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Home My WebLink About222-001MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2025 V-213A 50-029-23213-01-00 222-001-0 N SPT 2449 2220010 3100 93 3550 3315 3263 53 53 53 52 REQVAR P Bob Noble 4/23/2025 1 year MIT-T as per IO AA 26B.007 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 452 458 459 457IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250425150204 BBL Pumped:1 BBL Returned:0.9 Tuesday, June 10, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 9 MIT-T AA 26B.007 James B. Regg Digitally signed by James B. Regg Date: 2025.06.10 16:05:54 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 7, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/07/2024 V-213A 50-029-23213-01-00 222-001-0 G SPT 2449 2220010 3100 1730 1736 1725 1723 102 149 155 152 REQVAR P Bob Noble 4/14/2024 AOGCC 2 year MIT-IA per AIO AA 26B.007. Max psi of 3100 psi 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 315 3382 3185 3116IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240415140318 BBL Pumped:2.3 BBL Returned:2.2 Friday, June 7, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO AA 26B.007 James B. Regg Digitally signed by James B. Regg Date: 2024.06.07 14:10:38 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/22/2024 V-213A 50-029-23213-01-00 222-001-0 N SPT 2449 2220010 3100 855 3601 3424 3383 51 53 54 56 REQVAR P Kam StJohn 4/9/2024 1 Year AOGCC MIT-T as per AIO 26B.007 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 515 514 513 513IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240410142136 BBL Pumped:0.4 BBL Returned:0.7 Wednesday, May 22, 2024 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 V-213A 50-029-23213-01-00 222-001-0 N SPT 2449 2220010 3200 162 3619 3334 3272 58 55 55 55 REQVAR P Adam Earl 4/16/2023 MIT-T tested as per AIO 26B.007 to MAIP 3200 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 568 569 564 562IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230419200502 BBL Pumped:0.9 BBL Returned:1 Friday, May 19, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 MIT-T tested as per AIO 26B.007 James B. Regg Digitally signed by James B. Regg Date: 2023.05.19 16:25:03 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23213-01-00Well Name/No. PRUDHOE BAY UN ORIN V-213ACompletion StatusWAGINCompletion Date4/21/2022Permit to Drill2220010Operator Hilcorp North Slope, LLCMD6675TVD4965Current StatusWAGIN8/31/2022UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/PCG-GR/ADR, Cement EvaluationNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF3/4/20223480 6676 Electronic Data Set, Filename: PBU V-213A LWD Final.las36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final MD.cgm36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final TVD.cgm36395EDDigital DataDF3/4/2022 Electronic File: V-213A Surveys.xlsx36395EDDigital DataDF3/4/2022 Electronic File: V-213A_defintive survey report.pdf36395EDDigital DataDF3/4/2022 Electronic File: V-213A_defintive survey report.txt36395EDDigital DataDF3/4/2022 Electronic File: V-213A_GIS.txt36395EDDigital DataDF3/4/2022 Electronic File: V-213A_Plan.pdf36395EDDigital DataDF3/4/2022 Electronic File: V-213A_VSec.pdf36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final MD.emf36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final TVD.emf36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final MD.pdf36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final TVD.pdf36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final MD.tif36395EDDigital DataDF3/4/2022 Electronic File: PBU V-213A LWD Final TVD.tif36395EDDigital DataDF5/19/2022-11 6478 Electronic Data Set, Filename: PBU_V-213A_RBT_29APR22_FieldData.las36634EDDigital DataDF5/19/2022-11 6478 Electronic Data Set, Filename: PBU_V-213A_RBT_29APR22_ProcessedLog-V1.las36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22.pdf36634EDDigital DataWednesday, August 31, 2022AOGCCPage 1 of 3PBU V-213A LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23213-01-00Well Name/No. PRUDHOE BAY UN ORIN V-213ACompletion StatusWAGINCompletion Date4/21/2022Permit to Drill2220010Operator Hilcorp North Slope, LLCMD6675TVD4965Current StatusWAGIN8/31/2022UICYesDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22_FieldData.dlis36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22_img.tiff36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22_ProcessedLog-V1.dlis36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22_ProcessedLog-V1.pdf36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_29APR22_ProcessedLog-V1_img.tiff36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_ProcessedLog-Comparison_img.pdf36634EDDigital DataDF5/19/2022 Electronic File: PBU_V-213A_RBT_ProcessedLog-Comparison_img.tiff36634EDDigital DataDF5/19/20226380 2495 Electronic Data Set, Filename: V-213A_RBT_03MAR22_MainPass.las36635EDDigital DataDF5/19/20222495 6380 Electronic Data Set, Filename: V-213A_RBT_03MAR22_ProcessedLog-V2.las36635EDDigital DataDF5/19/2022 Electronic File: V-213A RBT 03MAR22.pdf36635EDDigital DataDF5/19/2022 Electronic File: V-213A RBT 03MAR22_img.tiff36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_03MAR22_MainPass.dlis36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_03MAR22_ProcessedLog-V2.dlis36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_03MAR22_ProcessedLog-V2.pdf36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_03MAR22_ProcessedLog-V2_img.tiff36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_29APR22_ProcessedLog-V1-compressed.pdf36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_29APR22_ProcessedLog-V1.pdf36635EDDigital DataDF5/19/2022 Electronic File: V-213A_RBT_ProcessedLog-Comparison_img.pdf36635EDDigital DataWednesday, August 31, 2022AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23213-01-00Well Name/No. PRUDHOE BAY UN ORIN V-213ACompletion StatusWAGINCompletion Date4/21/2022Permit to Drill2220010Operator Hilcorp North Slope, LLCMD6675TVD4965Current StatusWAGIN8/31/2022UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud 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:4/21/2022Release Date:1/19/2022Wednesday, August 31, 2022AOGCCPage 3 of 3M. Guhl8/31/2022 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: UPDATE UNDER EVALUATION: Injector V-213A (PTD #2220010) TxIA Communication Date:Wednesday, August 3, 2022 11:11:39 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, August 3, 2022 10:56 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: Re: UPDATE UNDER EVALUATION: Injector V-213A (PTD #2220010) TxIA Communication Ryan, Your request to extend the under evaluation period and continue monitoring under stable injection while the submitted admin approval request is being processed is approved. As the Admin Approval was originally written for a cement packer (with no mention of a pressure communication) then the TxIA is new from 07/07/22 and there are no valid MIT’s? Based on the new/current diagnostics and the sliding sleeve failure, am I correct in assuming the well would now not pass a MITIA in its present state? A combo mit tubing IA would be required with a deep plug to check the tubing now? Was there a leak detect log run or what what is Hilcorp’s understanding of where the leak is? Potential fix? Changes to the Admin Approval conditions are not proposed which would seem in conflict with the need to test the well under new TxIA conditions? When is Hilcorp proposing to test this well? What am I missing here? Thanks Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 2, 2022 5:06:40 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> Subject: UPDATE UNDER EVALUATION: Injector V-213A (PTD #2220010) TxIA Communication Mr. Wallace, Injector V-213A (PTD #2220010) AA amendment request was submitted on 07/26/22. The initial 28 day under evaluation period ends on 08/04. Would it be unreasonable to extend the under evaluation period and leave the well on stable injection while the AA is being reviewed? Thanks, 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 Sent: Thursday, July 7, 2022 4:00 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector V-213A (PTD #2220010) TxIA Communication Mr. Wallace, Injector V-213A (PTD #2220010) has been observed to have anomalous IA re-pressurization ~15 psi per day. On 07/07/22, DHD found the IA fluid level to be at ~60’ which also indicates TxIA while the well is on MI injection. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Cycle sliding sleeve @ 2996’ 3. Well Integrity: Further diagnostics and testing as required 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 Sent: Thursday, May 5, 2022 7:00 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector V-213A (PTD #2220010) Post Rig Mr. Wallace, Injector V-213A (PTD #2220010) passed AOGCC MIT-T & CMIT-TxIA on 04/29/22 post RWO. An online AOGCC MIT-IA will be scheduled once the well is thermally stable. At this time, the well is classified as OPERABLE while the AA is processed. Please call with any questions. 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, February 7, 2022 7:44 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-213A (PTD #2220010) Tubing Cut pre-Rig Mr. Wallace, Injector V-213A (PTD #2220010) had the tubing cut on 02/06/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. 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 isstrictly 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 recipientshould 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: Injector V-213A (PTD #2220010) TxIA Communication Date:Tuesday, July 12, 2022 2:17:46 PM Attachments:image002.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, July 7, 2022 4:00 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> Subject: UNDER EVALUATION: Injector V-213A (PTD #2220010) TxIA Communication Mr. Wallace, Injector V-213A (PTD #2220010) has been observed to have anomalous IA re-pressurization ~15 psi per day. On 07/07/22, DHD found the IA fluid level to be at ~60’ which also indicates TxIA while the well is on MI injection. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Cycle sliding sleeve @ 2996’ 3. Well Integrity: Further diagnostics and testing as required 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 Sent: Thursday, May 5, 2022 7:00 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector V-213A (PTD #2220010) Post Rig Mr. Wallace, Injector V-213A (PTD #2220010) passed AOGCC MIT-T & CMIT-TxIA on 04/29/22 post RWO. An online AOGCC MIT-IA will be scheduled once the well is thermally stable. At this time, the well is classified as OPERABLE while the AA is processed. Please call with any questions. 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, February 7, 2022 7:44 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-213A (PTD #2220010) Tubing Cut pre-Rig Mr. Wallace, Injector V-213A (PTD #2220010) had the tubing cut on 02/06/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. 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 isstrictly 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 recipientshould carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2022 V-213A 50-029-23213-01-00 222-001-0 G SPT 2449 2220010 1500 2590 2593 2588 2584 383 597 598 577 INITAL P Guy Cook 5/9/2022 Testing 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 1221 3265 3138 3102IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220508164009 BBL Pumped:1 BBL Returned:1 Friday, June 10, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 15:03:45 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/18/2022 V-213A 50-029-23213-01-00 222-001-0 N SPT 2449 2220010 3200 367 3449 3355 3317 81 251 254 254 OTHER P Brian Bixby 4/29/2022 CMIT-IA as per Sundry 322-111, NOTE: This is a Packerless completion. 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 330 3409 3320 3283IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220430053042 BBL Pumped:2.1 BBL Returned:2.1 Friday, June 10, 2022 Page 1 of 1 5(9,6(' 9 9 9 9 9 9 9 9 9 9 2449 James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 13:52:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-213A PRUDHOE BAY UN ORIN V-213A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/18/2022 V-213A 50-029-23213-01-00 222-001-0 N SPT 2449 2220010 3200 710 3419 3258 3217 75 77 77 77 OTHER P Brian Bixby 4/29/2022 MIT-T as per Sundry 322-111, NOTE: This is a Packerless completion. 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 ORIN V- 213A Inspection Date: Tubing OA Packer Depth 82 156 172 170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220430055358 BBL Pumped:0.7 BBL Returned:0.7 Friday, June 10, 2022 Page 1 of 1 5(9,6(' 9 9 9 9 9 9 9 9 2449 James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 13:55:07 -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: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Date:Thursday, May 19, 2022 11:18:15 AM Attachments:V-213A_RBT_29APR22_ProcessedLog-V1-compressed.pdf V-213 Cement Squeeze Reports.pdf From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, May 2, 2022 1:28 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: FW: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, May 2, 2022 11:37 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Eric Dickerman <Eric.Dickerman@hilcorp.com>; Ryan Holt <Ryan.Holt@hilcorp.com>; Andrew Ogg <Andrew.Ogg@hilcorp.com> Subject: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Hello Mel, Coil successfully completed a remedial squeeze of V-213A (PTD #222-001)’s cement packer under sundry #322-111. An initial squeeze on 4/19/22 was unsuccessful due to over displacement of cement while circulating out excess. The subsequent squeeze on 4/20/22 successfully pumped a full 3.5”x7” annular volume of ~ 13 bbls through the sliding sleeve at 2996’ MD down the IA and to the millout window at ~3500’ MD. Activity reports including cement details are attached for reference. The well had a successful AOGCC witnessed MIT-T and MIT-IA to 3200 psi on 4/29/22 confirming annular isolation post squeeze. A CBL run on 4/29/22 (attached) confirmed greatly improvement cement bond in the annulus below the sliding sleeve. Annular Isolation/Cement Packer – Achieved The CBL run on 4/29/22 confirmed good cement bond below the new TOC of ~ 2990’ MD (up from 3323’ pre squeeze) with CBL amplitudes decreased from ~ 50 mV to ~10 mV post squeeze. Similarly, VDL returns show areas of high attenuation indicating good tubing-to-cement- casing bond. There is no indication of channeling in the cement map/image. Vendor Comments (specific to initial 3.5” tubing-to cement interface only, does not reflect cement to casing bond): From top-1400 ft MD: free pipe to poor bonded cement. From 1400-2980 ft MD: patchy bonded cement with average bond index of 35%. From 2980-bottom: very good bond. The passing MIT-IA to 3200 psi and bond log results confirm well has IA integrity and is now ready for injection. Please let us know if you have any questions and if we have approval to place well on injection for initial, injecting MIT-IA. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads) O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, March 4, 2022 12:41 PM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Cc: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: V-213A (PTD #222-001) 3.5" Completion Cement Bond Log Hello Mel, We ran the V-213A (PTD #222-001) bond log yesterday 3/3/22 (attached). The bond log showed good cement across and above the injection interval up to our millout window. Unfortunately the TOC of the 3.5”x7” cement packer ended up ~ 320’ deeper than planned with TOC called at 3323’ MD. Yesterday’s MIT-T to 3200 psi passed but the CMIT-TxIA failed with pressure breaking over at 1800 psi for a .25BPM leak rate, presumably through the cement packer. Additional details and bond log interpretation included below. V-213A Cement Log Evaluation Isolation of Injection Fluids - Achieved The CBL run on 3/3/22, confirmed excellent cement bond across the injection interval. This injection interval includes the OA, OBA, OBB and OBD sands from 6,022’ MD to 6351’ MD. In this instance excellent bond is attributed to CBL amplitudes <10 mv as well as strong attenuation and formation returns observed in the VDL track. Additionally there is no indication of channeling in the cement map/image. This excellent cement bond continues up to roughly 3670’ providing ~ 2350’ of well bonded cement above the injection zone. Monitorable Annulus Clear of Cement - Achieved TOC picked at 3323’, ~320’ below the sliding sleeve confirms an uncemented, monitorable, annuls down to at least target depth of 3000’ MD. Subsequent leak rate during CMIT-TxIA confirms full 3.5”x7” annulus is in communication currently. Annular Isolation/Cement Packer –*Remediation Required* The CBL shows an interval of good to poor cement from ~3670’MD up to the picked TOC at 3323’ MD. Areas of better bond quality with CBL amplitude <20 mV and some VDL attenuation are present from 3410’ MV down to 3470’MV as well as patchy/poor bond from 3510’ MD- 3560’MD as evidenced by near free pipe amplitudes and lack of VDL attenuation. CMIT appeared to hold at 1800 psi before breaking over and establishing .25 BPM leak rate suggesting we do not have annular isolation between 3.5”x7”. We will perform a temperature log to confirm that flow path is through the cement packer. During the cement job we returned 10 bbls of excess cement from above the sliding sleeve suggesting initial TOC was up to at least 3000’. We suspect that, after cement was in place, cement column may have fallen back/utube’d with fluids on the uncemented backside of the 7” casing. Please let me know if above bond log evaluation does not meet PTD conditions of approval or if you need any additional information. I will plan to include relogging CBL along with additional cement evaluation summary in any remedial cement program. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, February 25, 2022 3:55 PM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Cc: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: V-213A (PTD #222-001) 3.5" Completion Cement Job Report Hello Mel, Per the V-213A (PTD #222-001) PTD conditions of approval please see attached cementing report from the cement job on the 3.5” completion for this well. Well service report also included below for reference. Overall the cement job appeared to go very well. We had full returns throughout the job, bumped plug then successfully sheared out our sliding sleeve at ~3000’ MD, returning 10 bbls of cement from above the sleeve. A follow-up CBL will be logged as part of slickline post rig work. Log and interpretation will be provided as soon as we have it. 2/25/22 Cement Job Service Report “Establish circulation through IA back to pits. Stage pumps to 4 bpm- 565 psi. Max Gas 390u. Perform cement job, pump 33 bbls 10.5# Tuned spacer 5.5 bpm 367 PSI. 128 bbls. 15.3# Type I/ II cmt, 1.235 yld (545sx), initial pump rate 3 bpm 369 psi slowing to 2 bpm psi at 60 bbls away FCP 161. Max Gas 388u. Launch dart. HES displace w/ 10 bbls H2O (HES) then turn over to rig. Rig disp w/ 46.4 bbls 9.5# inhibited brine, 2 bpm ICP 370 psi reduced rate last 3 bbls to 1 bpm, FCP 749 psi. Bump plug (1405 psi) with 46.4 bbls actual / 46.7 bbls calculated. Held pressure for 5 minutes, check floats - good. CIP @ 21:43 hrs. Full returns throughout job. MIT 3.5" tubing to 1,500 psi for 30 min on chart, good. Cont to Press up to 4,112 psi to shear rupture disk in Defender. Had to cycle pumps to get rupture disk fully sheared. Displaced 9.5 ppd mud to 9.5 ppg corrosion inhibited brine. Saw spacer at surface and about 10 bbls of cement. Blow down all lines. R/D IA. L/D cement head. Switch to completion AFE at 00:00.” Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 ifyou 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 immediatelynotify 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 considersappropriate. ACTIVITY DATE SUMMARY 4/17/2022 T/I/O = SI/1500/350. Barriers = MV , SSV,- WV,& LAT. Verified by performing independent LTT (passed). Removed SV Bonnet, Gate & Seats. Inspected Seat Pockets (passed). Installed new Seat Seals, Seats, Gate & rebuilt Bonnet. Pressure tested SV 300/low & 4000/high (passed). RDMO ***Job Complete*** 4/18/2022 CTU #9 - 1.75" Coil Job Objective: Cement Squeeze through sleeve, Mill CBP MIRU CTU. ...Continued on WSR 4-19-22........ 4/19/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-18-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP Rig up CTU. Make up cementing BHA with HB-3 sleeve shifting tool. RIH and tag 3- 1/2" CBP at 3007' E / 3015' M. PU to 3004'. Pump down the coil taking returns from the IA (good 1:1 returns). Close IA and bullhead diesel down the coil taking returns through sliding sleeve to formation (0.5 BPM at 2250 psi WHP). PU to 2976' and confirm TxIA communication one last time. Circulate the coil and tubing to KCL to warm the coil. Circulate in 15 BBL's of 13 ppg FineCem and 15 BBL's of 15.8 ppg class "G" cement to the nozzle. Squeeze ~ 11.6 BBL's of cement through the sliding sleeve. Unable to achieve squeeze or get non freezable fluid off surface. POOH while reverse circulating. S/I the swab and finish reverse circulating to tanks. Attempt to RBIH and find the swab handle is stripped. Pump 10 BBL gel pill through the coil to tanks. Unstab and break down tools while WS works on swab valve. MU Baker 2-1/8" motor & 2.80" 3-blade junk mill. Drift to CBP and pump powervis sweep off bottom, spot powervis across sliding sleeve in attempt to contaminate any residual cement. ...Continued on WSR 4-20-22... 4/20/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-19-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP POOH with milling BHA, laying in diesel. Circulate 1.5 bbls of powervis through sleeve and up IA to contaminate any cement across sleeve. Unit secured, standby for cement compressive strength, Attempt CMIT-TxIA and establish injectivity of 0.3 bpm at 1607 psi, 0.4 bpm at 2180 psi, and 0.47 bpm at 2470 psi. Will proceed with second cement job. Make up sleeve shifting/cementing BHA and RIH. Tag top of plug at 3003'. Circulate 50 bbls of KCL to warm up the coil and well followed by 20 bbls of diesel to feeze protect the bsct. Circulate in 6 bbls of 13 ppg FineCem and 7 bbls of 15.8 ppg Class G cement. Able to squueze 10 bbls behind pipe. Lay in 3 bbls and hesitate squeeze. ****Continued on 04/21/22*** 4/21/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-20-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP Hesitate squeeze w/ 3 bbls of cement. Unable to achieve squeeze pressure. Overdisplace/ with 3 bbls of diesel. Circulate 2 bbls of diesel down IA to ensure path clear. RIH with HB-3 shifting tool and close sleeve. Pressure test tbg to 1500 psi to confirm sleeve closed. Launch 1/2" steel ball ond open circ sub. Chase ooh any residual cement in tbg. Pump drift ball and gel sweep at surface. Standby for cement. Est TOC ~3110' in IA. Pressure test IA Passed to 2000 psi.Lost 92/27 for a total of 119 psi in 30 mins. ***Continued on 04/22/22*** Daily Report of Well Operations PBU V-213A Daily Report of Well Operations PBU V-213A 4/22/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-21-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP MU & RIH with Baker 2-1/8" milling BHA with 2.80" 3-bld junk mill. MIll CBP and push to 6473' CTMD (~9' above landing collar), milling contaminated cement from 6460- 6473 CTMD. POOH jetting jewelry and FP well with diesel. RDMO CTU. ***Job Complete*** ***CBP debris most likely throughout wellbore and in WFR Mandels due to multiple overpulls*** 4/28/2022 MIT T to 3552 psi. ( PASSED ) Lost 153 psi. in 1st 15 min 28 psi, in 2nd 15 min. MIT IA to 3538 psi. ( PASSED ) Lost 150 psi. in 1st 15 min and 47 psi. is 2nd 15 min. Bled TBG and IA down to starting pressures andhung tags on SV and IA valve. DSO notified of results. FWHP's = 48/0/78 4/28/2022 ***WELL S/I ON ARRIVAL*** MOVE IN & RIG UP ***WSR CONTINUED ON 4-29-22*** 4/29/2022 ***WSR CONTINUED FROM 4-29-22*** RAN 3-1/2" BRUSH w/ 2.78" GAUGE RING TO 6,459' SLM (6,483' MD) RAN 10' x 2.5" PUMP BAILER TO 6,483' MD RAN HES CBL FROM TD TO SURFACE LRS PERFORM PASSING STATE WITNESSES MIT-T & MIT TxIA TO 3,200 psi SET 3-1/2" X-CATCHER IN X-NIPPLE @ 6,412' MD PULLED ST#1 BK-DGLV FROM 6,326' MD SET ST#1 BK-FLOW SLEEVE @ 6,326' MD. ***WSR CONTINUED ON 4-30-22*** 4/29/2022 T/I/O= 700/80/75 (CEMENT SQUEEZE) Assist PSL and AOGCC testing AOGCC (Brian Bixby) MIT-T to 3217 psi ****PASSED**** Pumped 0.7 bbls diesel to reach max applied 3419 psi Target 3200 psi. 1st 15 minute T lost = 161 psi. 2nd 15 minute T lost = 41 psi. Total 30 min loss = 202 psi. Bled back .7 bbls AOGCC (Brian Bixby) CMIT-TxIA to 3317/3283 psi ****PASSED**** Pumped 2.1 bbls diesel to reach max applied 3449/3409 psi Target 3200 psi. 1st 15 minute T/I lost = 94/89 psi. 2nd 15 minute T/I lost = 38/37 psi. Total 30 min T/I loss = 132/126 psi. Bled back 2.1 bbls SL in control upon LRS departure FWHP's = 1200/500/90 4/30/2022 T/I/O=780/516/90 Assist SL with HPBD/ Injection tests Pumped 486 bbls 1% KCL and 92 bbls DSL for HPBD and injectivity tests. (see log for details) ***job continued to 05-01-22*** 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 Received By: Date: Hilcorp North Slope, LLC Date: 05/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU V-213A (PTD 222-001) RBT 03/03/2022 Field and Processed Logs Please include current contact information if different from above. PTD:222-001 T36635 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.19 09:41:11 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU V-213A (PTD 222-001) RBT 04/29/2022 Please include current contact information if different from above. PTD:222-001 T36634 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.19 09:46:41 -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: Injector V-213A (PTD #2220010) Post Rig Date:Tuesday, May 17, 2022 11:34:23 AM Attachments:RE EXTERNAL RE V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed.msg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, May 5, 2022 7:00 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>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector V-213A (PTD #2220010) Post Rig Mr. Wallace, Injector V-213A (PTD #2220010) passed AOGCC MIT-T & CMIT-TxIA on 04/29/22 post RWO. An online AOGCC MIT-IA will be scheduled once the well is thermally stable. At this time, the well is classified as OPERABLE while the AA is processed. Please call with any questions. 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, February 7, 2022 7:44 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-213A (PTD #2220010) Tubing Cut pre-Rig Mr. Wallace, Injector V-213A (PTD #2220010) had the tubing cut on 02/06/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. 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:Oliver Sternicki Cc:PB Wells Integrity; Eric Dickerman; Wyatt Rivard; Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] RE: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Date:Wednesday, May 4, 2022 9:23:07 AM Oliver, The request by Hilcorp to allow injection in V-213 while the Administrative Approval request is being progressed is granted. 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: Tuesday, May 3, 2022 4:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Eric Dickerman <Eric.Dickerman@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Chris, As discussed earlier today, testing requirements for V-213 have been completed and the well will be ready to be placed on injection in the next few days. We request permission to place the well on injection while the administrative approval request is being drafted, submitted and processed by the AOGCC. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, May 2, 2022 4:53 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wyatt Rivard <wrivard@hilcorp.com> Cc: Eric Dickerman <Eric.Dickerman@hilcorp.com>; Ryan Holt <Ryan.Holt@hilcorp.com>; Andrew Ogg <Andrew.Ogg@hilcorp.com> Subject: [EXTERNAL] RE: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Wyatt, If we have additional testing required above a standard 4 yr MITIA then we would need to receive an application for an administrative approval detailing all the conditions/restrictions being placed on the well. Thanks Chris From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, May 2, 2022 4:40 PM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Eric Dickerman <Eric.Dickerman@hilcorp.com>; Ryan Holt <Ryan.Holt@hilcorp.com>; Andrew Ogg <Andrew.Ogg@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Wyatt, I believe Chris Wallace, AOGCC UIC Engineer, may require a specific admin approval for tracking the annual MIT-T on this well. He is copied on this email. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Chris Wallace, Erick Dickerman, Ryan Hold, Andrew Ogg From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, May 2, 2022 11:37 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Eric Dickerman <Eric.Dickerman@hilcorp.com>; Ryan Holt <Ryan.Holt@hilcorp.com>; Andrew Ogg <Andrew.Ogg@hilcorp.com> Subject: V-213A (PTD #222-001) Remedial Cement Packer Squeeze Completed Hello Mel, Coil successfully completed a remedial squeeze of V-213A (PTD #222-001)’s cement packer under sundry #322-111. An initial squeeze on 4/19/22 was unsuccessful due to over displacement of cement while circulating out excess. The subsequent squeeze on 4/20/22 successfully pumped a full 3.5”x7” annular volume of ~ 13 bbls through the sliding sleeve at 2996’ MD down the IA and to the millout window at ~3500’ MD. Activity reports including cement details are attached for reference. The well had a successful AOGCC witnessed MIT-T and MIT-IA to 3200 psi on 4/29/22 confirming annular isolation post squeeze. A CBL run on 4/29/22 (attached) confirmed greatly improvement cement bond in the annulus below the sliding sleeve. Annular Isolation/Cement Packer – Achieved The CBL run on 4/29/22 confirmed good cement bond below the new TOC of ~ 2990’ MD (up from 3323’ pre squeeze) with CBL amplitudes decreased from ~ 50 mV to ~10 mV post squeeze. Similarly, VDL returns show areas of high attenuation indicating good tubing-to-cement- casing bond. There is no indication of channeling in the cement map/image. Vendor Comments (specific to initial 3.5” tubing-to cement interface only, does not reflect cement to casing bond): From top-1400 ft MD: free pipe to poor bonded cement. From 1400-2980 ft MD: patchy bonded cement with average bond index of 35%. From 2980-bottom: very good bond. The passing MIT-IA to 3200 psi and bond log results confirm well has IA integrity and is now ready for injection. Please let us know if you have any questions and if we have approval to place well on injection for initial, injecting MIT-IA. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, March 4, 2022 12:41 PM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Cc: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: V-213A (PTD #222-001) 3.5" Completion Cement Bond Log Hello Mel, We ran the V-213A (PTD #222-001) bond log yesterday 3/3/22 (attached). The bond log showed good cement across and above the injection interval up to our millout window. Unfortunately the TOC of the 3.5”x7” cement packer ended up ~ 320’ deeper than planned with TOC called at 3323’ MD. Yesterday’s MIT-T to 3200 psi passed but the CMIT-TxIA failed with pressure breaking over at 1800 psi for a .25BPM leak rate, presumably through the cement packer. Additional details and bond log interpretation included below. V-213A Cement Log Evaluation Isolation of Injection Fluids - Achieved The CBL run on 3/3/22, confirmed excellent cement bond across the injection interval. This injection interval includes the OA, OBA, OBB and OBD sands from 6,022’ MD to 6351’ MD. In this instance excellent bond is attributed to CBL amplitudes <10 mv as well as strong attenuation and formation returns observed in the VDL track. Additionally there is no indication of channeling in the cement map/image. This excellent cement bond continues up to roughly 3670’ providing ~ 2350’ of well bonded cement above the injection zone. Monitorable Annulus Clear of Cement - Achieved TOC picked at 3323’, ~320’ below the sliding sleeve confirms an uncemented, monitorable, annuls down to at least target depth of 3000’ MD. Subsequent leak rate during CMIT-TxIA confirms full 3.5”x7” annulus is in communication currently. Annular Isolation/Cement Packer –*Remediation Required* The CBL shows an interval of good to poor cement from ~3670’MD up to the picked TOC at 3323’ MD. Areas of better bond quality with CBL amplitude <20 mV and some VDL attenuation are present from 3410’ MV down to 3470’MV as well as patchy/poor bond from 3510’ MD- 3560’MD as evidenced by near free pipe amplitudes and lack of VDL attenuation. CMIT appeared to hold at 1800 psi before breaking over and establishing .25 BPM leak rate suggesting we do not have annular isolation between 3.5”x7”. We will perform a temperature log to confirm that flow path is through the cement packer. During the cement job we returned 10 bbls of excess cement from above the sliding sleeve suggesting initial TOC was up to at least 3000’. We suspect that, after cement was in place, cement column may have fallen back/utube’d with fluids on the uncemented backside of the 7” casing. Please let me know if above bond log evaluation does not meet PTD conditions of approval or if you need any additional information. I will plan to include relogging CBL along with additional cement evaluation summary in any remedial cement program. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, February 25, 2022 3:55 PM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Cc: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: V-213A (PTD #222-001) 3.5" Completion Cement Job Report Hello Mel, Per the V-213A (PTD #222-001) PTD conditions of approval please see attached cementing report from the cement job on the 3.5” completion for this well. Well service report also included below for reference. Overall the cement job appeared to go very well. We had full returns throughout the job, bumped plug then successfully sheared out our sliding sleeve at ~3000’ MD, returning 10 bbls of cement from above the sleeve. A follow-up CBL will be logged as part of slickline post rig work. Log and interpretation will be provided as soon as we have it. 2/25/22 Cement Job Service Report “Establish circulation through IA back to pits. Stage pumps to 4 bpm- 565 psi. Max Gas 390u. Perform cement job, pump 33 bbls 10.5# Tuned spacer 5.5 bpm 367 PSI. 128 bbls. 15.3# Type I/ II cmt, 1.235 yld (545sx), initial pump rate 3 bpm 369 psi slowing to 2 bpm psi at 60 bbls away FCP 161. Max Gas 388u. Launch dart. HES displace w/ 10 bbls H2O (HES) then turn over to rig. Rig disp w/ 46.4 bbls 9.5# inhibited brine, 2 bpm ICP 370 psi reduced rate last 3 bbls to 1 bpm, FCP 749 psi. Bump plug (1405 psi) with 46.4 bbls actual / 46.7 bbls calculated. Held pressure for 5 minutes, check floats - good. CIP @ 21:43 hrs. Full returns throughout job. MIT 3.5" tubing to 1,500 psi for 30 min on chart, good. Cont to Press up to 4,112 psi to shear rupture disk in Defender. Had to cycle pumps to get rupture disk fully sheared. Displaced 9.5 ppd mud to 9.5 ppg corrosion inhibited brine. Saw spacer at surface and about 10 bbls of cement. Blow down all lines. R/D IA. L/D cement head. Switch to completion AFE at 00:00.” Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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. 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WELL COMPLETION OR RECOMPLETION REPORT AND LOG Prudhoe Bay Field / Schrader Bluff Oil Pool, Orion Dev Area By Meredith Guhl at 3:27 pm, May 03, 2022 G Completed 4/21/2022 MDG RBDMS 5/3/2022 MDG MGR30AUG2022 DSR-5/4/22SFD 8/11/2022 5.3.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.05.03 12:38:29 -08'00' Monty M Myers CASING AND LEAK-OFF FRACTURE TESTS Well Name:PBU V-213A Date:2/14/2022 Csg Size/Wt/Grade:7", 26#, L-80 Supervisor:Lott Csg Setting Depth:3442 TMD 2692 TVD Mud Weight:9.5 ppg LOT / FIT Press = psi LOT / FIT =9.50 ppg Hole Depth =3527 md Fluid Pumped=0.7 Bbls Volume Back =0.2 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->012 ->00 ->153 -> ->290 -> ->3 112 -> ->4 146 -> ->5 176 -> ->6 199 -> ->7 216 -> ->8 229 -> ->9 238 -> ->10 242 -> ->11 246 -> ->12 -> ->13 -> Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 246 ->0 ->1 124 -> ->2 108 -> ->396 -> ->490 -> ->584 -> ->679 -> ->776 -> ->873 -> ->969 -> ->10 66 -> -> -> -> -> -> -> 10.9 ppg NOTE: Hilcorp approved to utilize parent surface casing LOT of 13.4 ppg EMW, as sidetrack is open to Ugnu sands. Note email 20220214 1003 Approval 200 0 1 2 3 4 5 6 7 8 9 10 11 00 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 01020Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 246 12410896 90 84 79 76 73 69 66 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 2/9/2022 R/D U-Tube Manifold and all 1502 components. Grease all plug valves and mud manifold and around Rig. Respool both Tuggers. Bridle up and Scope down Derrick. Remove 1502 Companion flanges from Wellhead and install blank Flanges. Prep Possum Belly Dump Line for Repair. C/O Valve/Seat MP #2 pod 3 and 4 C/O Wear plate gasket on MP #2. C/O Pulsation Dampener Gauges on MP #1. Perform Monthly EAM on both Pumps. Clean Magnetic filters, check TQ on fluid ends, check lube pump coupler, clean rod wash and oil suction strainers. Finish cleaning mud pits. WOW (Temp below -35°F) and V-213A pad prep to be completed before calling trucks for Rig Move to V Pad. C/O choke manifold valve #15. Fix Mouse hole bushing. Check/Air up tires on all Mods. Welder cut out old Possum Belly Dump Line and install new Flange. Re assemble Mud Pumps. Clean and clear Rig Floor of unneeded handling subs/XO’s. Clean up ears on all 1502 components. Work on rig inspections/hitchly paperwork. Clean/secure cellar and pipeshed for rig move. Perform monthly EAM on catwalk hydraulics and C/O filters. perform monthly EAM on test pump. Set rig mats and lay herculite on V-213A. B/D water system. prep pits for welding projects Prep and secure shop for rig move. Redress VBR's. Remove cuttings tank. C/O bearing on drag chain. Disconnect all pit mezzanine interconnect lines. Flip up roof caps and install stair wrench's. WOW (Temp below -35°F). Change out bearings on drag chain. Set rig mats over buried cable on pad. Remove ice from pipe-shed floor. Replace bolt on pipe lift column. Check torque on lift column bolt. Blow down steam lines. Unplug and move break shack and envirovac. R/D interconnects. Swap to cold start at 04:00. Turn stompers to walk off well. Jack up Gen mod and install jeep. Jack up pipeshed. NES on location at 05:00. Pull Gen mod and mud mod and stage on pad. 2/10/2022 Unhitch truck from Pipe Shed, cover with hooch and heat tires. Jack up catwalk hitch truck and pull away from Sub, cover with hooch and heat tires. Remove both Geo spans from lower utilidor and install 2 new ones. At 10:00 Convoy Gen Mod and Mud Mod to V-Pad. Remove out riggers, raise DS Stairs. Stomp Sub off Z- 220. Turn Stompers and Rotate Sub and install front steering arm on Sub. Install rear sub tires and remove steering arms. Hook up sow to sub base and line up convoy with pipe shed, cattle chute and sub. At 15:30 Convoy Pipe Shed, Cat Walk and Sub to V-Pad. Set cattle chute and pipeshed to side of pad. Drop mods and hooch/warm tires. Stage gen mod and mud mod to edge of pad. Set rig mats. Stage sub base. Remove front steering arms. Walk sub forward to install rear steering arms. Remove rear tires off sub. Cont. removing rear tires. Turn sub 90° and walk back over V-213A. Spot, shim and set sub base. Drive and re-stage mud mod back to unhook truck. Hook truck to cattle chute and begin spotting. 2/11/2022 Spot Catwalk into position and set down. Set outriggers on Sub. Turn and retract stompers, install covers. Verify stairs and cattle chute line up properly. Spot and set down pipe shed. Spot and set down Mud Mod. Verify hose and flow line alignment and scope out Interconnect. Spot Gen Mod, remove Jeep and set down Gen Mod. Release NES Trucks at 10:00 to move Satellite Camp and Shop f/ Z pad to V pad. Assist NES welder with possum belly repair. Hook up interconnects and take on Fuel. Assist Electrician plugging in Rig. Rig on Gen Power @ 12:00. Bring on Steam System to Rig. Move Satellite Camp and shop to V-Pad. Continue to safe out walkways and landings. Work on Rig Acceptance Check List. Prep and Scope Derrick. Unplug upper derrick section. Verify outriggers in place and check stompers pressure. Scope up derrick. Bridle down. Assist NES welder installing new hinges on centrifuge dump hatches, weld crack on shaker #2. Lay herculite and spot cuttings box. spot break shack and enivorvac. Perform post rig move derrick inspection. Function test all mud pit equipment, pipe shed equipment. Load up herculite from Z-pad and bring to shop. Bring XT-39 crossover, TIW, Dart valve to rig floor. Install companion flange on IA. Get 1502 components and hoses ready for circulating out freeze protect. Bring pipe handling equipment to rig floor. Take on 290 bbls seawater and build soap pill. Function test mud pumps. Rig accepted at 23:30 R/U circulation hoses. iniital SITP 50 pis, ISICP 80 psi. Bleed pressure. Shut in and monitor. SITP= 0, SICP 35 psi. Tubing on vac - underbalanced. Pre-RWO meeting with rig crew. Verify rig up and line up. Circulate out freeze protect down tubing out IA. Pump 50 bbls hot soap pill followed by 170 bbls 8.5 ppg seawater. ICP 230 psi at 1 bpm, FCP 695 psi at 2.5 bpm, observe erratic pressures up to 1250 psi. Shut down and monitor well. Tubing on vac, IA slight flow. 8.0 ppg coming out IA. Pump remaining 36 bbls seawater 2.5 bpm 695 psi. Monitor well, still underbalanced tubing vac, IA slight flow. Cont. to monitor until balanced - static. Blow down and rig down circulating hoses/1502 components. Install BPV. Install tree cap. Begin breaking studs on tree. 2/12/2022 Finish braking studs on Tree. Remove Tree and set aside. Install CTS Plug and PT to 4000 psi f/5 min. Inspect lift threads on Tbg Hgr with XO (8.5 turns) Check LDS, clean and fill Void/Hanger with oil. Istall DSA to Wellhead. Hook up bridge crane and remove cross chains from stack. Land Stck on DSA. Install cross chains, remove bridge cranes. N/U Choke/Kill lines, hole fill line and 1502 components. Install KOOMEY lines and energize system. Install drip pan and hoses. N/U 4" line to Beyond Orbit valve and all lines to Beyond Choke. Obtain RKB's: GL 26.71', LLDS 24.90', ULDS 22.89', LPR 20.72', Annular 13.40'. SIMOPS: Load and process 4" DP. C/O Saver Sub, Dies and Bell Guide to 4" XT-39. Grease Choke manifold and Manuals/HCR's on Stack. P/U 4.5” and 3.5” Doughnut Test Jts. Mark same with Annular, UPR, LPR positions and lay back down. Pull Bushings and remove Bowl Saver. Install MPD Test Cap and Tighten Clamp. Clean and clear rig floor. Send old saver sub and changing stand off rig floor. Send down 4.5" IF TIWand dart valves. Clean up and ut away 5" die blocks and bell guide. Adjust top drive back up wrench height. M/U XT-39 test sub to top drive. Flood stack and beyond lines. Cycle chokes. Close choke and PT beyond hardline 250/1250 - good. Bleed off and blow down lines. Break RCD clamp and remove test cap. Install riser, center stack. Tighten RCD clamp and inflate airboot. M/U test joint. Flood lines, purge air. Test BOPE's 250/3000 psi, AOGCC right to witness waived by Guy Cook. Check gas alarms, PVT sensors. F/P UPR's - function and retest. F on choke manifold #4. Cont testing, replace choke manifold valve 4 after drawdown and re-test - good. Accumulator drawdown: starting pressure 3000 psi, final 1500 psi, first 200 psi recharge 28 sec, Final 98 secs. 6 (N2) at 2325 psi average. Sim Ops while changing out/testing choke manifold 4: Rig down testing equipment, L/D test joint. Clean and clear rig floor. Break out test sub from top drive. Bring Weatherford power tongs and pipe handling equipment to rig floor. C/O elevators. Bring wear bushing to rig floor. Pull CTS plug and BPV. Observe fluid level drop in tubing. M/U landing joint to hanger. BOLDS. P/U hanger to floor, free at 102K, PUW 66K. Break out and L/D hanger and landing joint. Rig up to circulate. M/U XO and head pin. Circulate 50 bbls heated soap pill followed by fresh water staging pumps up to 7 bpm, 230 psi. Observe 34 bbls diesel returns at beginning of circulation. Monitor well, static. R/D circulating equipment. Daily Disposal to G&I = 0 bbls, total = 177 bbls. Daily H2O from Lake 2 = 280 bbls. Total H2O from Lake 2 = 890 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Spud Date: 2/14/2022 Well Name: Field: County/State: PBW V-213A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 50-029-23213-01-00API #: 2/13/2022 POOH laying down 4.5" TCII tubing from 3690', (87 joints, XN landing nipple, 1 cut joint) Calculated hole fill. Clean and clear rig floor. Rig down Weatherford tubing equipment. Mobilize BHA components to rig floor. Install wear ring. M/U Casing scraper BHA. Junk mill, 7" casing scraper, bit sub, watermelon mill, oil jar and XO as per Baker. Pick up, drift (2.3") and single in hole with casing scraper assembly to 655'. Calc displacement. Service rig: grease crown, top drive, drawworks, wash pipe, IBOP, iron roughneck, cobra heads. Pick up, drift (2.3") and single in hole with casing scraper assembly from 655' to top of stub at 3690', tag top of stub with 5K. Calc displacement. Calculated displacement observed. P/U 75K, S/O 65K Displace to 9.5 ppg milling fluid at 330 gpm, 665 psi. Monitor well, static. Pump dry job. POOH to 29'. Calculated hole fill observed. Pick up, drift (2.3"), and single in hole with remaining drill pipe in shed to 3,054'. P/U 70K, S/O 55K. Calculated hole fill observed. Circulate surface to surface at 330 gpm, 600 psi. Monitor well, static. pump dry job. POOH racking back drill pipe to surface. L/D BHA. Clean and clear rig floor. Service rig: grease and inspect crown sheaves. Grease blocks. Check top drive gear oil. Inspect carriage frame. Spot in E-Line. R/U E-line. Install sheave in elevators. M/U CCL and CIBP. RIH with CIBP. Tag top of stump lightly at 3690' and correlate. Locate collar at 3516'. Set CIBP at 3611', good indication of set. POOH and R/D E-Line M/U Whipstock assembly. M/U TM, DM, Float sub and XO. L/D to pipe shed. P/U Joint of HWDP and M/U milling assembly and scribe line. M/U whipstock with 35K shear bolt and anchor (14K shear on anchor). Scribe line and measure RFO = 4.57/4.67 = 352.29°. Daily Disposal to G&I = 0 bbls, total = 177 bbls. Daily H2O from Lake 2 = 140 bbls. Total H2O from Lake 2 = 1030 bbls. Daily Metal: 0 lb. Total Metal 0 lb. OA pressure 50 psi. 2/14/2022 Continue to M/U Whipstock BHA and 10 jts 4" HWDP. TIH to 375'. Shallow pulse Test MWD tools on 1st Jt of HWDP, 200 GPM, 375 PSI. Test Good. B/D Top Drive and Choke Lines. TIH with Whipstock Milling Assy on 4" DP from Derrick to 3463' MD @ 30-40 fpm. PU 73K , SO 64K. PU working single, fill pipe and orient tool face to 32º ROHS. Shut down pumps and RIH to 3509' and tag top of CIBP. Set Whipstock as per Baker Rep, observe bottom trip anchor shear @ 14K down and shear Whipstock bolt at 35K down. Parameters, 300 GPM, 1110 PSI, RPM 80, Tq 4K, PU 73K, SO 64K, Rot 68K Mill Window (TOW 3491', BOW 3504') erratic TQ/multiple stall starting window. 300 GPM, 1150 PSI, rpm 60-80, TQ 3-7K, WOB 2K. P/U 78K, S/O 65K, ROT 69K. Drill 20' of new hole to 3524'. Work through window multiple times. Shut down pumps/rotary. Trip through window with 2-3K drag down a 3-5K drag up Pump 30 bbls high vis sweep (no increase in cuttings) and circulate hole clean at 300 gpm/1150 psi even MW in/out. Rig up to perform FIT, flood and purge lines. Shut UPR's. Pump down IA and drill pipe. Attempt to perform FIT to 308 psi (11.7 ppg), pressured up to 246 psi, shut down as the well started taking fluid. 0.8bbls pumped 0.2 bbls bled back. Circulated hole. Discuss options with town, AOGCC approves to drill ahead using original LOT of 13.4 ppg from parent well due to: the Ugnu being open, clean, and permeable in this location in the uncemented 7” annulus and an original PB1 of v-213 at 3571’ MD. Any of which could impact the FIT and take fluid. Monitor well, static. Pump 15 bbls dry job. Finish rigging down circ. hoses/testing equipment. L/D working single. Simulate kick while drilling drill. Kelly up and call drill. Space-out. Monitor well. All hands respond accordingly. Hold after action review with rig crews. Discuss kick indicators, importance of early detection and why, well control equipment, types of barriers, sequence of well shut in. install stripping rubber and air slips. Cont POOH on elevators from 3432' to surface. L/D BHA starter mill 3/8" under-gauge, second mill 1/16" under-gauge, top mill in gauge. Clean and clear rig floor. Pull wear bushing. M/U Johnny Whacker and flush out BOPE stack. L/D Johnny whacker. Blow down top drive. Install wear ring. Bring BHA components to rig floor. M/U BHA. M/U NOV PDC bit to mud motor (1.5° bend), DM collar. Measure RFO = 0.01/4.8 = 0.75°. M/U GM collar, ILS, ADR, ILS, PWD, TM and float sub. Plug in and upload MWD. Daily Disposal to G&I = 57 bbls, total = 234 bbls. Daily H2O from Lake 2 = 110 bbls. Total H2O from Lake 2 = 1140 bbls. Daily Metal: 40 lb. Total Metal 40 lb. Daily DH losses 30 bbls, Total 30 bbls. OA pressure 200 psi. 2/15/2022 Cont. to M/U BHA. Finish upload MWD. P/U flex collars x 2, float sub and HWDP/jars to 515'. RIH with drilling BHA from 515' to 2090'. Fill pipe and shallow pulse test at 2090'. PUW 67K, SOW 60K Simulate kick while drilling drill. Kelly up and space out. Perform flow check and announce drill. All hands respond accordingly. AAR and discuss drill, kick indicators, importance of early detection, well control equipment and barriers. Cont. to RIH from 2090' to 3470', PUW 76K, SOW 64K. Cut and slip 82' of drilling line. Perform sheave wobble EAM. Pull trip nipple, install MPD bearing. Fill pipe, obtain parameters. Cont. to RIH from 3478' to 3524', no pumps or rotary. 2-4K drag going through window. Drill 6-1/8" hole from 3,524' to 3,789 (total 265', AROP 66fph) at 250 gpm, 1600 psi, WOB 1-3K, 40 rpms, 4Kft-lbs. Max gas 331U, ECD 10.78 ppg EMW with 9.5 ppg mud. PUW 82K, SOW 62K, ROTW 70K. Drill 6-1/8" hole from 3,789' to 4,297 (total 508', AROP 85fph) at 250 gpm, 1620 psi, WOB 1-3K, 80 rpms, 5Kft-lbs. Max gas 679U, ECD 10.82 ppg EMW with 9.5 ppg mud. PUW 101K, SOW 56K, ROTW 68K. Backream full stands. First clean survey at 3819'. Drill 6-1/8" hole from 4,297' to 4,887 (total 590', AROP 98fph) at 250 gpm, 1660 psi, WOB 3-8K, 80 rpms, 6Kft- lbs. Max gas 180U, ECD 10.9 ppg EMW with 9.5 ppg mud. PUW 113K, SOW 60K, ROTW 74K. Backream full stands. Distance to WP1: 3.4', 2.72' Low, 2.03' Right Daily Disposal to G&I = 114 bbls, total = 348 bbls. Daily H2O from Lake 2 = 145 bbls total = 1285 bbls. Daily Metal: 43 lb. Total Metal 83 lb. Daily DH losses 7 bbls, Total 37 bbls. OA pressure 75 psi. 2/16/2022 Drill 6-1/8" hole from 4,887' to 5,241 (total 354', AROP 59 fph) at 250 gpm, 2055 psi, WOB 3-10K, 80 rpms, 6Kft-lbs. Max gas 216U, ECD 11.04 ppg EMW with 9.5 ppg mud. PUW 116K, SOW 64K, ROTW 78K. Back ream full stands. Drill 6-1/8" hole from 5,241' to 5,615 (total 374', AROP 62.4 fph) at 250 gpm, 2150 psi, WOB 4-8K, 80 rpms, 9Kft-lbs. Max gas 468U, ECD 11.12 ppg EMW with 9.5 ppg mud. PUW 125K, SOW 63K, ROTW 82K. Back ream full stands. Cont Drill 6 1/8" Hole F/ 5,615' to 5,747' MD (4,287' TVD) Total 132’ (AROP 22’) 250 GPM/ MPD 225, 2,150 psi, 60-115 RPM, TRQ on 7k, TRQ off 6-8k, WOB 4-8k. ECD 10.82 MW 9.5. Max Gas 82u. P/U 125k, SLK 63k, ROT 82k. MPD 100% open. Back ream 60'. At 5,556' MD in Ugnu MB adjusting parameters to increase ROP. At 5,689' MD pump 40 bbl bit balling pill ( 1 ppb NutPlug & 3% DrilSlide) W/ no increase in ROP. Back on time. Cont Drill 6 1/8" Hole F/ 5,747' to 5,845' MD (4,364' TVD) Total 98’ (AROP 16.3’) 250 GPM/ MPD 246, 2,020 psi, 80 RPM, TRQ on 7k, TRQ off 6-8k, WOB 4-8k. ECD 11.0 MW 9.45 Max Gas 84u. P/U 130k, SLK 64k, ROT 84k. MPD 100% open. Back ream 60'. Cont adjusting parameters due to slow ROP. Distance to WP01: 2.57', 1.79' High, 1.85' Left Daily Disposal to G&I = 528 bbls, total = 876 bbls. Daily H2O from Lake 2 = 390 bbls total = 1675 bbls. Daily Metal: 45 lb. Total Metal 128 lb. Daily DH losses 0 bbls, Total 37 bbls. OA pressure 250 psi. w (TOW 3491', BOW 3504') AOGCC approves to drill ahead using original LOT of 13.4 ppg from parent well due to: the Ugnu being open, clean, and permeable in this location in t 2/17/2022 Cont Drill 6 1/8" Hole F/ 5,845' to 5,886' MD (4,391' TVD) Total 41’ (AROP 12’) 250 GPM/ MPD 246, 2,100 psi, 80 RPM, TRQ on 7.5k, TRQ off 6-8k, WOB 4-10k. ECD 11.0 MW 9.45 Max Gas 118u. P/U 136k, SLK 63k, ROT 86k. MPD 100% open. Back ream 60'. fighting for ROP. ~10-20 fph intermittent. Decision made to Pull 400’ wiper trip BROOH from 5886’ to 5495’. GPM 250, PSI 1885, RPM 60, TQ 7-8, ECD 11.1. No issues back reaming. Rotate/Reciprocate f/5495 to 5425', circ tandem 40 bbl sweeps follow with 30 bbls walnut sweep. All sweeps back on time w/10% increase at shakers. Wash and Ream F/ 5,425' to 5,886' MD GPM 250, PSI 1875, RPM 60, TQ 5-7, ECD 11.0. No issues. Bled down OA F/ 850 psi to 200 psi. Drill ahead from 5886’ to 5935’, immediately see 50 to 100 fast ROP slowing to ~8-10 ROP in ~50’. Adjust WOB and RPM’s with no change. Decision made to trip for Bit. Monitor well 10 min, static. BROOH from 5935' to 4,775' MD 250 gpm/ MPD 244, 1,730 psi 60 rpm Trq 6-7k, ECD 10.7 W/ MW 9.5 Max Gas 18u. P/U 130k SLK 60k ROT 84k Pull speed 30-50 ft/min. Cont BROOH F/ 4,775' to 3,919' MD CBU F/ 4,045' to 3,919' MD same parameters. Attempt to pull on elevators seeing swabbing. Kelly up and pump out observed pack off at 3,887' MD. RIH to 3,900' MD and back reamed to 3,793' MD. Pumped out F/ 3,793' ro 3,540' MD 2 bpm 490 psi due to swabbing. Pulled through window (TOW 3,491' BOW 3,504' MD) without pumps, no drag observed to 3,462' MD. At 3,462' MD Rot & Rec Pump 25 bbl 102 Vis sweep Surf to Surf 250 gpm/ MPD 245 1,580 psi 30 rpm Trq 2-4k Max Gas 76u. Sweep back on time no increase. Blow down top drive. Monitor well at possum belly 10 min, static. Shut in MPD for 10 min zero Press build. PJSM Drain stack. Break grey loc clamp and stand back RCD Bearing as per Beyond rep onsite to 3,399' MD. Install trip nipple and close clamp. While installing trip nipple observed fluid rising in stack and gas breaking out of drilling fluid. Decision was made to shut in well at 20:34 W/ Annular. Monitor SICP initial pressure 26 psi increasing to 252 psi after 28 min Cont to climb. ( 3 Floats holding) Installed TIW & R/U pump in sub and HP hose to mud manifold. Line up choke manifold to Gas Buster. Began Circ at 3 bpm 830 psi holding 150-160 back Press W/ Super Choke. Taking Wt's W/ non and Press scales. Check non Press scale prior to BU at 8.8 ppg and pressurized scale 9.45 ppg. Circ 2X surface to surface volume till none press scale 9.45 ppg. No losses observed. Max Gas 95u. Shut down at 12:03 and allow press to go zero psi. Shut in choke at 12:05. Monitor for 20 min zero Press build. R/D TIW and HP line. Kelly up. Open choke and Annular. Monitor well 10 min static. Monitored OA zero press. Rot & Rec 3,399' to 3,348' MD CBU Initial 3 bpm 630 psi final 4 bpm 845 psi 10 rpm Trq 4k. Max Gas 18u. F/O 22%. No visual sign of gas breaking out. Monitor well 10 min, staic. PJSM Attempted to pull on elevators and Cont seeing swabbing. Pump out at 2 bpm 345 psi F/ 3,348' to 1,398' MD Lost 5 bbls. Drill string not swabbing. POOH on elevators to verify F/ 1,398' to 1,209' MD. Pump 10 bbl 10.4 ppg dry job. Blow down top drive, choke and kill lines. Distance to WP01: 6.42', 5.47' High, 3.36' Left Daily Disposal to G&I = 228 bbls, total = 1104 bbls. Daily H2O from Lake 2 = 100 bbls total = 1775 bbls. Daily Metal: 0 lb. Total Metal 128 lb. Daily DH losses 0 bbls, Total 37 bbls. OA pressure 0 psi. 2/18/2022 Cont POOH on elevators F/ 1,209' to 515' MD P/U 46k SLK 45k. PJSM L/D BHA. Rack back 4" 27.7# XT39 HWDP, 4.5" SLB Jars, 4 3/4" NM FC, FS. Read MWD tools. Remove pulsar and send out TM. L/D PWD, ADR, GM & DM. Break off Bit & L/D 4 3/4" 1.5° Mud Motor. Bit Grade 3-7-BT-T-X-I-RO-PR. No signs of bit balling. PJSM Clean & clear rig floor. Drain stack BOLDS & pull wear ring. P/U M/U X/O, pump in sub & 4" TIW XT39 to 3.5" test jnt. Install test plug. Flood stack, choke manifold and kill line. Purge air F/ system and shell test to 3,000 psi, good. BOPE Test. Test W/ 3.5" test jnt 250/3,000 psi 5 min on chart. Annular, HCR Choke, HCR Kill, TIW, & Super Choke. Witnessed waived by AOGCC Rep Matt Herrera. Pull test plug & install wear ring. R/D test tools & Equip. Blow down surface Equip. PJSM P/U M/U BHA #4. P/U M/U 4 3/4" 1.5° StrataForce & 6.125" SKF513D PDC Bit (5X10 TFA 0.3835) , 4 3/4" DM, 4 3/4" GM, 4 3/4" ILS (5 7/8" OD) 4 3/4" ADR, 4 3/4" ILS (5 7/8" OD), 4 3/4" PWD, 4 3/4" TM, 4 3/4" NM FS (non port, plunger) 4 3/4" NM FC,4 3/4" NM FS (non port, plunger)4 3/4" NM FC, X/O 3.5" IF P X XT39 B, 6 ea 4" HWDP, X/O XT39 P X 3.5" IF B, 4 3/4" SLB Jar, X/O 3.5" IF P X XT39 B & 4 ea 4" HWDP. Total 515.93'. C/O pulsar to increase flow to 300 gpm. RIH W/ 4" 14# S-135 XT39 D.P. F/ 515' to 3,415' MD Perform shallow hole test 260 gpm 1465 psi at 2,500' MD, good. Circulate out Hydrate Gas. Blow down. P/U 93k SLK 59k. CBU slowly working pipe 250 gpm 1,500 psi 30 rpm Trq 3-4k Max Gas 36u. At BU observed gas breaking out at surface, circ 1.5 BU total till gone. Monitor well 10 min, static. PJSM Drain stack. Pull trip nipple and RIH stand W/ RCD Bearing as per Beyond rep onsite. Close and tighten grey clamp. (3,478' MD) Circ through MPD Equip & check for leaks, good. Orientate Mud Motor 30° R through window, no issue. RIH F/ 3,478' to 5,873' MD. Wash and ream F/ 5,873' to5,935' MD no fill. 250 gpm 1,800 psi 30 rpm Trq 7-8k. Rot & Slide 6 1/8" Hole F/ 5,935' to 6,059' MD (4,514' TVD) Total 124’ (AROP 41.3’) 275 GPM/ MPD 272, 2,375 psi, 30 RPM, TRQ on 7-8k, TRQ off 7-8k, WOB 3-8k. ECD 11.0 MW 9.5 Max Gas 229u. P/U 139k, SLK 66k, ROT 87k. MPD 100% open. Back ream 60'. Rot & Slide 6 1/8" Hole F/ 6,059' to 6,413' MD (4,764' TVD) Total 354’ (AROP 59’) 220 GPM/ MPD 221, 1,785 psi, 30 RPM, TRQ on 8-9k, TRQ off 8-9k, WOB 3-8k. ECD 10.8 MW 9.5 Max Gas 56u. P/U 148k, SLK 66k, ROT 91k. MPD 100% open. Back ream 60'. At 6,166’ MD encountered 84% loss in returns 275 gpm 2,590 psi W/ 11.03 ECD. Picked up off bottom and reduced flow F/ 275 to 170 gpm 1,080 psi. Well took ~24 bbls and breathed back 5 bbls, lost ~19 bbls. Was able to establish 100% in returns. Increased flow to 220 gpm 1,680 psi (250 AV) and cont drilling ahead. Distance to WP01: 5.69', 5.41' High, 1.77' Left. Daily Disposal to G&I = 57 bbls, total = 1,161 bbls. Daily H2O from Lake 2 = 90 bbls total = 1865 bbls. Daily Metal: 12 lb. Total Metal 140 lb. Daily DH losses 12 bbls, Total 49 bbls. OA pressure 250 psi. 2/19/2022 Rot & Slide 6 1/8" Hole F/ 6,413' to 6,601' MD (4,910' TVD) Total 188’ (AROP 41.8’) 220 GPM/ MPD 219, 1,920 psi, 30-60 RPM, TRQ on 8-9k, TRQ off 8-9k, WOB 4-7k. ECD 10.8 MW 9.5 Max Gas 136u. P/U 150k, SLK 65k, ROT 93k. MPD 100% open. Back ream 60'. Obtain final Survey at 6,601' MD 4910.25' TVD 41.68° Inc 52.30° Azi. Obtain SPR's Rot & Rec at 6,601' MD Pump 34 bbls 8,9 ppg 23 Vis & 36 bbls 10,0 ppg 43 Vis sweeps. Back 12 bbls late W/ 20% increase at shakers. Circ total 3.5 BU. 250 gpm/ mpd 246, 1,915 psi 60 rpm Trq 8-9k ECD 10.8 W/ 9.5 MW Max Gas 171u. Discuss with town to drill TD to 6,675' MD. Drill 6 1/8" Hole F/ 6,601' to TD 6,675' MD (4,966' TVD) Total 74’ (AROP 49.4’) 250 GPM/ MPD 245, 2,060 psi, 60 RPM, TRQ on 8-9k, TRQ off 8-9k, WOB 3-8k. ECD 10.9 MW 9.5 Max Gas 154u. P/U 156k, SLK 66k, ROT 93k. MPD 100% open. Obtain final Survey at 6,675' MD 4965.47' TVD 41.75° Inc 51.09° Azi. Obtain SPR's Rot & Rec F/ 6,675' to 6,625' MD CBU. 250 gpm/ mpd 245, 1,970 psi 60 rpm Trq 8-9k ECD 10.9 W/ 9.5 MW Max Gas 83u. BROOH F/ 6,675' to 3,541' MD 250 gpm/ mpd 244 1,580 psi 40-60 rpm Trq 5-6k Max Gas 10.8 ECD 10.8 W/ 9.5 MW. P/U 102k SLK 56k ROT 75k. Pull speed 20-60 ft/min. Slowed to 40 rpm prior to BHA entering window. Perform 2X BU 2 F/ 3,667' to 3,541' MD. Orientate Mud Motor 30° R prior to window. Pull on elevators F/ 3,541' to 3,475' MD (TOW 3,491. BPW 3,504') No issue. Lost 16 bbls BROOH. At 3,450’ MD after pulling through window monitored well for 10 min, very slight flow at possum belly. Came on with the pumps 250 gpm 1,608 psi and saw Gas Hydrates at surface after 200 stks into pumping. Cont circulate out Gas Hydrates increasing to 687u max gas at BU with no pit gain. . Cont Circ till gas fell to 24u. Circ a total of 2 BU. Pump 25 bbls 9.5 ppg 100 Vis sweep Surf to Surf. Back on time W/ 10% increase at shakers. Monitor well 10 min, static. Shut in MPD for 10 min, no press build. Blow down top drive. Drain stack, remove bowl saver, grey clam and pull RCD Bearing to rig floor. Strip off RCD Bearing. Close Annular to monitor well (21:18) while installing Trip nipple. Install trip nipple, close, tighten clamp and air boot. At 21:45 well press built to 42 psi. Bled press and opened Annular. Fluid was down by well head. Rot & Rec Circ at 250 gpm 1,480 psi 10 rpm Trq 3.7k F/O 30% saw 880u of Gas Hydrates at BU falling back to 30u. No gain seen. Circ total 2.5 BU. Monitor well 10 min, static. Decision was made to pump out of hole and rack back D.P. Pump out of hole F/ 3,450' to 1,390' MD 2.5 bpm 440 psi Pull speed 60 ft/min. P/U 73k SLK 60k. POOH on Elevators F/ 1,390' to 510' MD at 60 ft/min. Observed 1 bbl gain on pipe displacement. Monitor well for 20 min seeing surface gas breaking out gained 7.5 bbls. Shut in well at 02:58 initial SICP 20 psi at 03:07 SICP 74 psi, bleed off to 20 psi built back up to 41 psi at 03:12. Built up to 198 psi at 03:25 while R/U TIW, head pin & HP hoses. Circ through choke and poor boy to circ out gas cap, staging up to 3.5 bpm 605 psi Max gas 503u. Shut down and shut in at 04:09 SICP 241 psi bleed down pressure and open well. Seeing gas break out at surface RIH 1 stand of 4” D.P. Saw significant pit gain and shut in well at 04:16 SICP 261 psi and rising to max 580 psi. Attempt to Circ W/ top drive, unable too. Bleeding off surface Press as needed. R/U TIW, head pin and HP hoses. Gained a total of 49 bbls in 1.5 hrs including bleeding off surface pressure due to 9.625” FIT 490 psi. Circulating through choke and poor boy 2 bpm 560-600 psi holding ~315 psi choke 63% staging up to 3 bpm 756 psi Max Gas 1,291u. Prep for striping in hole operations. Saw about 4 bbls gained in last 30 min. Cont Circ at 3 bpm 695 psi Choke at 37% holding ~290 psi. L-109 injector was brought on yesterday, talked to operator to shut down L-109 at 05:00. OA Press 75 psi. Distance to WP01: 10.46', 8.77' Low, 5.71' Right. Daily Disposal to G&I = 171 bbls, total = 1,332 bbls. Daily H2O from Lake 2 = 445 bbls total = 2310 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 35 bbls, Total 64 bbls. OA pressure 75 psi. Bleeding off surface Press as needed. R/U TIW, head pin and HP hoses. Gained a total of 49 bbls in 1.5 hrs including bleeding off surface pressure due to 9.625” FIT 490 psi. C Shut in well at 02:58 initial SICP 20 psi at 03:07 SICP 74 psi, bleed off to 20 psi built back up to 41 psi at 03:12. Built up to 198 psi at 03:25 while R/U TIW, head pin & HP hoses. Saw significant pit gain and shut in well at 04:16 SICP 261 psi and rising to max 580 psi. 510' MD at 60 ft/min. Observed Decision was made to shut in well at 20:34 W/ Annular. Monitor SICP initial pressure 26 psi increasing to 252 psi after 28 min Cont to climb. F/ 6,601' to TD 6,675' MD 2/20/2022 Prep for Striping in hole operations. Shut in TIW, R/D head pin and circ hose. Suck out stack to top of Bag and pour lube oil on top of Bag. M/U Dart Valve and Strip in hole on Top Drive w/15 stands to 1,524'. ISICP 450 PSI, FSICP 300 psi. Venting Gas but no returns to TT. R/U Circ Hose, TIW and Head pin. Stage pump to 3.5 BPM 900 PSI and circ Surface to Surface x2, initial Gas -678u, final gas 278u., Bleed off and shut in choke, Casing pressure build to 78 psi. Lost 84 bbls during circulation. Continue to Strip in hole on elevators from 1'524 to 3,474'. (TOW). Bleed off .70 to 1 bbl per stand through choke, maintain 120-140 Casing pressure. Calc: 32.1 bbls, Actual: 24.4 bbls PUW 75K, SOW 50K Continue to Circulate STS through choke @ 3 BPM, 860 PSI, holding 180-200 psi Casing Pressure. Max Gas 729u start of 1st circulation falling to 106 psi . Pumped 5 x bottoms up. Shut down, shut in and monitor well. CICP from 0 to 108 and stabilized. Total losses on circulation - 14 bbls. Prep to Strip through TOW @ 3491' and in to open hole. Strip from 3475' and set down @ 3492' (1' inside TOW) multiple attempts to Strip through window set 5-15K down, checking TF orientation several times. No success. Discuss options with DD. Bring on pump at 1-2 bpm, 550-780 psi, inch down slowing working down to 3505' (1' below BOW) Shut down pump and Strip up through Window, see 10k drag, Strip back down through window no pump to 3507' (3' below BOW) with no drag. Pulled back above window to weight Mud System. No drag pulling above window. Max gas while pumping 715u. PU 80-95K, SO 56K. Bleed OA down from 650psi to 200 psi to bleed trailer. Mostly fluid. Weight up to 9.8 ppg in/out. Shut down, shut in choke W/ 13 psi csg Press for 15 min, built F/ 13 to 71 psi. Did not hold shut in longer due to standpipe may freeze. CBU holding 100-119 psi back pressure W/ choke (46-50%) 4 bpm 1,164 psi. Observed gas at surface 190 stks into pumping F/ 34u BGG to 260u, max gas at BU 648u dropping to BGG 120u. No losses. Call out Beyond and start rigging up MPD Equip. Found MWD tool without detection. Brought pump rate up F/ 4 bpm (168 gpm) to 5 bpm (210 gpm) 1,468 psi showing multiple error codes. Tried cycling pumps 5 bpm (210 gpm) 1,468 for mode change W/ choke set at 51% and was unable to get it working. Csg press falling to 13-18 psi in between pumps on and off. CBU 4 bpm 1160 psi holding 110-120 back press, max gas 160u dropping to 120 units. Attempted cycling pumps again without success. OA reading 350-400 psi. Beyond MPD Equip rigged up. Shut in well at 22:30 W/ 147 psi Csg Press. Rack back 1 stand of 4” D.P. Blow down top drive. Line up on Beyond hard lines, flood lines and check for leaks. Test MPD hard lines 250/ 1200 psi, good. 23:20 Kelly up, break Circ 4 bpm 1,120 psi W/ 120 psi back Press for a BU. Initial shut in Press 147 psi and built to 158 psi in 50 min. At 230 stks into pumping seeing gas increase at surface 239u dropping to 180u at 686 stks into pumping. (BU 1,240) Pull up another stand to 3,412' MD. BGG at ~73u. PJSM Circ at 4 bpm 1,120 psi holding 125 psi casing pressure choke at 51% 40u BGG. Slack down 1 joint F/ 3,412’ to 3,442’ MD. Shut down pump holding 169 psi on choke. Set slips break connection, blow down top drive. Pull trip nipple and install RCD Bearing on 4” Jnt as per Beyond rep onsite. Set bow Set bowl saver and RCD Bearing. Install grey clamp and Trq. Open orbital valve and flood MPD lines W/ rig pump. Attempt to pre charge MPD system to 150 psi prior to opening Annular. Trouble shoot MPD chokes. Line back up on well while trouble shooting MPD. Initial shut-in pressure at at 12:49 169 psi and prior to pumping at 02:48 was 138 psi. Break circ staging up to 3.25 bpm (136 gpm) 905 psi holding 140-150 psi back pressure W/ choke at 43% OA 180 psi. Initial gas 69u tapering down to 55u at BU continue to tapper down to 25u after 2 BU. Beyond found calibration issue with chokes. 03:43 shut in well W/ 186 psi on choke. Set slips and blow down top drive. Pre charge MPD system to 180 psi. Open Annular and equalize press, Csg press dropped F/ 186 psi to 178 psi MPD maintain 180 psi. Stage up pumps through MPD at 125 gpm/ MPD 122 pgm 813 psi. CBU seeing 18u Gas at surface. Simulate connection to ensure MPD is working correctly. PJSM MPD holding 150 psi dynamic and 180 psi static. Make connection and stage pumps up to 175 gpm 1,150 psi orient to mark on D.P. to 30° ROHS and wash down at 1-2 fpm F/ 3,475’ to 3,510’ MD. Observe fill @ 3,505’ MD and set parameters to 6k WOB 50-100 Diff 175 gpm/ MPD 176. MWD not operational. Unable to determine if in wellbore yet. Daily Disposal to G&I = 57 bbls, total = 1,389 bbls. Daily H2O from Lake 2 = 0 bbls total = 2310 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 19 bbls, Total 103 bbls. OA pressure 350 psi. 2/21/2022 With flow at 100 gpm, 750 psi continue wash/ream from 3510’ MD to 3528’, looking for free travel into open hole. Adjust RPM from 10-20 w/4-5k TQ. MPD Hold 150 psi pumps on/180 psi off. No MWD detection. Orient to 30º R mark on pipe. Kill pump and rotary, pull through window with 2-3K RIH to 3528’ and back up to 3080’ with no issues, see 3k drag both ways. Rack back 1 stand, B/D Top Drive. Decision made to Kill well and POOH for MWD. AT 3480’ MD, Beyond holding 150 psi. Shut annular and open rig to choke. Blow down Beyond. Bleed down casing to 0 and see 92 psi build over 15 minutes, Wt up active system to 9.9 ppg. M/U head pin/hose and circulate STS with 9.9 in/ out staging pumps to 4 bpm/1225 psi, holding 100 psi on casing. @ 700 stks see 588u gas dropping to 146u at end of circulation. Bleed casing to 0 and see 92 psi over 42 minutes. Wt up Mud system to 10.0 ppg. Circulated 10.0 STS @ 4 bpm/1160 psi. See MWD detection start working. MWD Detection back working Continue to attempt RIH referencing MWD/DD Slide sheet. Trip through window with no issues to 3527’. Orient TF to 130º R as per trend sheet. Make several attempts to find open hole. Bring on pumps @ 177 gpm, see 5-7 WOB and differential stalls, worked down worked down to 3571’. set down with 10K, @ 3530 sensor depth see 56.2º inc, 1.63º high from 54.63º original short survey Inc. Pull up Hole to 3525’, orient to ~160ºR and attempt to find well bore. Slide/Trough to undercut hole to drop inc and find well bore. Time Drill @ 30 fph 200 gpm, 1365 psi. At 3535 depth increase to 60 fph See 0-1K WOB no differential, set down @ 3571’. Short Survey @ 3508’ showed 56.9º, 1.3º high Pull up hole to 3507’ (3’ out side BOW) Rotate 30 rpm to 3527’, 200 gpm, 1420 psi, 3-4k Tq,. Orient to 130º R as per DD trend sheet and slide to from 3507’ – 3543’ @ 60 fph, 200gpm, 1360 psi. Short survey @ 3508’ sensor depth (3543’ bit depth) showed 56.83 inc, down from 56.9 inc. Pull up hole to 3507’ orient TF 180º, and slide from 3507’ – 3527’ @ 60 fph, 200gpm, 1360 psi, @ 3527’ adjust to 140-150 R slide to 3543’. PUH to 3500’, orient ~150º L , slide slowly down tray from 3500’ to 3506’, see 3K WOB, 40 Diff. At 3506’ roll TF to 180º R, see wt and diff fall off, @ 3535’, roll to 130º R. Slide to 3543’ see matching short survey Inc points for original Well Bore. Continue to slide to 3573’, all short surveys matching up. Back in original well bore. Wash and ream F/ 3,571' to 4,491' MD 250 gpm/ mpd 250, 1,880 psi 60 rpm Trq 4-5k, ECD 12.3 W/ MW 10.0 ppg Max Gas 484u BGG 180u. P/U 107k SLK 55k ROT 66k. Running speed 300-400 ft/hr. Keeping close eye on Diff and WOB. Perform check shots. Due to increase in Gas in old hole and slight flow increase at connections. Increase MPD F/ 150 psi Dynamic/ static to 180 psi dynamic EMW 11.28 & 210 psi static EMW 11.5 W/ MW 10.0 ppg at window TVD 2,696' TVD. At 20:00 Bled down OA F/ 650 to 150 psi seeing mostly gas. OA at 250 psi at 00:00. Lost 20 bbls for tour. Clean surveys at 3,800' MD. Check survey after each connection to confirm in wellbore. Wash and ream F/ 4,491' to 5,752' MD 250 gpm/ mpd 250, 1,990 psi 60 rpm Trq 6kk, ECD 12.03 W/ MW 10.0 ppg Max Gas 283u BGG 45u. P/U 128k SLK 61k ROT 73k. staging up running speed 400-600 ft/hr as hole dictates. At 4,549' MD adjusted MPD due to run speed decrease MPD Static 170 psi EMW 11.21 Dynamic 200 psi 11.42 W/ MW 10.0 ppg. At 4,740' MD reduced MPD Static 160 psi / Dynamic 190 psi. At 4,993' MD BGG 50u reduced MPD static 150/ dynamic 180 psi, 5,308’ MD 140 static / 170 Dynamic Staging down MPD pressure as gas and well pressure dictates. Appears gas falling off further into the well we get. After every connection about 30-500 stks into pumps on seeing gas spike to 150- 260u. Check survey after each connection to confirm in wellbore. Continue monitor OA every hour. Seeing dynamic losses 2-4 bph. Lost 11 bbls. OA Press 285 psi. Daily Disposal to G&I = 57 bbls, total = 1,446 bbls. Daily H2O from Lake 2 = 145 bbls total = 2455 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 20 bbls, Total 123 bbls. OA pressure 350 psi. 2/22/2022 Continue to wash and ream f/5752’ to 6675’ MD, tag bottom on depth w/5k down. 250 GPM/ MPD 250, 2150 PSI, 60 RPM, 8-10 TQ, ECD 11.8 w/10.0+ ppg MW, 482u Max Gas, 25u BGG. PU 164, SO 57K, Rot 89K. Run Speed 1500-2000 FPH as hole dictates. MPD 160 PSI Static and 180 dynamic, reduce to full open chokes by 6400’. Lost 19 bbls on trip. Circulate 35 bbls 10.0 ppg 200 vis sweep from STS, 250 GPM, Beyond F/O 250 GPM, 2055 PSI, 60 RPM, 8-9 TQ, ECD 11.7, Max Gas 482u decreasing to 30u at end of circulation. Sweep back 19 bbls late w/30% increase in cuttings. Shut in on MPD. Blow Down Top Drive and monitor well against M PD Choke. See shut in pressure build f/0 to 106 psi in 35 minutes. Pressure build and build times are consistent with 9.5, 9.8, 9.9 and 10.0 ppg MW’s. circulate STS @4 bpm while holding 130 psi surface pressure. PSI 1258, RPM 40, TQ 8-9K, ECD 10.56, Initial gas spike to 561u then up to 663u @ BUS from TOW(1277 stks) then falling to 35u at end of BUS from bit. 10.0 ppg in/out. Max gas spikes with multiple circulations are close to consistent with BUS from TOW @ 3491’. BROOH from 6675’ to 6383’ MD @ 45-50 FPH or as hole dictates. GPM 250, PSI 1945, Beyond F/O 215 GPM, RPM 60, TQ 8-10K, ECD 11.5, Max Gas 145u, PU 155K, SO 65K, Rot 98K. PJSM, Cont BROOH F/6383' md t/3546'md, gpm= 250, psi= 1780, rpm= 40- 60, tq= 4-6k, Beyond F/O = 250 gpm, max gas observed= 641 units, ECD= 11.6, p/u= 100k, s/o= 57k, rot= 71k, Beyond holding 150 psi static chokes full open while pumping, pumped BU over 2 stds prior to entering window, orient tool fac face orient tool face to 35 deg right pull into window with 3-4k t/3482' md Circulate 30 bbl 10.0 ppg, 110 vis sweep sts, 250 gpm, 1780 psi, max gas= 75 units, ECD=11.6, beyond chokes open. Back on time no increase. PJSM, RIH F/3482' MD to 3571' MD setting 8k down, out of original well bore, picked up to 3500' md orient tool to 150 left, 200 gpm, 1250 psi attempting to mirror entering original well bore 2 times 150 left f/3500' t/3507' orient to 180 down f/3507' t/3525' to 130 right f/3525' t/3543', short survey at window showed 1.3 deg high, pulled back to 3500' orient to 130 right and slide f3500' t/3543' still showing high at window. 3,500’ set TF 150° ROHS wash down 200 gpm 1,241 psi MPD 100% open. Slack down rolling to 130° ROHS to 3,525’ MD shot 55,68° inc, at 3,538’ MD depth 56.30° inc showing not in original wellbore. Pump out to 3,500’ MD hold 148° LOHS walking to 151° LOHS at 3,502’ MD W/ ~30 Diff continue washing down holding TF 130° LOHS to 3,508’ MD roll TF to 180° at 3,508’ MD seeing ~30 Diff at 3,519’ MD Diff falling to 2-3 TF walking / 168° to 127° ROHS at 3,542’ MD. Perform check shot showing 55.59° inc in original wellbore. Message without rotation holding TF 130° ROHS F/ 3,542’ to 3,527’, 3,542’ to 3,525’, 3,542’ to 3,523’, 3,542’ to 3,520’ MD performing check shots each time at 3,542’ MD showing 55.77° to 55.59° inc. F/ 3,542’ to 3,517’ MD check shot showed 56.74° in out of original wellbore. Messaged one more time F/ 3,542’ to 3,513’ MD check shot showed 56.83° at 3,542’ MD out of original wellbore. P/U to 3,507’ MD wash down holding TF 165° LOHS to 3,527’ MD rolled TF to 130° ROHS watching walk to 136° ROHS F/ 3,527’ to 3,542’ MD W/ no Diff, perform check shot at 3,542’ MD showing 55.59° Inc, good. RIH F/ 3,542’ to 3,578’ MD on elevators without issue verifying in wellbore. POOH rack back stand. Held no back pressure during tripping. Once pumps came on at 250 gpm 1,760 psi at BU saw 1,775u of gas and started holding 150 psi back pressure W/ MPD. Gas falling off quickly. Wash and ream F/ 3,542’ to 3,507’ MD 250 gpm 1,760 PSI 40 rpm Trq 3.7-4.4k control ream at 100 ft/hr F/ 3,520’ to 3,507’ MD. Shut down and trip back to 3,452’ and perform a check shot showing55.59° Inc TF 13° ROHS. Wash and ream 2nd time same parameters except slow down to 50 ft/hr F/ 3,520’ to 3,507’ MD, shut down and trip back to 3,452’ MD and check shot 55.56° inc TF 148 LOHS. Performed a 3rd time and showed 55.60° Inc TF 139 ROHS. Appears back in old hole without issue. POOH F/3483' MD T/3418' MD, 2 BPM, pulling 60 ft/min, circulate BU 250 gpm, 1680 psi, no rotation with beyond chokes open, max gas= 16 units. monitor well for 30 min. Start finger printing shut in press through MPD. Initial shut in 26 psi. Cont finger printing shut in pressure with MPD Initial shut-in pressure 26 psi first 10 min increased to 70 psi, 20 min 90 psi, 30 min 100 psi, 40 min 102 psi. 00:43 OA Press 190 psi. PJSM R/D RCD Bearing. Shut in Annular and monitor SICP Initial 13 psi. Remove grey clamp. Strip up RCD Bearing and bowl saver. L/D bowl saver and rack back RCD Bearing as per Beyond rep onsite. Install trip nipple and grey clamp. SICP 37 psi. Open choke and monitor well, initial flow 21 bph dropping to static after 5 min. Open Annular, well static. P/U TST-3 Storm Packer as Baker rep onsite. Pick 1 stand and set packer 10 turns to right. P/U 90k SLK 61k. Center of element 78’ MD top of packer 64’ MD, Bit depth 3,444’ MD. L/D run tools. 02:37 OA pressure 100 psi. PJSM Drain stack. P/U 3.5" test jnt M/U wear ring puller and pull wear ring. M/U test plug and set. M/U 3.5" Dart, 3.5" TIW, X/O & pump in sub. M/U test sub to TD. R/U test Equip & HP hoses. Flood stack and purge from system. Shell test 250/ 3000 psi 5 min, good. Test W/ 3.5" test jnt to 250/ 3,000 psi 5 min on chart Annular, Upper IBOP, 3.5" Dart, HCR Choke & HCR Kill. Daily Disposal to G&I = 57 bbls, total = 1,503 bbls. Daily H2O from Lake 2 = 145 bbls total = 2600 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 49 bbls, Total 172 bbls. OA pressure 100 psi. 2/23/2022 Continue testing CMV# 2,3, 4" TIW and Super Choke. Bleed off and R/D test equipment. break out and L/D Dart, TIW, XO and pump in sub. Pull test plug and set wear ring, RILDS, L/D test jt. M/U Over shot to running tool and RIH to 3444' and latch onto Storm PKR Verify no PSI in DP, shut annular and open to choke, PU and verify 0 pressure below PKR. Open annular and POOH and L/D PKR Assy. Drain stack, shut annular and open choke to monitor while installing MPD RCD. Remove trip nipple and install Bowl Saver/ MPD Bearing into Stack. Open annular to Beyond Choke, fill and flood Beyond lines checking WITS to Canrig. Good comms, no leaks. Orient to 25º ROHS and trip through window with no pumps/rotary from 3379' to 3585' and verify in original hole. No issues. 3-4K Drag through Window. PUW 96K, SOW 56K BROOH from 3585' to 3505' GPM 250, RPM 60, TQ 5K, ECD 11.5, Max gas 705u. To 3520' to 3505' pull 50 fph to clean up entry out of window. Pull Through window no issues. Pump out of hole from 3483' to 3283'. 3 bpm, 750 psi. Circulate BUS from 3283', gas spike to 215u and taper down to 37u. BROOH to 2664'. PUW 80K SOW 54K Pump out of hole from 2664' to 710' MD. 3 bpm, 540 psi, pull 90 fpm. PUW 54K, SOW 54K Monitor well for 1 hr prior to pulling MPD Bearing, closed Beyond Orbit Valve, lined up through choke to shakers watching for flow. Blow down Beyond lines. Drain stand, pull bowl saver, position stand at bearing, close annular to closed super choke to monitor well. Remove clamp and pull bearing, strip bearing off stand, run bell nipple and install clamp, open choke, no flow, open annular, fluid level at lower pipe rams. line up to TT. 3.5 bbls to fill POOH from 710' to 515'.Remove Dart and FOSV from stand #1 PJSM L/D 12 jnts 4" HWDP, SLB Jars, 2 ea NM FS, 2 ea NM FC. Read MWD tool. L/D TM, ADR, GM & DM. Milk mud motor and break off Bit. L/D. Bit Grade 2-6-T-X-1/16-NO-TD Lost 2 bbls during pumping out of hole. PJSM Remove wear ring. Clean and clear rig floor of BHA components. L/D 4" TIW & 4" Dart used in string. PJSM M/U X/O TCII P X 4.5" IF B, 5' 4.5" IF Pup & 20' 4.5" IF Pup for landing jnt. M/U 4.5" IF Cement Head, X/O 4.5" IF P X XT39 B and 5' XT39 handing pup. PJSM R/U 3.5" handling Equip & tools. C/O elevators to 3.5" YT. P/U 3.5" slips & air slips. R/U Power Tongs and JAM Equip. R/U fill up lines. Bring 90 centralizers (Pin & Hinge) to rig floor. Stage completion components in pipe shed. Stage 3.5" VAM pups on rig floor. Jnr 255 safety jnt in shed. PJSM P/U M/U Shoe Track. 3.5" 9.2# L-80 3.5" IBT Ported Shoe, 2 ea blank, FC, blank jnt, LC 127'. Baker Loc shoe track. Check floats, good. PJSM RIH 3.5" Completion. RIH 3.5" 9.2# L-80 JFE Csg F/ 127' to 788' MD. P/U 39k SLK 40k C/O Pups while running in hole F/ 3.5" JFE to 3.5" VAM in between 1 & 2, 4 & 5, 6 & 7 to get more separation between GLM's. Removed pup F/ X/N 2 & 4. Trq turn IBTM 3k, Vam 2,250 ft/lb JFE 3,870 ft/lb. Fill every 5 jnts, top off every 10 jnts. 01:00 OA 100 psi 05:00 OA 100 psi. No losses RIH. Daily Disposal to G&I = 347 bbls, total = 1,850 bbls. Daily H2O from Lake 2 = 150 bbls total = 2750 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 13 bbls, Total 185 bbls. OA pressure 100 psi. 2/24/2022 Continue RIH W/ 3.5” 9.2# L-80 JFE installing GLM’s & X/N’s F’ 788'’ to 4601'’ MD. PUW 65K, SOW 52K, TQ Turn JFE to 3870 ft/lbs. Run spiral centralizers and per tally (82 total) Fill every 5 jts top off every 10 jts. calc: 13.2 bbls, actual: 9.2, Loss 4bbls. No issues tripping through window. Continue RIH W/ 3.5” 9.2# L-80 JFE installing GLM’s & X/N’s F’ 4601' to 6617' MD. PUW 86K, SOW 58K, TQ Turn JFE to 3870 ft/lbs. Fill every 5 jts top off every 10 jts. No issues tripping GLM's through window. Confirm pipe count in pipe shed. (16 jts)P/U M/U Tbg Hgr, Landing joint and cement swivel. R/U cement line to swivel. M/U top Drive to 10' pup(W/Plug) on top of cement swivel. Land out hgr and verify landed through IA. Pull TG HGR 3' off seat. Circulate Bottoms Up from 6639' with 10.0 pps MW, staging pumps to 4 bpm 640 psi. Max gas @ 441u, stage to 5 bpm, 775 psi, 6 bpm 1030 psi. Switch over on the fly to 9.5 ppg at bottoms up and displace 10.0 ppg to 9.5 ppg. @ 7 bpm, 1320 psi. Shut down pumps, drain stack, land out TBG HGR w/24k below HGR placing shoe at 6614', RILDS, Establish circulation through IA back to pits. Stage pumps to 4 bpm. 1 bpm - 195 psi, 2 bpm- 275 ps, 3 bpm - 365, 4 bpm- 565 psi. Max Gas 390u. SIMOPS Haul off surface mud for cement displacement. PJSM, Wet lines w/ 5 bbls H2O (HES) and P/T w/ 1067 low/ 3344 high. Perform cement job as follows: 33 bbls 10.5# Tuned spacer 5.5 bpm 367 PSI. 128 bbls. 15.3# Type I/ II cmt, 1.235 yld (545sx), initial pump rate 3 bpm 369 psi slowing to 2 bpm psi at 60 bbls away FCP 161. Max Gas 388u. Launch dart. HES displace w/ 10 bbls H2O (HES) then turn over to rig. Rig disp w/ 46.4 bbls 9.5# inhibited brine, 2 bpm ICP 370 psi reduced rate last 3 bbls to 1 bpm, FCP 749 psi. Bump plug (1405 psi) with 46.4 bbls actual / 46.7 bbls calculated. Held pressure for 5 minutes, check floats - good. CIP @ 21:43 hrs. Full returns throughout job. PJSM R/U test Equip to cement swivel. MIT 3.5" tubing to 1,500 psi for 30 min on chart, good. Cont to Press up to 4,112 psi to shear rupture disk in Defender . Attempted to pump through Defender at 0.25 bpm working press up to 3,800 psi with returns. Appeared rupture disk not completely sheared. Attempted to shear again with test pump but could not get enough volume to pressure up past 980 psi. Came on with rig pumps cycled pumps F/ zero psi up to 3,800 psi at 0.75 bpm, rupture disk sheared. Increase pumps to 5 bpm 1,075 psi. Cont 7 bpm ICP 1,885 psi FCP 1690 psi displacing 9.5 ppd mud to 9.5 ppg corrosion inhibited brine. Saw spacer at surface and about 10 bbls of cement. Blow down all lines. R/D IA. L/D cement head. Daily Disposal to G&I = 314 bbls, total = 2,164 bbls. Daily H2O from Lake 2 = 200 bbls total = 2950 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 10.5 bbls, Total 195.5 bbls. OA pressure 100 psi. TBG HGR w/24k below HGR placing shoe at 6614', Circulate Bottoms Up from 6639' Activity Date Ops Summary 2/24/2022 PJSM R/D HP hoses. L/D landing Jnt. Drain stack. P/U tee bar and Vault rep set BPV. SIMOPS Clean pits and start inspection process on MP #1.,Flush through both MP's. Flush stack, choke manifold and all surface lines W/ H2O. Blow down. Drain stack.,PJSM Deenergize Koomey and remove lines. Remove drip pan and binders. Install bridge cranes to stack. Remove grey clamp and pull trip nipple. Install RCD cap. Remove 4" MPD lines. R/D kill & choke lines. Break and remove studs F/ DSA & RCD. P/U RCD head below rotary table. P/U and set stack on pedestal, secure. SIMOPS Cont cleaning pits and inspecting MP's. 2/25/2022 Continue N/D BOPE/MPD and associated equipment. Continue cleaning pits and inspecting mud pumps.,N/U Tree and test Tbg Hgr Void to 500/5000 psi. Pressure test Tree to 500/5000 psi for 15 min each. Pull TWC. R/D testing equipment,R/U LRS and pump 88 bbls DSL FP down IA take returns up Tbg @ 1.8 bpm, 700 psi. Shut down and R/D LRS. Line up IA to Tbg and U-Tube FP. SIMOPS L/D 4" DP from derrick in mouse hole. Clean pits. Went into Phase 2 weather conditions at 11:35. Working at reduced pace and limiting high risk operations.,Continue L/D 4" DP in mouse hole from the derrick and laying down in the pipe shed. Assist mechanic with cross head inspection on MP's. SIMOPS clean pits, C/O OA flange back to Ops W/ HP valve and gauge, C/O MP#2 wear plate Pod 3, MP #1 Pods 1, 2, 3, & 4 Valve & seats. Blow down H2O & R/D Mezz lines.,PJSM Pull Mouse hole. Set stack back on pedestal and secure.,PJSM Prep pipe shed for rig move. Cont working on pumps. Position Iron Roughneck in rig move position. and secure. Remove MPD flow line. R/U bleeder hose to flow line. At 22:39 Phase 3 weather condition due to high winds and visibility. Shut down all operations. Daily Disposal to G&I = 1318 bbls, total = 3482 bbls. Daily H2O from Lake 2 = 290 bbls total = 3240 bbls. Daily Metal: 0 lb. Total Metal 140 lb. Daily DH losses 0 bbls, Total 195.5 bbls 2/26/2022 Rig released at 06:00. 50-029-23213-01-00API #: Well Name: Field: County/State: PBW V-213A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 2/15/2022Spud Date: ACTIVITYDATE SUMMARY 3/2/2022 ***WELL S/I UPON ARRIVAL*** (waterflood regulator) RAN 2.80" CENT, 1.75" SAMPLE BAILER, SD HIGH @ 6,199' SLM (no sample) RAN 3 1/2" BRUSH, 2.75" GAUGE RING TO 6,349' SLM (restrictions @ 6207' & 6310') MADE 2 RUNS W/ 10' x 2.50" PUMP BAILER FROM 6,358' SLM TO 6,380' MD (recovered 3gals cement) ***CONT WSR ON 3/3/22*** 3/3/2022 ** ASSIST SL** AOGCC STATE WITINESSED by Adam Earl MIT X T ( 3200 psi. 3610 max applied ) (PASSED) Lost 72 psi. in 1st 15 min and 24 psi in 2nd 15 min. Pumped down IA at .18 bpm at 1275 psi. and .25 bpm at 1620 psi. Freeze protected FL with 2 bbls 60/40. FWHP's = 518/500/78 3/3/2022 ***CONT WSR FROM 3/2/22*** (waterflood regulator) RAN 10' x 2 1/2" PUMP BAILER FROM 6,381' SLM TO 6,385' SLM (1.5gal cement) SHIFTED 3 1/2" HP DEFENDER SLIDING SLEEVE CLOSED (up to close, pressured up to 1500psi and holding) RAN HES CBL FROM 6,370' SLM TO 2,000' SLM MADE 3 RUNS W/ 10' x 2 1/2" PUMP BAILER FROM 6,385' SLM TO 6,393' SLM (4gal of cement) LRS PERFORMED PASSING STATE WITNESSED MIT-T (see lrs log) LRS ATTEMPTED MIT-IA, GETTING LLR OF .16bpm @ 1600psi ***CONT WSR ON 3/4/22*** 3/4/2022 ***CONT WSR FROM 3/3/22*** (waterflood regulator) RAN HES 24 ARM CALIPER FROM 6,338' SLM TO SURFACE (good data) LRS ON IA *180DEG DIESEL1/2 bpm 2330PSI RAN HES PRESSURE/TEMP SURVEY W/ LRS ASSIST FROM 3,700' TO 1,000' SLM (see log) LRS PERFORMED PASSING MIT-T TO 4500psi (started 4800psi) SHIFTED 3 1/2" HP DEFENDER SLIDING SLEEVE OPEN (down to open) ***WELL S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 3/4/2022 **ASSIST SLICKLINE** (WATERFLOOD REGULATOR) Pumped x187 bbls hot diesel down IA. psi. for logging. MIT T to 4807 psi. (PASSED) lost 213 in 1st 15 min. Lost 78 psi in 2nd 15 min. SL on well at time of departure. 3/13/2022 ***WELL SHUTIN UPON ARRIVAL*** PLUG SET AT 3020.0', CCL TO ME = 9.0', CCL STOP DEPTH = 3011.0', ***READY FOR COIL*** 4/17/2022 T/I/O = SI/1500/350. Barriers = MV , SSV,- WV,& LAT. Verified by performing independent LTT (passed). Removed SV Bonnet, Gate & Seats. Inspected Seat Pockets (passed). Installed new Seat Seals, Seats, Gate & rebuilt Bonnet. Pressure tested SV 300/low & 4000/high (passed). RDMO ***Job Complete*** 4/18/2022 CTU #9 - 1.75" Coil Job Objective: Cement Squeeze through sleeve, Mill CBP MIRU CTU. ...Continued on WSR 4-19-22........ Daily Report of Well Operations PBU V-213A Daily Report of Well Operations PBU V-213A 4/19/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-18-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP Rig up CTU. Make up cementing BHA with HB-3 sleeve shifting tool. RIH and tag 3- 1/2" CBP at 3007' E / 3015' M. PU to 3004'. Pump down the coil taking returns from the IA (good 1:1 returns). Close IA and bullhead diesel down the coil taking returns through sliding sleeve to formation (0.5 BPM at 2250 psi WHP). PU to 2976' and confirm TxIA communication one last time. Circulate the coil and tubing to KCL to warm the coil. Circulate in 15 BBL's of 13 ppg FineCem and 15 BBL's of 15.8 ppg class "G" cement to the nozzle. Squeeze ~ 11.6 BBL's of cement through the sliding sleeve. Unable to achieve squeeze or get non freezable fluid off surface. POOH while reverse circulating. S/I the swab and finish reverse circulating to tanks. Attempt to RBIH and find the swab handle is stripped. Pump 10 BBL gel pill through the coil to tanks. Unstab and break down tools while WS works on swab valve. MU Baker 2-1/8" motor & 2.80" 3-blade junk mill. Drift to CBP and pump powervis sweep off bottom, spot powervis across sliding sleeve in attempt to contaminate any residual cement. ...Continued on WSR 4-20-22... 4/20/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-19-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP POOH with milling BHA, laying in diesel. Circulate 1.5 bbls of powervis through sleeve and up IA to contaminate any cement across sleeve. Unit secured, standby for cement compressive strength, Attempt CMIT-TxIA and establish injectivity of 0.3 bpm at 1607 psi, 0.4 bpm at 2180 psi, and 0.47 bpm at 2470 psi. Will proceed with second cement job. Make up sleeve shifting/cementing BHA and RIH. Tag top of plug at 3003'. Circulate 50 bbls of KCL to warm up the coil and well followed by 20 bbls of diesel to feeze protect the bsct. Circulate in 6 bbls of 13 ppg FineCem and 7 bbls of 15.8 ppg Class G cement. Able to squueze 10 bbls behind pipe. Lay in 3 bbls and hesitate squeeze. ****Continued on 04/21/22*** 4/21/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-20-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP Hesitate squeeze w/ 3 bbls of cement. Unable to achieve squeeze pressure. Overdisplace/ with 3 bbls of diesel. Circulate 2 bbls of diesel down IA to ensure path clear. RIH with HB-3 shifting tool and close sleeve. Pressure test tbg to 1500 psi to confirm sleeve closed. Launch 1/2" steel ball ond open circ sub. Chase ooh any residual cement in tbg. Pump drift ball and gel sweep at surface. Standby for cement. Est TOC ~3110' in IA. Pressure test IA Passed to 2000 psi.Lost 92/27 for a total of 119 psi in 30 mins. ***Continued on 04/22/22*** 4/22/2022 CTU #9 - 1.75" Coil ***Cont. from WSR 4-21-22*** Job Objective: Cement Squeeze through sleeve, Mill CBP MU & RIH with Baker 2-1/8" milling BHA with 2.80" 3-bld junk mill. MIll CBP and push to 6473' CTMD (~9' above landing collar), milling contaminated cement from 6460- 6473 CTMD. POOH jetting jewelry and FP well with diesel. RDMO CTU. ***Job Complete*** ***CBP debris most likely throughout wellbore and in WFR Mandels due to multiple overpulls*** 4/28/2022 ***WELL S/I ON ARRIVAL*** MOVE IN & RIG UP ***WSR CONTINUED ON 4-29-22*** Cement Squeeze through sleeve, Mill CBP Daily Report of Well Operations PBU V-213A 4/28/2022 MIT T to 3552 psi. ( PASSED ) Lost 153 psi. in 1st 15 min 28 psi, in 2nd 15 min. MIT IA to 3538 psi. ( PASSED ) Lost 150 psi. in 1st 15 min and 47 psi. is 2nd 15 min. Bled TBG and IA down to starting pressures andhung tags on SV and IA valve. DSO notified of results. FWHP's = 48/0/78 4/29/2022 T/I/O= 700/80/75 (CEMENT SQUEEZE) Assist PSL and AOGCC testing AOGCC (Brian Bixby) MIT-T to 3217 psi ****PASSED**** Pumped 0.7 bbls diesel to reach max applied 3419 psi Target 3200 psi. 1st 15 minute T lost = 161 psi. 2nd 15 minute T lost = 41 psi. Total 30 min loss = 202 psi. Bled back .7 bbls AOGCC (Brian Bixby) CMIT-TxIA to 3317/3283 psi ****PASSED**** Pumped 2.1 bbls diesel to reach max applied 3449/3409 psi Target 3200 psi. 1st 15 minute T/I lost = 94/89 psi. 2nd 15 minute T/I lost = 38/37 psi. Total 30 min T/I loss = 132/126 psi. Bled back 2.1 bbls SL in control upon LRS departure FWHP's = 1200/500/90 ) MIT-T to 3217 psi ****PASSED**** CMIT-TxIA to 3317/3283 psi ****PASSED**** Pumped TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. Yes X No Yes X No 6.48 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:x Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?x Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: Pup Joint Pup Joint Pup Joint Casing (Or Liner) Detail Other Pup Joint Tubing 4 1/2 118 2291.2 Rotate Csg Recip Csg Ft. Min. PPG9.5 Shoe @ 6614 FC @ Top of Liner6,525.00 Floats Held 20 128 10 118 Brine CASING RECORD County State Alaska Supv.J Lott / O Amend Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.PBW V-213A Date Run 24-Feb-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top HPHT Innovex 1.47 6,614.41 6,612.94 6,337.78 6,332.91 15.00 6,412.00 6,397.00 6,397.003 1/2 9.2 L-80 JFE 59.22 JFE 3 1/2 9.2 JFE Baker Baker 6,337.78 Vam Baker 7.22 3 1/2 9.2 3 1/2 9.2 Gas Lift Mandrel 5 1/2 6,310.06 Baker 4.87 VAM Baker Gas Lift Mandrel 5 1/2 Vam 6,268.76 4.90 6,302.843 1/2 6,254.56 6,332.91 6,325.71 15.65 6,325.71 6,310.06 14.20 6,297.94 7.20 29.18 Csg Wt. On Hook:59,000 Type Float Collar:Innovex HPHT No. Hrs to Run:17 JFE Baker Pup Joint 3 1/2 9.5 2 100 749FIRST STAGE10.5Tuned Spacer 33 4 1/2 46.4 / 46.7 1405 10bbl cmt Rig 15.3 128 Bump press cement circulated to surface through circ sub at 2995' MD Bump Plug? 21:43 2/24/2022 2,995 6,614.006,675.00 CEMENTING REPORT Csg Wt. On Slips:24,000 Profile Nipple Source water inhibited brine L-88 JFE JFE Baker9.2 9.2 6,253.33 6,302.84 1.23 6,254.56 6,297.94 6,268.76 26.71 RKB to CHF Type of Shoe:Ported/ Round Nose Casing Crew:Weatherford No. Jts. Delivered 225 No. Jts. Run 209 16 Length Measurements W/O Threads Ftg. Delivered 6,750.00 Ftg. Run 6,270.00 Ftg. Returned 180.00 Ftg. Cut Jt. Ftg. Balance www.wellez.net WellEz Information Management LLC ver_04818br 5108.83H2O 3 4.5" OD half clamp W/ nail Centralizers 1 ea Jnt 1 & 2, 1 ea Jnt 10 to 89. Total 82 used. Tubing 3 1/2 9.2 L-80 IBTM 86.52 6,612.94 6,526.42 Other 4 1/2 IBTM HPHT Innovex 1.08 6,526.42 6,525.34 Tubing 3 1/2 9.2 L-80 JFE 28.26 6,525.34 6,497.08 Pup Joint 3 1/2 9.2 L-88 JFE 4.33 6,497.08 6,492.75 Landing Collar 4 1/2 Vam Baker 1.26 6,492.75 6,491.49 Pup Joint 3 1/2 9.2 L-80 JFE 4.91 6,491.49 6,486.58 Tubing 3 1/2 9.2 L-80 JFE 58.91 6,486.58 6,427.67 Pup Joint 3 1/2 9.2 JFE Baker 14.43 6,427.67 6,413.24 Profile Nipple 4 1/2 JFE Baker 1.24 6,413.24 6,412.00 Tubing 3 1/2 9.2 L-80 JFE Type I/II 545 1.24 1405 cement circulated to surface through circ sub at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helsea Wright Digitally signed by Chelsea Wright Date: 2022.02.22 10:21:53 -09'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.02.22 11:32:37 -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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220421 1628 V-213A (PTD #222-001) Remedial Squeeze Sundry - Second Squeeze Date:Thursday, April 21, 2022 4:29:33 PM From: Rixse, Melvin G (OGC) Sent: Thursday, April 21, 2022 4:28 PM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: V-213A (PTD #222-001) Remedial Squeeze Sundry - Second Squeeze Wyatt, Second cement squeeze approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, April 20, 2022 10:48 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: V-213A (PTD #222-001) Remedial Squeeze Sundry - Second Squeeze Hello Mel, We performed an initial remedial squeeze with coil tubing on V-213A (PTD #222-001) yesterday under sundry # 322-111 (attached). While we were able to get nearly a full 3.5”x7” annular volume of 12 bbls of cement squeezed away, the squeeze rate was relatively low (~.25 bpm at 2500 psi) and we did not reach squeeze pressure before having to circulate out the remainder of our 30 bbls squeeze to avoid freezing cement. In the process of circulating out excess cement our slow leakoff rate continued. Today we are planning to test the squeeze after it has reached compressive strength then likely perform a smaller, 2nd squeeze job of ~12 bbls if we still have injectivity. This smaller volume will minimize the need to circulate once our squeeze is in place and avoid overdisplacing cement. Our smaller squeeze will follow the same sundry steps #5-10 but with a smaller volume pumped. Please let me know if you have any questions. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 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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y Meredith Guhl at 7:19 am, Mar 07, 2022 0*50$5 '656)' GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.11 14:00:48 -09'00' RBDMS SJC 031122 ĂƚĞ͗ Ăǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐ ^ƵŶĚƌǇWƌŽĐĞĚƵƌĞ ĂƚĞ͗ ĂƚĞ͗ ĂƚĞ͗ ĂƚĞ͗ 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 907 564-4422. Received By: Date: Hilcorp North Slope, LLC Date: 03/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: V-213A PTD: 222-001 API: 50-029-23213-01-00 FINAL LWD FORMATION EVALUATION LOGS (02/14/2022 to 02/19/2022) ROP, PCG, ADR (2” & 5” MD/TVD Color Logs) Final Definitive Directional Surveys SFTP Transfer - Data Folders: Please include current contact information if different from above. 222-001 T36395 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:56:00 -09'00' 1 Carlisle, Samantha J (OGC) From:Rixse, Melvin G (OGC) Sent:Friday, February 25, 2022 5:10 PM To:AOGCC Records (CED sponsored) Subject:FW: V-213A (PTD #222-001) 3.5" Completion Cement Job Report Attachments:Job Log V-213 Sidetrack.docx From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, February 25, 2022 3:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Nathan Sperry <Nathan.Sperry@hilcorp.com>; Joseph Engel <jengel@hilcorp.com> Subject: V‐213A (PTD #222‐001) 3.5" Completion Cement Job Report Hello Mel, Per the V‐213A (PTD #222‐001) PTD conditions of approval please see attached cementing report from the cement job on the 3.5” completion for this well. Well service report also included below for reference. Overall the cement job appeared to go very well. We had full returns throughout the job, bumped plug then successfully sheared out our sliding sleeve at ~3000’ MD, returning 10 bbls of cement from above the sleeve. A follow‐up CBL will be logged as part of slickline post rig work. Log and interpretation will be provided as soon as we have it. 2/25/22 Cement Job Service Report “Establish circulation through IA back to pits. Stage pumps to 4 bpm‐ 565 psi. Max Gas 390u. Perform cement job, pump 33 bbls 10.5# Tuned spacer 5.5 bpm 367 PSI. 128 bbls. 15.3# Type I/ II cmt, 1.235 yld (545sx), initial pump rate 3 bpm 369 psi slowing to 2 bpm psi at 60 bbls away FCP 161. Max Gas 388u. Launch dart. HES displace w/ 10 bbls H2O (HES) then turn over to rig. Rig disp w/ 46.4 bbls 9.5# inhibited brine, 2 bpm ICP 370 psi reduced rate last 3 bbls to 1 bpm, FCP 749 psi. Bump plug (1405 psi) with 46.4 bbls actual / 46.7 bbls calculated. Held pressure for 5 minutes, check floats ‐ good. CIP @ 21:43 hrs. Full returns throughout job. MIT 3.5" tubing to 1,500 psi for 30 min on chart, good. Cont to Press up to 4,112 psi to shear rupture disk in Defender. Had to cycle pumps to get rupture disk fully sheared. Displaced 9.5 ppd mud to 9.5 ppg corrosion inhibited brine. Saw spacer at surface and about 10 bbls of cement. Blow down all lines. R/D IA. L/D cement head. Switch to completion AFE at 00:00.” Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads) O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.com Hilcorp Alaska, LLC | Anchorage, AK 99503 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. 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. HILCORP ALASKA LLC For: James Lott Date: Thursday, February 24, 2022 V‐213 Inno sidetrack Inno sidetrack Job Date: Friday, February 25, 2022 Sincerely, Cody Yates Legal Notice Disclaimer: All information in this report is provided subject to the terms and conditions which govern the services provided by Halliburton. Halliburton personnel use their best efforts in gathering information and their best judgment in interpreting it, but any interpretation, research, analysis or recommendation furnished by Halliburton are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and empirical relationships and assumptions are not infallible, and with respect to which professionals in the industry may differ. iCem 3D Displacement results are used to understand how fluids intermix during a cement job. Simulation and 3D displacement results are not intended as and should not be used as a replacement for bond logs in determining top of cement. Current 3D model calculations are known to model more volume than the input volume for standard cases due to known calculation improvements required. For rotational cases, the modeled volume will be impacted by the same calculations impacting the standard cases, as well as additional constraints imposed to make the calculation time required operationally feasible. Therefore, until further notice, 3D displacement results should not be used for replacement of a bond log, or used as an identifier of top of cement. HALLIBURTON IS UNABLE TO GUARANTEE THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, OR JOB RECOMMENDATION and any interpretation or recommendation is not for use of or reliance upon by any third party. The customer has full responsibility for any of its decisions which are based on the information provided in this report. © 2020 Halliburton. All rights reserved. Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 3 (v. 6.0.286.0) Created: Thursday, February 24, 2022 Table of Contents Real‐Time Job Summary ....................................................................................................................................... 4 Job Event Log ......................................................................................................................................................................................... 4 Attachments ......................................................................................................................................................... 9 Inno sidetrack‐Cement.png ................................................................................................................................................................... 9 Custom Graphs ................................................................................................................................................... 10 Custom Graph ...................................................................................................................................................................................... 10 Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 4 (v. 6.0.286.0) Created: Thursday, February 24, 2022 1.0 Real‐Time Job Summary 1.1 Job Event Log Type Seq. No. Activity Graph Label Date Time Source PS Pump Press DH Density Comb Pump Rate Pump Stg Tot Comments (psi) (ppg) (bbl/min) (bbl) Event 1 Depart Shop for Location Depart Shop for Location 2/24/2022 09:30:00 USER Cody Yates Chan Poonian Mike Beulow Rick Houlton Event 2 Arrive At Loc Arrive At Loc 2/24/2022 10:30:00 USER Event 3 Pre‐Rig Up Safety Meeting Pre‐Rig Up Safety Meeting 2/24/2022 11:15:00 USER Wear traction devices, self aware of cold temperatures, communication. Event 4 Rig‐Up Equipment Rig‐Up Equipment 2/24/2022 11:30:00 USER Event 5 Rig‐Up Completed Rig‐Up Completed 2/24/2022 13:00:00 USER Event 6 Comment Meet with company man 2/24/2022 14:00:00 USER Hole 6 1/8'' Window top 3491' Window bottom 3504' TOC 3000' Shoe 6643.55' Float 6555' Plug landing 6521' Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 5 (v. 6.0.286.0) Created: Thursday, February 24, 2022 9.2# 3.5" tubing inside 26# 7" casing 7" casing from 3491' to surface Cement OL 545sks, 120BBL, MW 72.5bbls Event 7 Pre‐Job Safety Meeting Pre‐Job Safety Meeting 2/24/2022 18:28:24 USER ‐7.92 0.29 0.00 10.36 Event 8 Prime Pumps Prime Pumps/H2O Test 2/24/2022 19:28:27 USER 12.97 0.33 0.00 10.36 pH 7 Chlorides 0 ppm Hardness 10 ppm Alkalinity 60 ppm Iron 0 ppm Temp 75 F Event 9 Start Job Start Job 2/24/2022 19:36:43 COM4 ‐7.09 0.39 0.00 0.00 Event 10 Pump Spacer Ahead Pump H2O Ahead 2/24/2022 19:37:01 USER ‐7.42 0.37 0.00 0.00 pump 5 bbl, 440 psi, 3.4 bbl/min Event 11 Pressure Test Low Pressure Test 2/24/2022 19:39:33 USER 26.59 8.31 0.00 5.04 Low PT to 1100 psi, no leaks, eko functioned, good pt Event 12 Pressure Test High Pressure Test 2/24/2022 19:42:23 USER 3247.07 8.42 0.00 5.08 High PT to 3300 psi, no leaks, pressure held, good PT Event 13 Start Mix Start Mix 2/24/2022 19:45:21 USER ‐0.84 8.27 0.00 0.00 Spacer Wet 10.5 # Recirc 10.5# Mud Cup Event 14 Pump Spacer Ahead Pump Spacer Ahead 2/24/2022 19:54:24 USER 8.67 8.27 0.00 0.02 Pump Spacer Ahead, 40 bbl on location Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 6 (v. 6.0.286.0) Created: Thursday, February 24, 2022 Event 15 Comment Spacer Total 33 bbl 2/24/2022 20:06:09 USER 161.97 10.87 2.04 31.78 Event 16 Pump Cement ‐ Start Pump Cement ‐ Start 2/24/2022 20:07:52 USER 150.99 12.92 1.55 1.57 Pump cement, 15.3 ppg, 1.235 cft/sk, 5.593 gal/sk, 545 sks on location Event 17 Mud Cup Sample Pulled Mud Cup Sample Pulled 2/24/2022 20:12:45 USER 339.09 15.14 3.08 15.11 15.3 ppg Mud Cup Event 18 Slow Rate Slow Rate 2/24/2022 20:25:09 USER 331.41 15.30 3.07 53.26 Slow Rate to limit losses on backside Event 19 Pump Cement ‐ End Pump Cement ‐ End 2/24/2022 21:00:11 USER 111.53 14.81 1.73 0.23 Pump 128 bbl TOTAL 15.3 ppg Event 20 Drop Plug Drop Plug 2/24/2022 21:03:10 USER 7.18 8.18 0.00 0.00 Drop 3.5'' Plug PESI, IBOP frozen, Need to steam top drive Event 21 Pump Displacement ‐ Start Pump Displacement ‐ Start 2/24/2022 21:08:05 USER 5.81 8.34 0.00 0.00 Pump 10 bbl H2O from CMT pump Pump 46.7 bbl Brine from rig Event 22 Displ Reached Cement Displ Reached Cement 2/24/2022 21:08:54 USER 122.04 8.96 3.16 1.36 6 bbl H2O away Event 23 Pump Displacement ‐ Start Pump Displacement ‐ Start 2/24/2022 21:11:16 USER 191.10 8.48 3.65 10.82 10 bbl TOTAL pumped by cement pump Swap to rig to pump 46.7 bbl (753 strokes) to land plug Event 24 End Job End Job 2/24/2022 21:15:24 COM4 0.89 8.47 0.00 0.00 Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 7 (v. 6.0.286.0) Created: Thursday, February 24, 2022 Event 25 Pump Displacement ‐ Start Pump Displacement ‐ Start 2/24/2022 21:22:45 USER ‐8.29 0.22 0.00 0.00 350 strokes away, 2 bbl/min, 420 psi Event 26 Pump Displacement ‐ Start Pump Displacement ‐ Start 2/24/2022 21:23:54 USER ‐8.27 0.22 0.00 0.00 500 strokes away, 2 bbl/min, 670 psi Event 27 Pump Displacement ‐ Start Pump Displacement ‐ Start 2/24/2022 21:37:00 USER 749 strokes, 2 bbl/min, 900 psi fcp Event 28 Pressure Up Tubing Pressure Up Tubing 2/24/2022 21:37:27 USER pressure up tubing to 1500 psi to seat plug Event 29 Check Floats Check Floats 2/24/2022 21:42:49 USER Floats Held Event 30 Pressure Up Tubing Pressure Up Tubing 2/24/2022 21:44:51 USER Pressure test tubing, State Requirement, MIT 1500 psi for 30 mins Event 31 Comment Test Successful 2/24/2022 22:24:16 USER Prepare to burst disks in Sleeve Event 32 Comment Open sleeve 2/24/2022 22:25:50 USER Pressure well up to 4112 psi, burst disks in sleeve open and begin circulating Pressure 3000 psi Rate .5 bbl/min Well flowing with restriction Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 8 (v. 6.0.286.0) Created: Thursday, February 24, 2022 Event 33 Comment Pumping 2/24/2022 22:45:29 USER Pumping again, .5 bbl/min, 3600 psi having trouble moving fluid returns at shakers Event 34 Comment Pressure Dropped 2/24/2022 23:09:19 USER Pressure dropped off while working sleeve, Circulating well now Pressure 1800 psi Rate 7 bbl/min Event 35 Pre‐Rig Up Safety Meeting Pre‐Rig Up Safety Meeting 2/24/2022 23:11:43 USER Event 36 Crew Leave Location Crew Leave Location 2/24/2022 23:30:56 USER Event 37 Comment Job Complete 2/24/2022 23:35:04 USER Chemicals Used on JOB: 100 lbs citric acid 5 gal MMCR Customer: HILCORP ALASKA LLC Job: Inno sidetrack Case: Inno sidetrack | SO#: 907656682 Page 9 (v. 6.0.286.0) Created: Thursday, February 24, 2022 2.0 Attachments 2.1 Inno 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DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV HPDLOLVVWULFWO\SURKLELWHG,I\RXKDYHUHFHLYHGWKLVHPDLOLQHUURUSOHDVHLPPHGLDWHO\QRWLI\XVE\UHWXUQHPDLORUWHOHSKRQHLIWKHVHQGHU VSKRQHQXPEHULVOLVWHG DERYHWKHQSURPSWO\DQGSHUPDQHQWO\GHOHWHWKLVPHVVDJH :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH 3%89$37' +LOFRUS,QQRYDWLRQ 7HVWRI8VHG%23( -%5 37' 9 9 -%5 37' HILCORP BOP TEST SHEET DATE: 2/23/2022 PRIG CONTRACTOR: PDC R!G # !RIG TIME: 5 30:00 WELL NAME PBU-V-213A TYPE OF OPERATION - {DRILLING 1 WORKOVER 1 OTHER}: Workover gt NESS: START TIME; 5:30 AM REP: Lott/Amend END TIME: 6:30 AM ISOR: Sfure/Evans TEST TIME: 1 hr MPANY: PDC DP SIZES; 3 112 DENT: Jan King BOP SIZE &RATING: 13 518 5M Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail 1 "-Annular, upperIBOP, Dart, Kill HCR, Choke HCR 515 250 PASS 30QQ 2 4" TIW, CMV# 2,3 5/5 2.5 3000 PASS 3 Super Choke 1800 PASS 4 5 6 7 8 10 Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 13 5/8" ANNULAR Final Pressure 2 7/8"X5 1/2" UPPER RAMS 200 psi Re -charge Full Recovery 5" NO2 Bottle Avg. 3 1/8 "CHOKE/KILL HCRS Hiicorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. HILCORP BOP TEST NOTES A: LEFT VALVE ON TEST PUMP OPEN, UNABLE TO PRESSURE BACK UP BEFORE DROPPING BELOW 250 PSI TEST PRESSURE. BLEED OFF AND RE -TEST. 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: Injector V-213A (PTD #2220010) Tubing Cut pre-Rig Date:Thursday, February 10, 2022 8:10:40 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, February 7, 2022 7:44 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>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-213A (PTD #2220010) Tubing Cut pre-Rig Mr. Wallace, Injector V-213A (PTD #2220010) had the tubing cut on 02/06/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. 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. 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU V-213A Hilcorp North Slope, LLC Permit to Drill Number: 222-001 Surface Location: 4719' FSL, 1517' FEL, Sec. 11, T11N, R11E, UM, AK Bottomhole Location: 2244' FSL, 1274' FWL, Sec. 01, T11N, R11E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced 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 AOGCCwithin 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, Jeremy M. Price Chair DATED this ___ day of January, 2022. 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rudhoe Bay West V-213A SB Injector PTD Application ,QQRYDWLRQ5LJ&KRNH0DQLIROG6FKHPDWLF 3DJH Prudhoe Bay West V-213A SB Injector PTD Application &DVLQJ'HVLJQ 3DJH Prudhoe Bay West V-213A SB Injector PTD Application 0$63 0: ZLOO EH XVHG LQ KROH '/% +LOFRUSDVVXUDQFHWKDWSRUHSUHVVXUHVVOLJKWO\VXEQRUPDOPJU 3DJH Prudhoe Bay West V-213A SB Injector PTD Application 6SLGHU3ORW1$'*RYHUQPHQWDO6HFWLRQV 3DJH Prudhoe Bay West V-213A SB Injector PTD Application 6XUIDFH3ODW$V%XLOW1$' 6WDQGDUG3URSRVDO5HSRUW 'HFHPEHU 3ODQ9$ZS +LOFRUS1RUWK6ORSH//& 3UXGKRH%D\ 9 3ODQ9 3ODQ9$ 245028003150350038504200455049005250True Vertical Depth (700 usft/in)1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650 7000 7350 7700Vertical Section at 44.83° (700 usft/in)V-213A wp01 tgt350040004500500055006000650070007225V-21330003500400045005000550060006500700075008000850090009215V-213PB17" x 8 1/2"4000450050005500600065006567V-213A wp01KOP : Start Dir 12º/100' : 3550' MD, 2753.31'TVD : 30° RT TFEnd Dir : 3567' MD, 2762.89' TVDStart Dir 4º/100' : 3587' MD, 2773.91'TVDEnd Dir : 3898.97' MD, 2972.23' TVDStart Dir 3º/100' : 6321.85' MD, 4705.58'TVDEnd Dir : 6322.16' MD, 4705.8' TVDTotal Depth : 6566.8' MD, 4880.8' TVDUG4UG4AUG3UGNU MBSchrader NBOAOBAOBBOBDHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: V-213Ground Level: 54.30+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005969968.37590785.03 70° 19' 39.6543 N149° 15' 49.4502 WSURVEY PROGRAMDate: 2021-12-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool98.00 538.00 Survey #1 GYD_GC_MS (V-213PB1) 3_Gyro-CT_Drill pipe577.35 3476.49 Survey #2 MWD+IFR+MS (V-213PB1) 3_MWD (BP MWD+IFR+MS-WOCA)3571.07 3550.00 Survey #3 MWD+IFR+MS (V-213) 3_MWD (BP MWD+IFR+MS-WOCA)3550.00 6566.80 V-213A wp01 (Plan: V-213A) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation2906.80 2826.00 3804.47 UG42943.80 2863.00 3858.68 UG4A3294.80 3214.00 4349.86 UG34142.80 4062.00 5535.20 UGNU MB4353.80 4273.00 5830.13 Schrader NB4490.80 4410.00 6021.63 OA4554.80 4474.00 6111.09 OBA4593.80 4513.00 6165.60 OBB4703.80 4623.00 6319.36 OBDREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-213, True NorthVertical (TVD) Reference:V-213A RKB @ 80.80usftMeasured Depth Reference:V-213A RKB @ 80.80usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:VWell:Plan: V-213Wellbore:Plan: V-213ADesign:V-213A wp01CASING DETAILSTVD TVDSS MD SizeName4880.80 4800.00 6566.80 7 7" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 3550.00 54.79 46.34 2753.31 1447.19 1143.17 0.00 0.00 1832.30 KOP : Start Dir 12º/100' : 3550' MD, 2753.31'TVD : 30° RT TF2 3567.00 56.57 47.56 2762.89 1456.77 1153.43 12.00 30.00 1846.33 End Dir : 3567' MD, 2762.89' TVD3 3587.00 56.57 47.56 2773.91 1468.04 1165.75 0.00 0.00 1863.00 Start Dir 4º/100' : 3587' MD, 2773.91'TVD4 3898.97 44.32 50.70 2972.23 1625.53 1346.87 4.00 169.80 2102.39 End Dir : 3898.97' MD, 2972.23' TVD5 6321.85 44.32 50.70 4705.58 2697.79 2656.88 0.00 0.00 3786.39 Start Dir 3º/100' : 6321.85' MD, 4705.58'TVD6 6322.16 44.33 50.69 4705.80 2697.92 2657.05 3.00 -44.77 3786.61 V-213A wp01 tgt Start Dir 3º/100' : 6321.85' MD, 4705.58'TVD7 6566.80 44.33 50.69 4880.80 2806.23 2789.32 0.00 0.00 3956.67 Total Depth : 6566.8' MD, 4880.8' TVD 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 5500 5775 6050 South(-)/North(+) (550 usft/in)1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 West(-)/East(+) (550 usft/in) V-213A wp01 tgt 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 50 0 4 7 5 0 4983 V-21 3 3 0 0 0 3 5 0 0 3 7 5 0 4 0 0 0 4250 4 5 0 0 4 7 5 0 5 0 0 0 5 0 8 9 V -2 1 3 P B 1 7" x 8 1/2" 3 0 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 4 8 8 1 V- 2 1 3 A wp 0 1 KOP : Start Dir 12º/100' : 3550' MD, 2753.31'TVD : 30° RT TF End Dir : 3567' MD, 2762.89' TVD Start Dir 4º/100' : 3587' MD, 2773.91'TVD Total Depth : 6566.8' MD, 4880.8' TVD CASING DETAILS TVD TVDSS MD Size Name 4880.80 4800.00 6566.80 7 7" x 8 1/2" Project: Prudhoe Bay Site: V Well: 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3UXGKRH%D\+LOFRUS1RUWK6ORSH//&$QWLFROOLVLRQ5HSRUWIRU3ODQ99$ZS(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG'HFHPEHU &203$663DJHRI 0.001.002.003.004.00Separation Factor3675 3850 4025 4200 4375 4550 4725 4900 5075 5250 5425 5600 5775 5950 6125 6300 6475 6650 6825Measured Depth (350 usft/in)V-122V-212V-213V-213PB1V-137No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: V-213 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 54.30+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005969968.37590785.0370° 19' 39.6543 N149° 15' 49.4502 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-213, True NorthVertical (TVD) 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