS. 18-20) (S-213 WoOO-06 PGS. 1-4) (S-216 WoOO-10 PG. 50) 3. COORDINATES ARE ALASKA STATE PLANE, ZONE -4 NAD 27. 4. GEODETIC COORDINATES ARE NAD -27. 5. MPU S -PAD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL 15 BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. 27 I 26 125 S PAD 34 1 ?6 �, PROJECT A- AREA T.12N. 3 MIN 2 VICINITY MAP N. T. S. `OF Ar >{ �49 .9 'o, °•, J�ffre J. Cotton , LS 8306 0.• SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 31, 2000. I OCATFD WITHIN PRnTRACTFD SFC_ 35. T 19 N R 19 F IIMIAT MFPiniAN AI A4KA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS S-200 Y=5,980,504.88 N. 1,010.30 70'21'19.407" 70.3553907' 36.1' 4,301' FSL X= 618,930.26 E. 350.08 149'02'02.971" 149.0341587' 4.500' FEL S-201 Y=5,980,789.92 N. 1,010.07 70'2F22.21 70.3561694' 35 9, • 4,587' FS X= 618,929.93 E. 65.01 149'02'02.849" 149.0341247' 4,496' FEL S-213 Y=5,980,549.84 N. 1,010.01 70'21 19.849 70.3555136' 35'9 4,347' FS X= 618,929.96 E. 305.12 149'02'02.959" 149.0341554' 4,501' FEL S 216 Y=5,980,520.26 N. 1,009.75 70'21'19.558" 70.3554328' 36.0' 4,'317' FSL X= 618,929.71 E. 334.70 149'02'02.980" 149.0341611' 4,501' FEL F. Rober! DRAWN: JJC - �„ CHECKED: RFA , 1 DATE: N ORAwNG: FMO3 WDA -S 03-00 WOA S -PAD SPIE" JOS D 111c1k�xUlho scuERENAMED AS -BUILT CONDUCTORS o TT za ISSUED FOR p1fDRYATtOt1 JJc RfA E " t•= 150' WELL S-200, S-201 S-213 & S-116 1 of t NO. DATE IREVISION DY CN1C 5-201A Area of Review:, Distance From Top of Pool Well Name Planned Well (ft) Annulus Integrity (TVDss) TOC 5-201 is currently a non-operable producer. A traditional cement packer repair was planned to return 5-201 to an operable status in 102018. A LDL was run on 3/12/18 during Pumped 45 bbls of 11.5 ppg LiteCrete and 75 bbls of 15.8 ppg the pre -cement work after 2 IBP set attempts set above all perfs Class G cement. A total of 55 bbls of cement was lost during the 5-201 (parent) 450' continued to fail a CMIT. The LDL identified there to be a PC leak -4869 above the production packer at 6112' MD. 5 -Pad Schrader cement job. Top of quality cement is estimated to 6e at 6,200' development was being worked at the same time. 5-201's BHL was MD based on USIT log. determined to be in a prime location to provide injection support to the 5-202 new drill. The cement packer repair was cancelled so 5-201 could be converted to an injector to support 5-202. 5-103 is an operable gas lifted producer at time of signing SoR. 4/30/06: MIT -IA tested to 3500 psi. No comments on Nordic 2's operations report of IA losing pressure during 30 -minute test. Pump 161 bbls of 11.5 ppg LiteCrete followed by 57 bbls of 15.8 Tubing had 1500 psi. This test proves up the integrity of the 5-103 880' tubing and PC strings down to the production packer at time of -4860 class G cement. No losses were noted during the cement job. test. Assuming 30% washout, the estimated TOC is —3,793' MD. The T/1/0 plots look good for a gas lifted well. No history of requiring frequent bleeds. 5-122 is an operable gas lifted producer at time of signing Salk. 5/29/16: MIT -IA tested to 2726 psi. Lost 70 psi followed by 18 psi passing to 2638 psi. T/IA had 2552 psi differential during test. Pumped 175 bbls 11.0 ppg LiteCrete followed by 57 bbls of 15.8 5-122 580' IA/OA had 2638 psi differential during test (T/I/O —86/2638/0 -4895 Class G cement. No losses were noted during the cement job psi). This test proves up the integrity of the tubing and PC strings down to the production packer at time of test. and the estimated TOC is —4,036' MD assuming 30% washout. The T/I/O plots look good for a gas lifted well. No history of requiring frequent bleeds. 5-121 is an operable gas lifted producer at time of signing SoR. 2/23/14: MIT -IA tested to 2508 psi. Lost 51 psi followed by 16 psi Pumped 37 bbls 12.5 ppg LiteCrete followed by 434 bbls of 15.8 passing to 2441 psi. T/IA had 1135 psi differential during test. ppg cement on first stage. Circulated cement off the top and no IA/OA had 2440 psi differential during test (T/l/O — 1306/2441/1 losses were noted during the first stage. Open ES cementer and 5-121 1260' psi). This test roves u the integrity of the tubing and PC strings P 1� P P B ' v g g -4961 pump 73.6 bbls of 12.5 ppg LiteCrete followed by 40.6 bbls of down to the production packer at time of test. 15.8 ppg Class G cement. TOC is estimated to be just below surface casing shoe, 3,405' MD. The T/I/O plats look good for a gas lifted well. No history of requiring frequent bleeds. 5-105 is an operable gas lifted producer at time of signing SoR. 12/30/17: MIT -T tested to 2747 psi. Lost 27 psi followed by 15 psi passing to 2705 psi. T/IA had 2712 psi differential during test (T/I/O — 2705/8/212 psi). This test proves up the integrity of the tubing string to the production packer as TTP was set below the Total of 170 bbls of cement were pumped (115 bbls of 11.5 ppg packer. lead, 55 bb's of 15.8 ppg tail). No losses were noted during the 5-105 1200 -4939 cement job. Assuming 30% washout the TOC would be "3,300' 12/30/17: CMIT-T%IA tested to 2704/2731 psi. Tubing gained 6 psi MD. / IA lost 97 psi followed by 21/27 psi passing to 2689/2607 psi. IA/OA had 2372 psi differential during test (T/I/O — 2689/2607/235 psi). This test proves up the integrity of the PC down to the production packer. a zo sw r� row +nasus Ytlillf� I twaa List any wells in any reservoir where injection is planned, that are within Y. mi. of any point along the planned well path within the reservoir Distance from Top of oil pool section planned well (Feet) TVDss S-201(parent) 450' -4869 S-103 880' -4860 5-122 580' -4895 5-121 1260' -4961 5-105 1200 -4939 TREE = CMJ WELLHEAD = FMC ACTUATOR=_ —_.BAKER C PROPOSED OKB. ELEV = 64.42' REF ELEV = 64.42' BF_ ELEV = 37.84' KOP = 1800' Max Angle = �� @ e Dalian MD = Datum TVD = 5000' SS 9-5/8" CSG, 40#, L -80 -BTC, ID = 8.835" 3190' ir•lac � 525T-_ WHIPSIOCK (–_!– /_ )�–� 57 7 7" CSG, 26#, L-80, BTC -M, -0383 bpf, ID = 6276" —1-6757* Minimum ID = " @ - 3--112" TBG, 92#, L-80 ICU, 0087 bfp, ID = T_.992" 708T - - - - ---- DATE I REV BY COMMENTS 12/13/001 PGS 'ORIGINAL COMPLETION _! I SIDETRACK (S -201A)--_ - 02/21/19 _ JMD BUILTPROPOSED -- - - FSAFEb .40TES: S-201 A DATE REV BY COMMENTS L 3-1/2" HES X NIP. ID = 2-813" MLLOUT WQVDOW (S -201A) 5757' - 00000- 3-1/2- HES X NIP, ID = 2.813" I SURESENS SPIV GAUAGE MANDREL, ID= 2-875" 1 3-1/2" HES X NIP, ID = 2.813" I SURESENS SPIV GAUAGE MANDREL, ID = 2-875" I 3-1/2" HES X NIP. ID = 2.813" I SURESENS SPTV GAUAGE MANDREL, ID= 2.875" 1 3-1/2" HES X NIP, ID = 2.813" I SURESENS SPIV GAVAGE MANDREL. ID = 2-875' 1 3-1/2" HES X NIP. O = 2.813" POLARIS UNIT WELL: S -201A PERMIT No: API No: 50-029-22987-01 SEC 35, T12N, R12E, 4586' FSL & 4495' FEL BP Exploration (Alaska) I TREE= aw WELLHEAD - MD ACTUATOR = BAKER OKB. ELEV = 64.42' REF ELEV = 64.42' BF. ELEV = 37.84' KOP = 1800' Max Angle = 57- Q 4414' Datum MD= 6658' Datum TV D = 5000' SS P&A s -2o1 9-518" CSG, 40#, L-80-13TC, ID = 8.835" 1-- L 3190, nm fill guile w — L.0 rd lw u lu l 3-1/2" HES X NIPPLE Top of P&A Cement plug 5,900 I PC leak at -6,100' MD j 17" X 10' SHORT JOINT W/RA TAG ( 6182' Top of Quality Cement 6200' Top DPZ 1 = - 6,508' MD 25' of dump bailed cement " X 20' SHORT JOINT W/RA TAG 6797' PBTD -j 7100• 7" CSG, 26#, L-80, BTC -M, .0383 bpf, D = 6.276" 7233' [_SA; - . NOTES: 2200'-13-1/2' HES X NIP, MILLED TO 2.92' GAS LIFT MANDRR_S ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 2752 2536 57 MATH DMY RK 0 12/28/00 3 4618 3568 54 MMM DMY RK 0 12/28/00 2 6024 4442 35 ATMA 0MY RK 0 12/28/00 1 6084 4491 35 MMA EMPTY - - 01/22/18 'STA #1 =LEFT EMPTY FOR PKR REPAIR 6144' —1�1 1/2" HES X NP, D = 2.813' J 61 bb' 3-112" X 4-112" XO, D = 2.992' 61 b7' 7"X3-112` BAKER S-3 PROD FKR 6160' 4-1/2" X 3-1/2" XO, 618 3-1/2' HES X NP. D = 2.813' 6202' 3-112" HES X NP, D = 2.813' 62141 6610' BKR BP (02/20/18) ?? FISH - ELEMENT FROM JET PUMP (08/29/10) ?? FISH - 1 "X3" SLP & ELEMENT FROM ER PKR (05/05/15) PERFORATION SUMMARY FEF LOG: ??? ANGLE AT TOP PERF: 21 Q 6640' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sgz I DATE I DATE 2-1/2" 4 16640-67301 O 110/02/01110/02/01 2-1/2" 4 6833 - 6841 O 03/26/01 03/26/01 DATE REV BY COMMENTS DATE FEV BY COM 13M 12113/00 PGS ORIGINAL COMPLETION 01/29/18 MS/JM? SET IBP(01/28/18) 03/16/01 CH TP CORRECTIONS 02/19!18 CJN/JMD PULLED BP(02/15/18) 03/26101 GNITLP INITIAL PERFS 02!27/18 JCF/JArD SET IBP (02127/18) 03/04/16 GCOND ADDED REF ELEV 03/21/18 JW --/J REMOVED SAFETY NOTE 111/16/161JTG/JMD PULL® PX RUG (11/15/ 16) F� 01/24/18 RCB/J GLV CIO (01122!18} POLARIS UNIT WELL: S-201 PERMIT No.- "2001840 AR No: 50-029-22987-00 SEC 35, T1 2N, R12E, 4586 FSL & 4495' FEL BP Exploration (Alaska) i TREE= crvv WELLHEAD = FW ACTUATOR = BAKER C OKB. ELEV = 64.42' REF ELEV = 64.42' BF. ELEV = 37.84' KOP = 1800, Max Angle = 57- @ 4414' Datum MID = 6658' Datum TVD= 5000'SS 9-5/8- CSG, 40#, L -80 -BTC, ID = 8.835- 1--{ 3190' Minimum ID = 2.813" @ 6181' 3-1/2" HES X NIPPLE 7:-X 10' SHORT JOINT WIRA TAG 3-112" TBG, 9.2#, L-80-EUE-BRD, �-j 6214' .0087 bpf, 11) = 2,992' PERFORATION SUMMARY FEF LOG: 2?? ANGLE AT TOP PEW 21 @ 6640' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL I Opn/Sqz I DATE DATE 2-1/2- 4 6640 - 67301 0 110/02101 10/02/01 2-1/2' 4 6833 - 68411 0 103/26101 03/26/01 7* X 20' SHORT JOINT W/RA TAG 1--- 6797' I PBTD -L_1100' 7* CSG, 26#, L-80, BTC -M, .0383 bpf, 0 = 6.276* S-20SAFE' -40TES: I 2200- 3-1/2- HES X NIP, MILLED TO 2.92' GASLFr MANDRELS 15) ST MID I TVD DEV TYPE VLV LATCH PORT DATE 4 2752 2536 57 MMM DW RK 0 12128/00 3 4618 3568 54 MMM OMY W 0 12t28100 2 6024 4442 35 MMM DMY W 0 12/28/00 1 6084 4491 35 MMM *EMI:'TY - - 01/22/18 *STA #1 = LEFT EMPTY FOR PKR REPAIR 6144' j--�3-112-HES XNP, 0=2.813- I 6166' 3-1/2- X 4-1/2- 6157'-f7" X —3-1/2' BAKER S-3 PROD PKR 4-1/2'X3-112'XO, ID=2.992' 618V -3-1/2- HES X NIP. ID = 2.813" j3-1/2" 813- 13-1/2- HES X NIP, ID = 2.813- 1 6214'____N3 1i 2" WLEG, D=2992" 1�9=6*F1MD TT LOGGED Q3,r26/01 6610'-j-F6—KR-13-P—(021-20-/-18-)-j ?? 7L�-f�ISH1"X�WE LIP & ELEMENT FROM ER I PKR (05/05115) i DATE FEV BY OOMMWI's DATE RE=VBY COMMENTS 12/13100 PGS OfaGINAL COMPLETION 01/29/18 M5/JM} SET IBP(01/28118) 03/16/01 airTP CORRECTIONS 02JI9/18 C.JWJMD PLYLLE3DIBP(02115/18) 03126101 GKITLP INITIAL PEWS 02t27/18 JCF/JMD SET 13P(02/27/18) 03/04/16 GCJJMD, ADDED REF ELEV 03121/18 JMG1JMD REMOVED SAFETY NOTE 111/16/16 1,FTGJMD PULLED, PX PLUG (11/15/16) 101/241181 1 2/18) POLARIS UNIT WELL: S-201 PERMIT No: *2001840 AR No: 50-029-22987-00 SEC 35, T1 2K R1 2F- 4586 FSL & 4495' FEL BPExploration (Alaska) �N Q J � Q � � •v L ai o cn Q a a tQ c c � L Q cn cn - - Z a cn cn a n. a Qm Y J cQ U Q O a N C oc N O m N 9 z a (n rn a co Q. CLa or _ 0 E d Q ad+ za� y () o. U)33 o co m lli V (h fD N v V d m C W G N = N ❑ d m 0 c v _Q cu a a Y Y a d Q Q (a N co m a N a a Q U O Z « « m r` N y ❑ ❑ Q Q Q z z mE ai 7 v y O N M O Q CL 2 aE E U N O ° z x � Q O m M m f� y In Un ❑ O O 0 O 04O Cl) M a 00 c0 d N N 3 a 04 04 N y L = P- r Q a a U r E m? c v a z z E - = < = = o a a W m y ui U C O d L U' d N = 0 a d O 7 O U C d U 5 vcc cy di = c u O w !n d W o w w d U N U d = a a o v J J (� O >�> O 7 c6 J F Z fA o O Q 01 3 � O O 0 0 T N CL F m Un 3 o c m 0 n 32 m 0 o a a Qm Y J cQ U Q O a N C oc N O m N 9 z a (n rn a co Q. CLa or _ 0 E d Q ad+ za� y () o. U)33 o co m lli V (h fD N v V d m C W G N = N ❑ d m 0 c v _Q cu a a Y Y a d Q Q (a N co m a N a a Q U O Z « « m r` N y ❑ ❑ Q Q Q z z mE ai 7 v y O N M O Q CL 2 aE m co o O - o 0 ° O N o rn * O U) O + M O z Q J a t d z �: L N O ° O m Opp 0 O m M m C\jN N N O 04O U a = N N N m L = O � r N m co o O - o 0 ° O N o rn * O U) O + M O z Q J a t d m d d O 04O U a = J U L = C d N m? c v d - = O m y J J U' d > 0 a d 3 7 O U !n Im _ o v J J (� 01 3 � O O 0 0 _ Q F 3 o N 0 Q 32 m 0 o a R LL y y c N O O N N N V O O 3 J O 00 mN C ( O M m m O m r- O M — co m m m m M 00 LO m N r- m d O 00 OI a m m c0 = a 6 0 0 > Z W m >d v c w `° L Ol D = t+ C C7 M O Z W N C c w t m o Z W u m co o O - o 0 ° O N o rn * O U) O + M O z Q J a t d d C C U O a .N = O 04O U a = d 2 d d C y a° ° a° d N m? c v R CL E w O rn m LL a d d y 0 a d 3 d 7 d d o Q> > !n 3 � O O 0 0 3 O 0 3 o 0 0 0 Q m 0 o a ON O d N E Q O C z O F- N N N m N a 13 co a c Z W c c m co o O - o 0 ° O N o rn * O U) O + M O z Q J a t d d C C U O a .N = = 0 •N U a = d 2 d d C y a° ° a° ° a c m? c v R w O rn m LL a d d y 0 a d 3 d 7 d d o Q> > Q O O (D (� O O O O O (D N N O M m (- V r V O V m I- m V co co O O O (O (D 00 M (� 0 M (O 'p M (O (O (O M M m (A V M d V — Co (0 0 H O O LO O O O V V V V V V V V V O lO O O V V V V V V V V V U O O (D O Z Q U N 7 O (Op O p p O ow r) Cl) M d — /W�� V J Y N N W m (D V m I- V V O N I- � Z N NJ Q m (fl (O (D (D (- N 00 00 N CO V O (p M M M m 1-- W m N m m CL s U N (D In M CO I,- r r- ; m O V o ca m Y N Y Y E (O O C (D (D (n O] In m (n 00 in (D (O m (n to (n (D (n m (n O (D co (D M (D Z Z £ W N Ma w W— O M M O m Cl) V co 1l m O (D N I� (O (D M 1O O 00 (O O N N N CO (D O m N m M (- (D (O m Cl) (-co O O N r N (O Cl) (O 0) N M V (O (O u'1 (O CO m m m m C O C V V V V V (O N N m (O m (O (O d L u M Mm M M M m M M Cl) Cl) Cl) M w 041 7 0) m m m m m m m m m m m m Z (O LO (O N iO (O (O (O tO (O (O (O (O m C d _ U O_ v m N N V M V V V (O O Cl) m CO M Cl) V O I� d W t0 O (f1 (D Cl) M O 00 00 M (O (O O N M m m O O N N Nm I- (O to U L U N N N CO Cl) co M M M N N N N YY Z (N ❑ Q Q m W o + 2 d 0 .0C LLLL O. + + i + m 00 O m m N m O O (O m Of ^ V oD N m co co (O N (p C > >> m M n V co co 00 M M [D (O I� M N N ❑ m V (D (D (0 CO 0 V (- co � (D � 00 NNN W O 00 N m Cn y N N N N N N N N N N N N N Ma C Q (6 U o > jY Y U V V N N Cl) U) I-- N O O V N m M co N O O V M O O Q Q co f� co Cl) 00 m m V O m C4 M d + w � N N N M N O N O N co co N V N V N (O N (D co (D N N WLL LL IL N V V V V V V V V V V V V V d >❑> F — F m m m (D m m N (O m V (O m (O N N 00 (O N M O N V M O Cl) O (D O(D N V N I- M (O V m N Cl) N Cl) M co V CO N V O (O (O O (D O (O r m r O m V V V V V V V V V V V V V >❑ N F 7 O N Q Q Q U Z• N N N O O O N N M CO (O (n U) U) I� (D (D m O N (O V N V m m Ll C C C a (n 0I d N co M (n (A (O (O N V O V N m (D m (O O (D O D Cl) M co M M M dN tO (O (O •N — ¢- mm ca _ a. m > > ¢ ¢ ¢ Q N m 0 Y ^O N = O O O O U N N N N N r -O O O O m m O r r m Q N D) U U U Cl) U 00 m (O ❑ m m r m r h r V V J Q d O O N m V V V V N V N V p V CO) .-- N N CO N N N V 0 _ p p (D O N I- O O O C to EO F M N m r (nn O QQ a w H � O co Z d U U d U a- W M (D 1� O O to V m O O r O O p 0 O O (O O O O M O O Q Ol 00 O r- O O m O O p 0 N O O . O O O O O 00 ((� Q M M O M nI� � Co Cl) O O O O m O OM O m(O O 6(N.6 (7 m co D � r m m m O N NO M M � Er m 0. dr (n LO (O (D (O (D (D (o c (i a YN (p (s C V p C CL d a m T d d c rn o ;oradd R a U a m 3 3❑ (n a N v M o rn n rn M O O O O O O O O O O M 0) v m co Co M M rn 0 V a O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 M N CO CO n n n j m DO U LL p O O CO N v v v v v v <t v O O O O O 0 O 0 O O O o O 0 O 0 a FL o 0 & U N N N N N N N O O O O O O O O O O z Q N U N co d O c c W) Lr) U O O Q Cl) 00 a m m y O N N N l0 OD MV O n n N Cl) M Cl) l0 rn n n Z C14 C14a s 7 a U c0 M (D n M V O V O rn V co rn OD rn N O O M co 0) n M V n CC) N V n M O 00 N rn co aD aD LO N N M aD O m m Y n OD N N M Cl) V V (O n co 0)O N ejr y� co co c ggo (o ,. m m to m (0 to m m m m (o (o co co co (o a a r w W CO (D N co co co N N Cl) O co Cl) rn OD N QO co N V 00 co n M O n OD V d U N N co Cl) Cl) 10 M 0) O Vo0 O M rn N M n V n rn M N t0 M n O OD rn OD .a C O d 0) CN '1' (O n (O n LQ V l0 co N Cl) (O M N V) rn V CO V n V (0 [f V V Cl) C N V L w N L 3 M M 00 M 00 Cl) co M co co Go co co Cl) 00 Cl) 00 Cl) co co co co Go M co M co M 00 co OD 4. 0 rn rn rn rn rn (3 rn rn rn rn rn rn rn rn rn rn (O (O Ln N M N 10 N (O (O LO N M M (O (O N O C d U N 'p C c°'i N 3 N O (D n O N O 10 O co N O O O O co O W 00 rn 0N4 N O Cl) n n N O Cl) n N 0) n i0 rn 0) N4 a Cl) rn @ O O O w 0) U N Cl) O O N N 10 v Cl) O 00 M n co C) O s N N _ _ O O O O O N .nN a� >> ❑ J F 2 to ❑ W 7 0 O SZ @ n Cl) co O rn O n N O N t0 CO n N rn Cl) O O n n O N Ol0 m N V O � O N co T, O O n OO O O a N O con t0 N Q) rn CO- - cc - n - n - n - n - n - n - n - n - n - ( - to - ro to - � �� N N N N N N N N N N N N N N N N coW U) Z C d O O O O rn M O O. 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(O LL (o • co 0 7t I c0 a' a (o o (o a o •4 3 to Z z Z N Z 2 Z o y "a in71 ❑ a _ N v L G i 0 0 0 0 0 0 0 0 0 0 0 0 o O O O 0 O O O O O O O O O O O op 0 0 0 0 0 0 0 0 0 0 0 o O C) j U � (0 0 m LL— 8 a 0 o o 0 a o 0 o O 0 O 0 O 0 o O O o 0 0 0 0 0 0 O 0 d o 0 0 0 0 0 0 0 0 0 0 � U 0 0 0 0 o O Z Q x N U 3 O 7 J In n 0 O O O Q r M M IL m m y ca 7 N N N l0 (l- n Z M co O N O m N In r- 04 Cl) O Q1 OD 7 O Cl) 0) In N ON. 04 3 Q U OD (- V V In (V M In 1l to O) V r- (n N Cl) YD n N O M cD O O V 0) M c0 (D c0 O m m Y N Y Y 10 N0 G 00 c0 N OD LO OD O cD n (O O m O 0) O (3) 01 Cl) 0) M 01 In W n 0) In r gg; o(D w" (D co co co co co co co co co co co (D a a r w Cl) R 0) (D co N n O O) N m co O d U L0) 0 L (- m N C L M to Cl) V Cl) M Cl) O M M m N O 0) M M N N co c- M M O M N O M M N 1� V M M co n ND Cl) M Cl) Cl) O O Cl) M Cl) Go O Cl) N M M Cl) O V O M Cl) Cl) 0) N Cl) 01 N m r- N co Cl) ao O (D N M wN d d CO 0 ` 0) Z to m O) If] m 0) In O 0) In OD 01 In O 0) In OD () In OD 0) In OD m In OD CO In co 0) N OD 0) In 00 0) In co 0) LO d 0 U C d W U d C 7 C U M (D (D OD Cl) N co N M In N In U O d d O) N O I- M m In N M O In 6 m - co O O N co O 0) 01 O O O (D V' O w d U d U d m T @ c0 O In O Cl) O M O N O O OO) O c0 O) 00 Q) r- 01 1n OI l0 O) M d) D) d a Jo '2 Z N ❑ 0) Cl) (l N In O Cl) M 1- O O (0 (N O O 0) O M N O N V N (D OD W 00 OR 0) In O OD M O 0) U7 0) In V (C _ V) y N �f (D _ N N (D _ N (D _ N O (D _ N OD In _ N (D m _ N (0 In _ N In In _ N '7 (O _ N N (O _ N (n _ N O) V _ N c - V _ N Z � 0 0 (n (n 0 0 r� (O O o o O (D rn v O O o v O o Cl) co In O O o 0) O O 0 O O O 0 O o C co In O o a) 00 O rn v N g O V) x O Lr .- 16 N L N N N Ln N LO Cl! 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N a O O O O O N N 6 N n n n W Cl) W O N LO « LO N O (D O n North America - ALASKA - BP PBU S S-201 Plan S -201A S -201A WP05 Anticollision Summary Report 27 February, 2019 Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-201 Well Error: 0.00usft Reference Wellbore Plan S -201A Reference Design: S -201A WP05 BP Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-201 PLAN KB P272 @ 83.05usft PLAN KB P272 @ 83.05usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference S -201A WP05 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria WARNING: There is hidden tight data in this project Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 5,737.97 to 7,087.12usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 904.00usft Error Surface: Elliptical Conic Survey Tool Program Date 2/27/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 138.63 3,218.45 S-201PB1 (S-201PB1) MWD+IFR:AK MWD +IFR[Alaska] 3,310.46 5,737.97 S-201 MWD -IFR Sperry (S-201) MWD+IFR:AK MWD + IFR [Alaska] 5,737.97 6,050.00 S -201A WP05 (Plan S-201 A) BLIND Blind drilling 6,050.00 7,087.12 S -201A WP05 (Plan S-201 A) MWD MWD - Standard 6,050.00 7,087.12 S -201A WP05 (Plan S -201A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) S S-100 - S-100 - S-100 Out of range S-101 - S-101 - S-101 Out of range S-102 - S-102 - S-102 Out of range S-102 - S-1021-1 - S-1021-1 Out of range S-102 - S -102L1 PB1 - S -102L1 PB1 Out of range S-102 - S-102PB1 - S-102PB1 Out of range S-103 - S-103 - S-103 5,907.54 5,850.00 35965 198.99 162.89 Pass - Major Risk S-104 - S-104 - S-104 Out of range S-105 - PLAN S-1 05A - S-1 05A WP13 Out of range S-105 - S-105 - S-105 Out of range S-106 - S-106 - S-106 Out of range S-106 - S-106PB1 - S-106PB1 Out of range S-107 - S-107 - S-107 Out of range S-108 - S -108A' - S -108A Out of range S-111 - S-111 - S-111 Out of range S-111 - S-111 P131 - S-111 P61 Out of range S-111 - S-111 P62 - S-111 PB2 Out of range S-113 - S-113 - S-113 Out of range S-113 - S-11 3A - S-11 3A Out of range S-113 - S-11 3B - S -113B Out of range S-113 - S-113BL1 - S-113BL1 Out of range S-114 - S-114 - S-114 Out of range S-114 - S-1 14A - S -114A Out of range S-119 - S-119 - S-119 Out of range S-120 - S-120 - S-120 Out of range S-122 - S-122 - S-122 6,097.27 6,150.00 301.15 157.51 143.70 Pass - Major Risk S-122 - S-122PB1 - S-122PB1 6,097.27 6,150.00 301.15 157.65 143.57 Pass - Major Risk S-122 - S-122PB2 - S-122PB2 6,097.27 6,150.00 301.15 157.52 143.70 Pass - Major Risk S-122 - S-122PB3 - S-122PB3 6,097.27 6,150.00 301.15 157.51 143.70 Pass - Major Risk S-200 - S-200 - S-200 Out of range S-200 - S -200A - S -200A Out of range S-201 - S-201 - S-201 6,044.04 6,050.00 70.45 2.02 70.45 Pass - NOERRORS 2/27/2019 2:40:49PM Page 2 of 3 COMPASS 5000.1 Build 81D Company: NorthAmerica- ALASKA - BP Project: PBU Reference Site: S Site Error: O.00usft Reference Well: 5-201 Well Error: 'O.00usft Reference Wellbore Plan S -201A Reference Design: S -201A WPO5 BP Anticollision Report Local Co-ordinate Reference: Well S-201 TVD Reference: PLAN KB P272 @ 83.05usft MD Reference: PLAN KB P272 @ 83.05usft North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM R5K - Alaska PROD - ANCP1 Offset TVD Reference: Offset Datum Reference Depths are relative to PLAN KB P272 @ 83.05usft Coordinates are relative to: S-201 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 ` OGP-Usa AK Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91' Ladder Plot 0 1500 3000 4500 6000 7500 9000 -4r S -104,S -104,S -104V3 $ S-Ivlea(�PaZJe R69bulus�n) -0- S-122,S-122PB2,S-122PB2V2 $S -108,S -108,S -108V6 $ S-106, S-106, S-10 V2 l $ S-119, S-119, S-119 V7 $ S-107, S-107, S-107 V36 -f S-110, S-110, S-110 V1 8 -I�'- S-110, S-1106, S-11 OB VO -fir• S -110,S-11 OA, S-11 OA VO $ S-100, S-100, S-100 V10 $ S-101,S-101PB1,S-101PB1 V10 $ S -101,S -101,S-101 V5 1E- S-102,S-102L1PB1,S-102L1PB1 V11 ->� S-1 02, S-1 021-1, S-1 021-1 V5 $ S-213, S-213AL3, S-213AL3 V7 S-213,S-213AL1,S-213AL1 V9 -r�- S-213, S-213AL2, S-213AL2 V5 $ S-213, S-213, S-213 V9 S-213,S-213ALl-01,S-213ALl-01 V7 $ S-213, S -213A, S -213A V22 $ S-200,S-200PB1,S-200PB1 V10 �F S-200, S-200, S-200 V1 ->�- S-200, S -200A, S -200A VO $ S-120, S-120, S-120 V4 - S-113, S -113A, S -113A V3 -r�- S-113, S-1138, S-1138 V6 $ S-113, S-113, S-113 V14 $ S-113,S-113BL1,S-113BL1 VO $ S-112, S-112, S-112 V20 $ S-112, S-1121-1, S-1121-1 VO -Xf S-112,S-112L1PB2,S-112L1PB2V0 $ S-112,S-112L1PB1,S-112L1PB1 VO 2127/2019 2 40:49PM Page 3 of 3 COMPASS 5000.1 Build 81D (ui/ljsn OS oe VISC O m m m 800 D; LD og�-- 850 0 900 hmox E E CL o z =5s5' z a C �^ L2?E�� 1000 p s� 1050 + m V pr Z� CNw 1150 li 0 N C m N � U 1250 3 J F w o O d LU 0 O m i= o o c O O P LU F^ O p (ui/ljsn OS oe VISC O �ti 800 D; LD og�-- 0 as N m afgNaN oN?ia°� a 30 � o � ❑ e°Oe � S Q 07 U. x�w{i7 -Z 9RfSI I c RD m Rl p71. J O O O O O O O O O O O O O O O O O C (u1/Usn 001) g3doQ luollian orul 800 850 900 0 950 z a C �^ 1000 p s� 1050 + m Y 1100 pr Z� W 1150 li 1200 j U 1250 3 1300 O p 1350 2m L m M. Ra a_a 1400 0 1450 a a -M.Mm NLLNN� 1500 1550 1600 � o � ❑ e°Oe � S Q 07 U. x�w{i7 -Z 9RfSI I c RD m Rl p71. J O O O O O O O O O O O O O O O O O C (u1/Usn 001) g3doQ luollian orul O O f— a a > N ry m LC) Uf) M aI m N d d y Q N JI d m cff O N O ¢ M CO f- # 9 0 1 t b f D 0 1 1 P Q L C7 O `m m m m G a n � u O O I%1 a N m m a a N a N JI N til Y N a Ow Ih (h Ih J, 16 Ih h h h h Ih d U ! 0# 0 0 b g s _ N q > > > c0 O o > Cl) (O (f) N Jl JI 2 J1 n� J J N J a � QQ Qa QQ O f- O N N Li Cn (o (O u u a N y m w u! m u 7100 Q 11 n� m aIn ccc LLOmmm o�aaa N CN ��SLLSS ddd aa2¢¢¢ 00000 j N N N N N v m o taino�r; N 1000 Q MNfDnn EM -100 ocq a aloo U-M�M�N Q�MI�00 N a a > N ry m v m m > N � O o N aI m N d d y Q N JI d m cff V I) N N N Q w Jl y ul � Jl III dl fA (h fA (h dl (d 7 # 9 0 1 t b f D 0 1 1 P Q L > > S > S `m m m m G a n � u _ry > S a> ^ n 3 `> N J1 J1 JI IA I%1 a N m m a a N a N JI N til Y N O n a N ti) JI JI N JI N N V! U Ih (h Ih J, 16 Ih h h h h Ih d ! 0# 0 0 b g s _ N q > > > a m N m m m N Jl JI 2 J1 n� J J N J a � QQ Qa QQ a o N d to J1 N V) N N N y JI UI N III a N N N. N N UI .... N a b# 0 0 1 j a j u u a N y m w u! m u a m a o a o o a J, di IA III fh J, IA In uS y J, aS J 666666666(h6 d3 (hJ #¢ b/ I b# 0! f I 0# 4 .Ili 66NIZI, 00 0 'ANN N�mm �eZo �¢aa mm ay `m o�aaa ��oaaa �m�333 a ¢¢a ZNNNNN Om�II]Nnn a U E 0 I �.� 5�ggg Q mm3 mmmmmmmmmmmm 0 mmmmmmmmmmmm E m>>>R�gRRRmy�B M S n N `rh;nrama�m��-qui m .� g gg8soi9B - - -rv8 m m m m m m m m m m m m m m 0 N v m o0 m a s; N o TRANSMITTAL LETTER CHECKLIST WELL NAME: P_b (A- PTD: a j9 - C24 Development VService _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: Pr cJkoe, Bay POOL: Po F a, l^ I$ O f t Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by Vf (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC V within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 _ Well Name: PRUDHOE BAY UN POL S -201A _Program SER Well bore seg 1:1I PTD#: 2190920 Company BP Exploration (Alaska) Inc_ Initial Class/Type SER / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ❑ Administration 1 Permit_fee attached_ - NA_ Existing 20" conductor_ - - - - - - - - - - - 2 Lease number appropriate_ Yes - - - - - -- - - - - NA_ 3 Unique well name and number - - _ - - - - - - - - Yes - CMT_v_oladequate_to circul_ate_on conductor_& su_rf_csg - - - - - - - - - - - - - - - - 4 Well located in a_defined _pool _ Yes 21 5 Well located proper distance from drilling unit -boundary Yes 6 Well located proper distance from. other wells- - - . Yes - - Fully cemented across_ injection interval_ - - - - - - - - - '7 Sufficient acreage available in drilling unit - - - - . Yes - 8 If -deviated, is wellbore plat -included - - - Yes Directional -plan-& wellbore profile views included._ 9 Operator only affected party _ - - Yes - 10 Operator has. appropriate bond in force - - - - - - - - - - - Yes If -a. re -drill, has a 1.0403 for abandonment been approved - - - - 11 Permit can be issued without conservation order Yes Appr Date 12 Permit -can be issued without administrative approval - - - - - - - - -Yes - - - - Planned wellpat_h-passes all BP separation -criteria 13 Can permit be approved before 15-day_wa_it- - - - - - - - - - - - - - - Yes _ - DLB 6/17/2019 Appr Date 28 Drilling fluid. program schematic_& equip list -adequate - - - - - - - - - Yes 14 Well located within area and strata authorized by Injection Order # (put_ 10# in -comments) (For_ Yes - - - - - - Governed by C0484. ------- --------- BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - 15 All wells- with 0.1/4 -mile area.of review identified (For service wel_I only)_ Yes.... 30 16 Pre -produced injector duration of pre -production less- than 3 months _(For service well only) Yes - - - - - - - - - - - - - - - - - - - - - 17 Nonconve_n. gas conforms to AS31.05.0304.1-.A),(j.2.A-D) - - - - - NA i18 _Conductor string -provided - - - . - - - - - - - - - - - - - - - - - - . - Yes Existing 20" conductor_ - - - - - - - - - - - Engineering 19 Surface casing_protects all known USDWs - - - - NA_ Sidetrack below surface casin 20 CMT_v_oladequate_to circul_ate_on conductor_& su_rf_csg - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - Drilling_w_ill -be from existing -intermediate interval only 21 CMT_vol adequate to tie -in -long string to surf csg_ - NA_ Production -interval fully cemented_ - - - 22 _C_MT_will coverall known -productive horizons_ - - - - - - - - - Yes Fully cemented across_ injection interval_ - - - - - - - - - 23 _Casing designs adequate for C,_T_, B &_ permafrost - - - - - - - - - - Yes 24 Adequate tankage_or reserve pit Yes Parker 272 is ongoing operations with good truck support 25 If -a. re -drill, has a 1.0403 for abandonment been approved - - - - Yes 26 Adequate wellbore separation_proposed - - - - - - - - - - - - - - Yes - - - - Planned wellpat_h-passes all BP separation -criteria 27 If_diverter required, does it meet_ regulations- - - - - - - - - - - - - - - NA_ - - - - Drilling production hole only from_ existing- Intermediate_ casing Appr Date 28 Drilling fluid. program schematic_& equip list -adequate - - - - - - - - - Yes All fluids overba_lanced_to expected pore pressure- - - - - - - MGR 6/27/2019 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - Yes 3 ram_ stack,_ 1_ annular, flow_ cross - - - - - - - - - - - 30 BOPE_press rating appropriate; test to (put psig in comments)_ - - - - - - Yes 5M BOPE stack, tested to 4000 psi, -annular to 3500 psi 131 Choke -manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - Yes Parker 272 in ongoing operations, AOGCC_inspectors to -assure compliance - - - 32 Work will occur without operation shutdown_ Yes Parker 272 will be in ongoing drilling_ operations - - - - - - 133 Is presence of H2S gas probable No_ PBU S Pad is_not_considered a_n_H_2S-pad 34 Mechanical -condition of wells within AOR verified (For_service well only) .. - Yes - - 35 Permit_can be issued w/o hydrogen _Sulfide measures - - - - - - - - _ - _ NO_ - - - S--PadIS an H2S site_ H2S meas -ores are required- - - - - - Geology 36 -Data-presented on potential ove_rpressur_e zones - - - - - - - - - - - - - - - - Yes No abnormally geo-pressured strata -are anticipated. Appr Date 37 Seismic_analys_is_ of shallow gas -zones_ - - - - - - - - - - NA_ DLB 6/17/2019 38 Seabed condition survey -(if off_ -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - 39 Contact name/phone for weekly -progress reports- [exploratory only] - - - - - - - - - - - - - - NA_ - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date �'�