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Home My WebLink About197-248CAUTION: 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: MPC-39 (PTD: 1972480) Tx IA communication Date:Monday, January 26, 2026 9:51:56 AM Attachments:MP C-39 SCHEMATIC 3-7-2025.pdf From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Monday, January 26, 2026 9:48 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com> Subject: Under Evaluation: MPC-30 (PTD: 1972480) Tx IA communication Mt Wallace, WAG Injector MPC-39 (PTD #1972480) IA was bled 11/24/26. The well is now reclassified as Under Evaluation and on a 28-day clock to perform diagnostic tests to determine the IA re-pressurization. See attached schematic and 30-day TIO plot. Plan Forward: PPPOT-T Slickline to verify SSD closed Bleed IA and monitor Please respond with any questions. Steve Steve Soroka Hilcorp Alaska North Slope, LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Revised By: TDF 3/7/2025 SCHEMATIC Milne Point Unit Well: MPU C-39 Last Completed: 2/7/2025 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80/ JFE Bear 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 7,171’ Sliding Sleeve: HAL XD SSD 2 7,215’ Packer: HES TNT Permanent 3 7,236’ X Nipple:Min ID = 2.813” 3 7,252’ Overshot: Non Sealing w/ 4 -1” Ports –Btm @ 7,259’ 4 7,283’ 7” Baker Packer 5 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 6 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 7 7,465’ Baker Anchor Seal Assy 8 7,467’ 7” Baker S Packer 9 7,484’ XN Nipple W/ 2.75 No Go 10 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’ (MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 3 6 9-5/8” 2Min ID= 2.813” @ 7,236’ 7 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ Tubing Cut @ 7,255’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 8 9 10 4 1 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E–1/29/1998 Tubing Cut & Add Packer by ASR1 –2/7/2025 Well: MPC-39 6,C 5.5 5.0 QE 4,C Fp a 3.5 m y 3.0 a`2a 2,C 5 t.0 TIO Plot �— Tubing On ■ Bleed ♦ Operable + Not Oper ♦ Under Eval t Man. IA —A— Man. OA Man. OOA - . Man. OOOA —0 - Man. WHT CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from chris.casey@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable: MPC-39 (PTD #1972480) - IA pressure stabilization Date:Tuesday, June 3, 2025 10:17:26 AM Attachments:image001.png From: Chris Casey - (C) <Chris.Casey@hilcorp.com> Sent: Tuesday, June 3, 2025 9:39 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com> Subject: Operable: MPC-39 (PTD #1972480) - IA pressure stabilization Mr. Wallace, WAG Injector MPC-39 (PTD #1972480) had a PPPOT-T to 500/5000 psi and a PPPOT-IC to 500/3000 psi performed on 5/13/2025, both tests ended with PASSING results. On 5/15/2025 the IA was bled (all fluid) and further monitored for repressurization. With the IA showing signs of stability, we will reclassify the well as OPERABLE. Attached is a 30-day TIO plot for reference. Please call with any questions or concerns. Thanks, Chris CaseyHilcorp Alaska LLCField Well Integrity chris.casey@hilcorp.com O: (907) 659-5738 P: (907)242-1021Alt: Steve Soroka Hilcorp North Slope, LLC From: Stephen Soroka Sent: Monday, May 12, 2025 4:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com> Subject: Under Evaluation: MPC-39 (PTD #1972480) - IA Repressurization Mr. Wallace, WAG Injector MPC-39 (PTD #1972480) had a tubing swap RWO in February 2025. The well was placed on injection on February 22, 2025, and passed an AOGCC witnessed MIT-IA post coming online. IA pressure has been increasing, as shown in the attached 30-day TIO plot. The well is now classified as UNDER EVALUATION and on a 28-day clock while we perform diagnostic tests to determine the cause of the IA repressurization. Plan forward. 1. PPPOT-T 2. Additional diagnostics, as necessary. Please call with any questions or concerns. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well- MPC-39 ■ 05@325 W10125 W1725 052M25 0513125 300 290 280 270 260 250 240 230 220 210 200 190 180 170 160 3 150 0 140 130 120 110 100 90 80 70 60 50 40 30 20 10 TIO Plot f Tubing On ■ Bleed * Operable + Not Oper ♦ Under Eva] —AM— Man. IA —A Man.OA Man. OOA Man. OOOA — Man. WHT 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: MPC-39 (PTD #1972480) - IA Repressurization Date:Tuesday, May 13, 2025 8:21:20 AM Attachments:MP C-39 SCHEMATIC 3-7-2025.pdf From: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Monday, May 12, 2025 4:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com> Subject: Under Evaluation: MPC-39 (PTD #1972480) - IA Repressurization Mr. Wallace, WAG Injector MPC-39 (PTD #1972480) had a tubing swap RWO in February 2025. The well was placed on injection on February 22, 2025, and passed an AOGCC witnessed MIT-IA post coming online. IA pressure has been increasing, as shown in the attached 30-day TIO plot. The well is now classified as UNDER EVALUATION and on a 28-day clock while we perform diagnostic tests to determine the cause of the IA repressurization. Plan forward. 1. PPPOT-T 2. Additional diagnostics, as necessary. Please call with any questions or concerns. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: MPC-39 6,000 5,500 5,ODD 4,5W 4,OD0 3,50D 3,OW 2,500 2,ODD 1,500 1,0D0 5D0 04A1,25 0411 &25 04/25125 05IM5 05'09+25 t?1.f: 230 260 240 220 200 130 160 a m 140 m 120 m 100 30 60 40 20 TIO Plot f Tubing On ■ Bleed * Operable + Not Oper ♦ Under Eval --1111- Man. IA A Man. OA Man. OOA Man. OOOA 0 Man. WHT _____________________________________________________________________________________ Revised By: TDF 3/7/2025 SCHEMATIC Milne Point Unit Well: MPU C-39 Last Completed: 2/7/2025 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80/ JFE Bear 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 7,171’ Sliding Sleeve: HAL XD SSD 2 7,215’ Packer: HES TNT Permanent 3 7,236’ X Nipple:Min ID = 2.813” 3 7,252’ Overshot: Non Sealing w/ 4 -1” Ports –Btm @ 7,259’ 4 7,283’ 7” Baker Packer 5 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 6 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 7 7,465’ Baker Anchor Seal Assy 8 7,467’ 7” Baker S Packer 9 7,484’ XN Nipple W/ 2.75 No Go 10 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’ (MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 3 6 9-5/8” 2Min ID= 2.813” @ 7,236’ 7 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ Tubing Cut @ 7,255’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 8 9 10 4 1 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E–1/29/1998 Tubing Cut & Add Packer by ASR1 –2/7/2025 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 3, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-39 MILNE PT UNIT C-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/03/2025 C-39 50-029-22849-00-00 197-248-0 G SPT 6947 1972480 1737 4319 4311 4319 4319 103 105 101 111 INITAL P Guy Cook 2/25/2025 Post rig workover MIT-IA on injection per Sundry 325-023. 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:MILNE PT UNIT C-39 Inspection Date: Tubing OA Packer Depth 667 2020 1979 1966IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250224180434 BBL Pumped:1.2 BBL Returned:1.2 Thursday, April 3, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 9 9 Post rig workover MIT-IA on injection per Sundry 325-023 James B. Regg Digitally signed by James B. Regg Date: 2025.04.03 12:21:14 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 1, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-39 MILNE PT UNIT C-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/01/2025 C-39 50-029-22849-00-00 197-248-0 N SPT 6947 1972480 3650 1198 1592 1609 1606 62 50 39 34 OTHER P Kam StJohn 2/18/2025 Sundry # 325-023 Post initial injection MIT-IA 3650 psi per procedure 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:MILNE PT UNIT C-39 Inspection Date: Tubing OA Packer Depth 575 3802 3738 3721IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250218090605 BBL Pumped:2.9 BBL Returned:2.9 Tuesday, April 1, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.01 12:10:10 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG Injector MPC-39 (PTD# 1972480) - Post RWO for WAG injection Date:Tuesday, February 18, 2025 11:11:39 AM Attachments:image001.png image002.png MP C-39 AOGCC 10-403 APPROVAL 1-24-2025.pdf From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, February 18, 2025 11:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: WAG Injector MPC-39 (PTD# 1972480) - Post RWO for WAG injection Mr. Wallace, Injection well MPC-39 had a RWO completed on 2/7/25 replacing the tubing per Sundry #325-023. The packer was set post rig. On 2/18/25 the well passed an AOGCC witnessed offline MIT-IA to 3721 psi. Prior to the RWO, the well was operated under AIO 10B.020 as a PWI only well. The well is now reclassified as an operable WAG injector per the sundry approval. Sundry attached for reference. A cancellation of AIO 10B.020 will be submitted to AOGCC separately. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, June 15, 2023 2:43 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: PWI Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC-39) Mr. Wallace, AA, AIO 10B.020 was approved by AOGCC on 6/14/2023. This well will now be classified as OPERABLE for water injection only. Please respond with any concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, June 1, 2023 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, Per our conversation we will leave this well online as we pursue an AA for PWI only. Thanks, Ryan Thompson Milne/Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, May 4, 2023 10:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) is currently shut in. Per our conversation we will now bring this well onlineUNDER EVALUATION on water injection only and monitor for pressure communication. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi 3. CTU remove ice plug 4. Ops to place well on water injection Please respond with any comments or concerns. Thanks, Ryan Thompson MPU/Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Tuesday, January 31, 2023 12:52 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified asNOT OPERABLE. The well will be re-evaluated at a later time. 5. PPPOT-T Passed 6. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified asUNDER EVALUATIONand is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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 acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Tubing Cut Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Complete 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,922'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Erik Nelson Contact Email:Erik.Nelson@hilcorp.com Contact Phone:907-564-5277 Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT C-39 MILNE POINT KUPARUK RIVER OIL N/A 7,537' 7,796' 7,420' 4,145 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/30/2025 Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 197-248 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22849-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 112' 112' 9.3 / L-80/ EUE TVD Burst 7,497' MD 7,854' N/A 5,750psi 7,240psi 4,674' 7,502' 4,821' 7,884' See Schematic See Schematic 3-1/2" 7" Baker & 7" Bakler S and N/A 7,283 MD/ 6,947 TVD & 7,467 MD/ 7,116 TVD and N/A 79' 20" 9-5/8" 7" 4,790' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:09 am, Jan 22, 2025 325-023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.22 09:49:09 - 09'00' Taylor Wellman (2143) DSR-1/22/25A.Dewhurst 23JAN25JJL 1/23/25 10-404X AOGCC witnessed BOP Test to 4500 psi, Annular Test to a minimum of 2500 psi. AOGCC witnessed post-initial injection MITIA X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.24 14:51:58 -09'00'01/24/25 ®ôīīϙbÍıôϡ aϙϱ͒͘IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ ®ťŘϙiĲīƅϙIĲĤ ĖČϡ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͒͏ϙVÍĲϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͔ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͖͐͘ϱ͓͑͗ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͓͓͕͗ϙŕŜĖϙЬϙiϙ͖͓͒͑ϱċťϙa"ϙϼ͖͏͏͔ϱċťϙ«"Ͻ ŜĖĲČϟIϟĺċϟ͖͚͕͜ϟŕŜĖϟЂ͖͛ϟVÍĲϟ͕͚͗͗ЃϟÍĲîϟ͝ϥ͚ϳϟƲŪĖî ͕͐ϙVÍĲϙ͑͏͔͑ϙиϙ͐͒ϟ͒ϙ(a®ϙϼ͐͒ϟ͔ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͓͓͔͐ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͓͑ϟ͖еϙЬϙ͓͘͏͏ϱċťϙa" aÍƄϙ"ĺČīôČϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͒ϟ͑еϯ͐͏͏ϱċťϙЬϙ͕͓͐͑ϱċťϙa" aĖĲϙI"ϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϽϡ ͑ϟ͖͔͏ϱĖĲϙ³bϙbĖŕŕīôϙÍťϙ͖͓͓͗ϱċťϙa" Xϡ ͓͑ϟ͗͗ϱċťϙϼbÍæĺŘŜϙ͑͑(Ͻ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙϱ͒͘ϙſÍŜϙîŘĖīīôîϙĖĲϙ"ôèôıæôŘϙ͐͗͘͘ϙÍŜϙÍϙŽôŘťĖèÍīϙXŪŕÍŘŪħϙĖĲĤôèťĺŘϟϙϙƄIϙèĺııŪĲĖèÍťĖĺĲϙĺĲϙČÍŜϙēÍŜϙ æôôĲϙĲĺťôîϙıŪīťĖŕīôϙťĖıôŜϙŜĖĲèôϙťēôĲϙſĖťēϙťēôϙīÍťôŜťϙæôĖĲČϙi@ЍŜϙîıĖĲĖŜťŘÍťĖŽôϙŕŕŘĺŽÍīϙϼIiϱ͑͒ϱ͏͐͒Ͻϙ ČŘÍĲťĖĲČϠϙŜŪæĤôèťϙťĺϙèĺĲîĖťĖĺĲŜϠϙFĖīèĺŘŕЍŜϙŘôŗŪôŜťϙťĺϙèĺĲťĖĲŪôϙſÍťôŘϙĺĲīƅϙĖĲĤôèťĖĺĲϟϙϙēôϙſôīīϙēÍŜϙæôôĲϙĺĲϙ ſÍťôŘϱĺĲīƅϙĖĲĤôèťĖĺĲϙŜĖĲèôϙťēÍťϙÍŕŕŘĺŽÍīϙîÍťôîϙ͓͐ϙVŪĲôϙ͑͏͑͒ϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -aIϱIϙťĺϙ͔͑͐͏ϙŕŜĖϙŕÍŜŜôîϙϼi@ϙſĖťĲôŜŜϽϙĺĲϙ͏͓ϙôŕϙ͑͏͑͒ -aIϱIϙťĺϙ͓͕͖͏ϙŕŜĖϙŕÍŜŜôîϙϼbĺĲϱi@ϙſĖťĲôŜŜϽϙŕÍŜŜôîϙĺĲϙ͏͑ϙVÍĲϙ͑͏͑͒ -æČϙFČŘϙiϙŕÍŜŜôîϙťĺϙ͔͏͏͏ϙŕŜĖϙ͑͒ϙ"ôèϙ͑͏͑͑ -͐ϱΫЋϙĖŘèϙ«ÍīŽôŜϙŜôťϙĖĲϙÍıèĺϙaa@ϱ͑ϙ@[aŜϙĺĲϙ͏͐ϙaÍŘϙ͐͗͘͘ -IϙīĺČϙŕŪīīôîϙ͐͗ϙVÍĲϙ͐͗͘͘ϟϙϙiϙèÍīīôîϙÍťϙѷ͔͏͏͏ϱċťϙa"ϟϙϙ@ĺĺîϙèĺĲťĖĲŪĺŪŜϙèôıôĲťϙċŘĺıϙѷ͕͏͏͏ϱċťϙ a"ϙťĺϙ͖͖͏͏ϱċťϙa"ϟ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ iæĤôèťĖŽôϡ ®ĖťēϙťēĖŜϙŕŕīĖèÍťĖĺĲϙċĺŘϙŪĲîŘƅϙŕŕŘĺŽÍīϙſôϙÍŘôϙŘôŗŪôŜťĖĲČϙťĺϙŕŪťϙϙĺĲϙaϙϱ͒͘ϙťĺϙŕôŘċĺŘıϙÍϙťŪæĖĲČϙ ŜſÍŕϙťĺϙŘôŜťĺŘôϙĖĲťôČŘĖťƅϟϙϙ®ĖťēϙċĺīīĺſϱŪŕϙaIŜϙťēĖŜϙŜēĺŪīîϙÍīīĺſϙċĺŘϙťēĖŜϙſôīīϙťĺϙæôϙŕŪťϙæÍèħϙťĺϙ®@ϙĖĲĤôèťĖĺĲϙ ŜôŘŽĖèôϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -Řôϱ®iϙſôīīſĺŘħϙťĺϙŕŘôŕϙÍĲîϙŜôèŪŘôϙſôīī -ŪīīϙôƄĖŜťĖĲČϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ((ϙ͗ŘîϙťæČ -ŪĲϙĲôſϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙŜťÍèħϙŕÍèħôŘϙèĺıŕīôťĖĺĲ -ôťŪŘĲϙſôīīϙťĺϙ®@ϙIĲĤôèťĖĺĲ ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ īĖèħīĖĲô ÍϽ "ŘĖċťϙċĺŘϙæČϙŪťťôŘϙϼ͑ϟ͖͔͒ϱĖĲϽϙťĺϙ͖͓͔͏ϱċťϙa" æϽ iæťÍĖĲϙŪŕîÍťôîϙFϙſĖťēϙ͐͏ϱıĖĲϙŜťĺŕϙÍťϙ͖͓͔͏ϱċťϙa"ϙϼ͖͐͏͏ϱċťϙ«"Ͻϙſϯϙ͔ϱıĖĲϙČŘÍîĖôĲťϙŜťĺŕϙ Íťϙ͖͑͒͐ϱċťϙa"ϙϼ͕͘͏͏ϱċťϙ«"ϽϙÍĲîϙ͕͖͘͘ϱċťϙa"ϙϼ͕͔͏͏ϱċťϙ«"Ͻ èϽ ôťϙ³ϙŕīŪČϙÍĲîϙèÍťèēôŘϙĖĲϙ͑ϟ͖͔ϙЌ³ЍϙĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" îϽ ϙťæČϙťĺϙ͔͒͏͏ϙŕŜĖϙťĺϙôĲŜŪŘôϙŕīŪČϙĖŜϙŜôÍťôîϙĖĲϙŕŘĺƱīô ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ ͑Ͻ (ϱ[ĖĲô ÍϽ ŪťϙťæČϙѷ͖͔͔͑ϱċťϙa"ϙϼıĖîϱĤťϙĖĲϙ͐ ŜťϙċŪīīϙĤťϙÍæĺŽôϙÍħôŘϙaĺîôīϙϱ͒ϙŕħŘϙϼťıϯĺŕϙϳϙѷ͖͖͑͐ϯѷ͖͓͑͏ϱ ċťϙa"ϽϽ bi(ϡϙϙFÍŽôϙŕŪıŕϙÍŽÍĖīÍæīôϙĺĲϙīĺèÍťĖĺĲϙťĺϙîôťôŘıĖĲôϙĺŪŘϙÍæĖīĖťƅϙťĺϙèĖŘèŪīÍťôϙÍċťôŘϙťēôϙťæČϙèŪťϟϙϙIċϙ èĖŘèŪīÍťĖĺĲϙŘÍťôŜϙÍŘôϙĖĲŜŪƯĖèĖôĲťϠϙaϙťæČϙŕŪĲèēϙÍĲîϙŕŪĲèēϙÍæĺŽôϙťæČϙèŪťϙſēĖīôϙ(ϱ[ĖĲôϙĖŜϙŜťĖīīϙĺĲϙ īĺèÍťĖĺĲϟ ͒Ͻ >ŪīīæĺŘô ÍϽ īôôîϙæČϯIϙťĺϙ͏ϙŕŜĖ æϽ ĖŘèŪīÍťôϙťēôϙſôīīϙĺŽôŘϙťĺϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϙîĺſĲϙťēôϙťæČϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙ ťēŘĺŪČēϙťēôϙťæČϙèŪť bi(ϡϙϙæČϙ«ĺīϙϼѷ͕͓ϙææīŜϽϙϯϙIϙ«ĺīϙϼѷ͐͑͘ϙææīŜϽϟϙϙIċϙ>ϙĲôôîŜϙťĺϙæôϙŕīÍèôîϙĖĲϙſôīīϙÍèèĺŘîĖĲČϙťĺϙ ЍŜϙÍŘŘĖŽÍīϠϙèĺĲťÍèťϙi(ϙċĺŘϙÍîĤŪŜťôîϙX®>ϟϙϙ®ôϙĲôôîϙťĺϙèĖŘèŪīÍťôϙťēôϙſôīīϙħĖīīϙÍŜϙèīĺŜôϙÍŜϙ ŕĺŜŜĖæīôϙťĺϙЍŜϙÍŘŘĖŽÍīϙîŪôϙťĺϙťēôϙŕĺťôĲťĖÍīϙċĺŘϙæÍŘĖťôϙŜÍČϙſĖťēϙťēĖŜϙX®>ϙŜƅŜťôıϟ ͓Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙϙŕĺťϙŘĖČϙıÍťŜϠϙ͔͏͏ϙææīϙťÍĲħϠϙÍĲîϙèĺĲťÍĖĲıôĲťϟ æϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ èϽ aIϙèŘÍĲôϟϙϙôťϙ«ϟϙϙb"ϙťŘôôϙÍĲîϙbϙ͐͐Ћϙi(ϙŘĖŕīôϙťÍèħϙϼīĖĲîŜϙϯϙ͑ϱ͖ϯ͗ЋϙƄϙ͔Ћϙ«ϙϯϙ͒ϱ ΫЋϙĖŕôϙϯϙĲĲŪīÍŘϽϟϙϙbϙi(ϙēĺŪŜôϟϙϙŕĺťϙıŪîϙæĺÍťϟ bi(ϡϙϙ«ϙŕŘĺƱīôϙĖŜϙ͒ЋϙI® ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ aIϙϯϙôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϠϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲϙťÍĲħ ͑Ͻ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙťæČϙÍĲîϙ èŜČϟϙϙĖŘèŪīÍťôϙ͐͒ϟ͔ϙX®>ϙîĺſĲϙťæČϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙťēŘĺŪČēϙťēôϙťæČϙèŪťϙÍŜϙĲôôîôîϟ ͒Ͻ ôŜťϙi(ϙťĺϙ͓͔͏ϙŕŜĖϙ[ĺſϙϯϙ͓͔͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͓͔͏ϙŕŜĖϙ[ĺſϙϯϙ͓͔͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙ ŘÍıϯŽÍīŽôϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ bĺťĖċƅϙi@ϙ͓͑ϱēŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜťĖĲČ æϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī èϽ ôŘċĺŘıϙťôŜťŜϙÍŜϙŕôŘϙϙ͐ϙi(ϙôŜťϙŘĺèôîŪŘô îϽ ôŜťϙ«ŜϙĺĲϙ͒ϱΫЋϙϼôƄĖŜťĖĲČϙèĺıŕīôťĖĺĲϠϙſĺŘħŜťŘĖĲČϠϙÍĲîϙĲôſϙèĺıŕīôťĖĺĲϽϙťôŜťϙĤťϟϙϙôŜťϙĖŕôϙ ÍıŜϙĺĲϙ͒ϱΫЋϙťôŜťϙĤťϟ ôϽ ŪæıĖťϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙťĺϙi@ϙſĖťēĖĲϙϼ͔ϽϙîÍƅŜϙĺċϙi(ϙťôŜť ͓Ͻ ŪīīϙϙīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙĺƯϙťæČϯIϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙIċϙŘôŗЍîϠϙèĖŘèŪīÍťôϙÍîîĖťĖĺĲÍīϙ ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϟϙϙŪīīϙ«ϟϙϙ[ŪæŘĖèÍťôϙĖċϙŕŘôŜŜŪŘôϙĖŜϙôƄŕôèťôîϟ ŪīīϙŘĺîϙæČϡ ͔Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϙÍĲîϙŪĲīÍĲîϙťæČϙēČŘ ͕Ͻ īĺŜôϙæÍČϙÍĲîϙèĖŘèŪīÍťôϙēĺīôϙŽĺīŪıôϙϼѷ͔͔͑ϙææīŜϽϙťĺϙŘôϱèĺĲîĖťĖĺĲϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®> ͖Ͻ ôèĺŽôŘϙťæČϙēČŘ ͗Ͻ aĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſ ͘Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙôƄĖŜťĖĲČϙ͒ϱΫЋϠϙ͘ϟ͒ϭϠϙ[͗͏ϙ((ϙ͗ŘîϙťæČϙıÍĖĲťÍĖĲĖĲČϙēĺīôϙƱīīϙŕôŘϙťæČϙ îĖŜŕīÍèôıôĲťϟϙϙ®ÍŜēϙÍĲîϙťŘÍŜēϙÍīīϙĤťŜϙÍĲîϙĤôſôīŘƅϟ bi(ϡϙϙbĺϙŘôèĺŘîϙĺċϙ®ϙĺŘϙi®ϙċŘĺıϙbÍæĺŘŜϙ͑͑(ϙ ͐͏Ͻ bĺťôϙèĺĲîĖťĖĺĲϙĺċϙŕŘôϱ®iϙťæČϙèŪťϟϙϙaĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſϟ ŪĲϙ͒ϱΫЋϙťÍèħϙħŘϙôϱĺıŕīôťĖĺĲϡ ͐͐Ͻ aϙÍĲîϙIFϙſϯϙĲôſϙ®@ϙIĲĤϙèĺıŕīôťĖĺĲϡ ÍϽ ĺĺŘϙĺƅϙiŽôŘŜēĺťϙĺŘϙŜĖıĖīÍŘϙϼſϯϙťÍťťīôϙťÍīôϙŜēôÍŘϙŕĖĲŜϽϙŜôťŪŕϙċĺŘϙѷ͐͏ϱċťϙŜſÍīīĺſϙĺĲϙ͒ϱΫЋϙťæČϙ æôċĺŘôϙĲĺϱČĺϟ æϽ ĺŘťôîϙŪæ èϽ ͒ϱΫЋϙЌ³ЍϙĲĖŕŕīôϙŕŘĺƱīôϙϼ͑ϟ͗͐͒ГϙĺŘôϽϠϙ͘ϟ͒ϭϠϙ[͗͏ϙ((ϙ͗ŘîϠϙϙƄϙϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜ îϽ ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ((ϙ͗ŘîϙŕĖĲϙƄϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙ«ÍıϙĺŕϙƄϱĺŽôŘ ôϽ ͖ЋϙƄϙ͒ϱΫЋϙF(ϙbϙFƅîϙôťϠϙôŘıϙħŘϙϼ͒ϱΫЋϠϙ͘ϟ͑ϭϙ«ÍıϙĺŕϙϙƄϙϽϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜ bi(ϡϙϙaĖîϱ(īôıôĲťϙŕīÍĲĲôîϙťĺϙæôϙŜôťϙѷ͖͓͑͐ϱċťϙa"ϙϼ˕Ϸċťϟa"ϟťĺϟiϟѷϟ͖͗͝ϷċťϽ ċϽ ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙ«ÍıϙĺŕϙƄϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ((ϙ͗ŘîϙƄϱĺŽôŘ ČϽ ͐ϙĤťϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙťæČ ēϽ ͒ϱΫЋϙŜīĖîĖĲČϙŜīôôŽôϠϙ͘ŘϙϙĺŘϙ³ϙϼ͑ϟ͗͐͒Ћϙ³ϱŕŘĺƱīôϠϙ"iϽϠϙϙƄϙϙſϯϙ͐͏ϱċťϙƄϱĺŽôŘϙēÍĲîīĖĲČϙ ŕŪŕŜ bi(ϡϙϙŪĲϙŜīĖîĖĲČϙŜīôôŽôϙĖĲϙ[i("ϙŕĺŜĖťĖĺĲ ĖϽ ³³³ϙĤťŜϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙťĺϙŜŪŘċÍèô ĤϽ ͒ϱΫЋϠϙ͘ϟ͑ϭϙV>(ϙôÍŘϙƄϱĺŽôŘϙťĺϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ((ϙ͗ŘîϙťĺϙıÍħôϙŪŕϙťĺϙťæČϙēČŘ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ͐͑Ͻ IFϙťĺϙīĺèÍťôϙťæČϙŜťŪæϙϼѷ͖͔͔͑ϱċťϙa"ϽϙſϯϙĺĺŘϙĺƅϙiŽôŘŜēĺťċťôŘϙīĺèÍťĖĲČϙťæČϙŜťŪæϙŕĖèħϙæÍèħϙŪŕϙťĺϙ ƱČŪŘôϙŜŪŘċÍèôϙŜŕÍèôϙĺŪť ͐͒Ͻ ĖŘèŪīÍťôϙēĺīôϙŽĺīŪıôϙϼѷ͔͔͑ϙææīŜϽϙťĺϙŘôϱèĺĲîĖťĖĺĲϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®> ͓͐Ͻ aϙťæČϙēČŘϙÍĲîϙīÍĲîϙťæČϙēČŘϟ ͔͐Ͻ I["ϙÍĲîϙīÍƅϙîĺſĲϙīÍĲîĖĲČϙĤťϟϙϙbĺťôϙϙÍĲîϙiϙſťŜϙĺĲϙťÍīīƅϟ ͕͐Ͻ ôŜťϙŕÍèħĺƯŜϙťĺϙ͔͏͏ϙŕŜĖϙ[ĺſϙϯϙ͔͏͏͏ϙŕŜĖϙFĖČē ͖͐Ͻ ôťϙ«ϙÍĲîϙıĺŽôϙϙĺƯϙťēôϙſôīī ĺŜťϱĖČϙŘĺèôîŪŘôϡ ͐Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ "ϙıŪîϙæĺÍťϙÍĲîϙi(ϙēĺŪŜôϟϙϙaĺŽôϙťĺϙĲôƄťϙſôīīϙīĺèÍťĖĺĲϟ æϽ ϙŘÍĲôϙÍĲîϙb"ϙi( èϽ bϙ͒ϱ͐ϯ͗Ћϙ͔aϙťŘôôϟϙϙôŜťϙŽĺĖîϙťĺϙ͔͏͏ϙŕŜĖϙ[ĺſϙϯϙ͔͏͏͏ϙŕŜĖϙFĖČēϟϙϙŪīīϙ«ϟ îϽ "ϙèŘÍĲôϟϙϙaĺŽôϙ͔͏͏ϙææīϙŘôťŪŘĲŜϙťÍĲħϙÍĲîϙŘĖČϙıÍťŜϙťĺϙĲôƄťϙſôīīϙīĺèÍťĖĺĲϟ ͑Ͻ >ŪīīæĺŘô ÍϽ ϙťĺϙŕŪıŕϙîĺſĲϙIϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙťæČ æϽ "ĖŜŕīÍèôϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϙċŘĺıϙIϙſϯϙѷ͓͐͏ϙææīŜϙ͗ϟ͔ϭϙIϙŜĺŪŘèôϙſťŘϙċĺīīĺſôîϙæƅϙѷ͔͒ϙ ææīϙîĖôŜôīϙ>ϙťēŘĺŪČēϙĺŘťôîϙŪæϙÍæĺŽôϙĺĺŘϙĺƅϙiŽôŘŜēĺť bi(ϡϙϙ(ĲŜŪŘôϙîĖŜŕīÍèôıôĲťϙŘÍťôϙĖŜϙѴ͓ϙæŕıϙϼ͔͐͏ϙċťϯıĖĲϙĖĲϙťēôϙ͖ЋϙƄϙ͓ϱΫЋϙĲĲŪīŪŜϽϙťĺϙıĖĲĖıĖƏôϙ ťēôϙŕĺŜŜĖæĖīĖťƅϙĺċϙîÍıÍČĖĲČϙťēôϙŕħŘϙôīôıôĲťŜϟϙϙIϙ«ĺīϙϼѷ͐͑͘ϙææīŜϽϟ ͒Ͻ ĺĖīôîϙŪæĖĲČ ÍϽ aIϙϙŪĲĖťϙÍĲîϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲť æϽ ϙi(ϙŕôŘϙôŘŽĖèôϙĺĖīϙ®ôôħīƅϙiϙŘĺèôîŪŘôŜ ĖϽ bĺϙi@ϙĲĺťĖƱèÍťĖĺĲϙŘôŗŪĖŘôî ĖĖϽ ôèĺŘîϙi(ϙťôŜťϙŘôŜŪīťŜϙĺĲϙ͐͏ϱ͓͓͑ ĖĖĖϽ IċϙſĖťēĖĲϙťēôϙŜťÍĲîÍŘîϙ͖ϱîÍƅϙi(ϙťôŜťϙŕôŘĖĺîϠϙÍϙċŪīīϙæĺîƅϙťôŜťϙÍĲîϙċŪĲèťĖĺĲÍīϙťôŜťϙĺċϙťēôϙ ŘÍıŜϙĖŜϙŜŪƯĖèĖôĲťϙťĺϙıôôťϙŘôŗŪĖŘôıôĲťŜ èϽ aϙVbϙFϙÍĲîϙIFϙèĖŘèŪīÍťĖĲČϙ͗ϟ͔ϭϙŜĺŪŘèôϙſťŘϙťēŘŪϙťēôϙĲĺƏƏīôϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙϙ ƄϙϙÍĲĲŪīŪŜ bi(ϡϙϙaĖĲϙI"ϙĺĲϙŜťÍèħϙŕħŘϙŘôϱèĺıŕīôťĖĺĲϙŜēĺŪīîϙæôϙ͑ϟ͗͐͒ϱĖĲϙæŪťϙèēôèħϙťÍīīƅϙċĺŘϙ èĺĲƱŘıÍťĖĺĲ îϽ ϯĺŪťϙ͐͒ϟ͒ϭϙæÍŘĖťôϙıŪîϙſϯϙ͗ϟ͔ϭϙŜĺŪŘèôϙſťŘϙÍīīϙťēôϙſÍƅϙťĺϙťēôϙ³ϙŕīŪČϙŜôťϙĖĲϙťēôϙ³ϱĲĖŕŕīôϙ ŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" ôϽ ĖŘèϙ͐ƄϙϙÍťϙıÍƄϙŘÍťôϙϼϙƄϙIϙŽĺīϙѱϙѷ͔͏ϙææīŜϽ ċϽ iiFϙſēĖīôϙèĺĲťĖĲŪĖĲČϙĺŽôŘϙîĖŜŕīÍèôıôĲťϙĺċϙŽĺĖîÍČô ČϽ "aiϙ ͓Ͻ īĖèħīĖĲô ÍϽ IFϙſϯϙ³ϙŕīŪČϙťĺϙŜôťϙĖĲϙ³ϱĲĖŕŕīôϙŕŘĺƱīôϙĤŪŜťϙæôīĺſϙĲôſϙŜťÍèħϙŕħŘ æϽ iĲèôϙ³ϙŕīŪČϙĖŜϙèĺĲƱŘıôîϙĺĲϙŜôÍťϠϙŕŘôŜŜŪŘôϙŪŕϙťēôϙťæČϙťĺϙŜôťϙŕħŘϙŕôŘϙŽôĲîĺŘϙŕŘĺèôîŪŘôŜ èϽ īôôîϙŕħŘϙŜôťťĖĲČϙŕŘôŜŜŪŘôϙĺƯϙťæČ îϽ ôŘċĺŘıϙaIϱϙϼ͕͔͒͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲϙèēÍŘťôîϽ ôϽ īôôîϙaIϱϙŕŘôŜŜŪŘôϙĺƯϙĺċϙťæČ ċϽ ĲŜôÍťϙ³ϙīŪČ ČϽ ôŘċĺŘıϙaIϱƄIϙϼ͕͔͒͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲŜϙèēÍŘťôîϽϙıĺĲĖťĺŘĖĲČϙťæČϙċĺŘϙŕŘôŜŜŪŘô ēϽ ŕĺĲϙèĺıŕīôťĖĺĲϙĺċϙŜŪèèôŜŜċŪīϙťôŜťĖĲČϠϙiiFϙſϯϙ³ϙīŪČ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ĖϽ IFϙťĺϙŘôťŘĖôŽôϙèÍťèēôŘϙċŘĺıϙÍťĺŕϙ³ϙŕīŪČϙĖĲϙŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" ĤϽ IFϙťĺϙŕŪīīϙ³ϙŕīŪČϙċŘĺıϙŜÍıô bi(ϡϙϙŘôŜŜŪŘôϙŪŕϙťæČϙťĺϙѷ͖͔͐͏ϙŕŜĖϙæôċĺŘôϙŕŪīīĖĲČϙťēôϙŕīŪČϙŜĺϙÍŜϙıĖĲĖıĖƏôϙˏϙÍèŘĺŜŜϙťēôϙŕīŪČ ħϽ ŪŘĲϙſôīīϙĺŽôŘϙťĺϙiŕŜϙċĺŘϙiI ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè _____________________________________________________________________________________ Revised By: TDF 5/28/2024 SCHEMATIC Milne Point Unit Well: MPU C-39 Last Completed: 1/29/1998 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80/ EUE 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 2,240’ X Nipple:Min ID = 3.813” 2 7,272’ X Nipple:Min ID = 3.813” 3 7,283’ 7” Baker Packer 4 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 5 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 6 7,465’ Baker Anchor Seal Assy 7 7,467’ 7” Baker S Packer 8 7,484’ XN Nipple W/ 2.75 No Go 9 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’(MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 2 4 9-5/8” 1 5 3 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 6&7 8 9 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E– 1/29/1998 _____________________________________________________________________________________ Revised By: TDF 5/29/2024 PROPOSED Milne Point Unit Well: MPU C-39 Last Completed: 1/29/1998 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80/ JFE Bear 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Sliding Sleeve 2 ±7,214’ Packer 3 ±X,XXX’ X Nipple: Min ID = 2.812” 3 ±X,XXX’ Overshot 4 7,283’ 7” Baker Packer 5 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 6 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 7 7,465’ Baker Anchor Seal Assy 8 7,467’ 7” Baker S Packer 9 7,484’ XN Nipple W/ 2.75 No Go 10 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’(MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 3 6 9-5/8” 2 7 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ Tubing Cut @ ±7,277’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 8 9 10 4 1 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E– 1/29/1998 Updated 1/21/2025 11” BOPE Shaffer 11'’-5000 3-1/2" Pipe CIW-U 4.30'Hydril GK 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual Milne Point ASR 11” BOP (Triple) 1/21/2022 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Tubing Cut Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Complete 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,922'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Erik Nelson Contact Email:Erik.Nelson@hilcorp.com Contact Phone:907-564-5277 Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT C-39 MILNE POINT KUPARUK RIVER OIL N/A 7,537' 7,796' 7,420' 4,145 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/30/2025 Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 197-248 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22849-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 112' 112' 9.3 / L-80/ EUE TVD Burst 7,497' MD 7,854' N/A 5,750psi 7,240psi 4,674' 7,502' 4,821' 7,884' See Schematic See Schematic 3-1/2" 7" Baker & 7" Bakler S and N/A 7,283 MD/ 6,947 TVD & 7,467 MD/ 7,116 TVD and N/A 79' 20" 9-5/8" 7" 4,790' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:09 am, Jan 22, 2025 325-023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.01.22 09:49:09 - 09'00' Taylor Wellman (2143) DSR-1/22/25A.Dewhurst 23JAN25JJL 1/23/25 10-404X AOGCC witnessed BOP Test to 4500 psi, Annular Test to a minimum of 2500 psi. AOGCC witnessed post-initial injection MITIA X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.24 14:51:58 -09'00'01/24/25 RBDMS JSB 012925 ®ôīīϙbÍıôϡ aϙϱ͒͘IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ ŪŘŘôĲťϙťÍťŪŜϡ ®ťŘϙiĲīƅϙIĲĤ ĖČϡ (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͒͏ϙVÍĲϙ͑͏͔͑(ŜťĖıÍťôîϙ"ŪŘÍťĖĺĲϡ ͔ϙ"ÍƅŜ ôČŪīÍťĺŘƅϙĺĲťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͖͐͘ϱ͓͑͗ >ĖŘŜťϙÍīīϙ(ĲČĖĲôôŘϡ (ŘĖħϙϟϙbôīŜĺĲ ϼ͘͏͖Ͻϙ͔͕͓ϙϳϙ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϙϳϙ͖͓͏͖ϙϼϽ ôèĺĲîϙÍīīϙ(ĲČĖĲôôŘϡ ÍƅīĺŘϙ®ôīīıÍĲ ϼ͘͏͖Ͻϙ͖͖͖ϙϳϙ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϙϳϙ͔͒͒͘ϙϼϽ ŪŘŘôĲťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϙϼFϽϡ ͓͓͕͗ϙŕŜĖϙЬϙiϙ͖͓͒͑ϱċťϙa"ϙϼ͖͏͏͔ϱċťϙ«"Ͻ ŜĖĲČϟIϟĺċϟ͖͚͕͜ϟŕŜĖϟЂ͖͛ϟVÍĲϟ͕͚͗͗ЃϟÍĲîϟ͝ϥ͚ϳϟƲŪĖî ͕͐ϙVÍĲϙ͑͏͔͑ϙиϙ͐͒ϟ͒ϙ(a®ϙϼ͐͒ϟ͔ϙX®>Ͻ aÍƄϙĺťôĲťĖÍīϙŪŘċÍèôϙŘôŜŜŪŘôϙϼaϽϡ ͓͓͔͐ϙŕŜĖ @ÍŜϙĺīŪıĲϙ@ŘÍîĖôĲťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙ"ôŽĖÍťĖĺĲϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͓͑ϟ͖еϙЬϙ͓͘͏͏ϱċťϙa" aÍƄϙ"ĺČīôČϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϯ®iϽϡ ͒ϟ͑еϯ͐͏͏ϱċťϙЬϙ͕͓͐͑ϱċťϙa" aĖĲϙI"ϙϼŘôīÍťĖŽôϙťĺϙ®ôīīſĺŘħϽϡ ͑ϟ͖͔͏ϱĖĲϙ³bϙbĖŕŕīôϙÍťϙ͖͓͓͗ϱċťϙa" Xϡ ͓͑ϟ͗͗ϱċťϙϼbÍæĺŘŜϙ͑͑(Ͻ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙϱ͒͘ϙſÍŜϙîŘĖīīôîϙĖĲϙ"ôèôıæôŘϙ͐͗͘͘ϙÍŜϙÍϙŽôŘťĖèÍīϙXŪŕÍŘŪħϙĖĲĤôèťĺŘϟϙϙƄIϙèĺııŪĲĖèÍťĖĺĲϙĺĲϙČÍŜϙēÍŜϙ æôôĲϙĲĺťôîϙıŪīťĖŕīôϙťĖıôŜϙŜĖĲèôϙťēôĲϙſĖťēϙťēôϙīÍťôŜťϙæôĖĲČϙi@ЍŜϙîıĖĲĖŜťŘÍťĖŽôϙŕŕŘĺŽÍīϙϼIiϱ͑͒ϱ͏͐͒Ͻϙ ČŘÍĲťĖĲČϠϙŜŪæĤôèťϙťĺϙèĺĲîĖťĖĺĲŜϠϙFĖīèĺŘŕЍŜϙŘôŗŪôŜťϙťĺϙèĺĲťĖĲŪôϙſÍťôŘϙĺĲīƅϙĖĲĤôèťĖĺĲϟϙϙēôϙſôīīϙēÍŜϙæôôĲϙĺĲϙ ſÍťôŘϱĺĲīƅϙĖĲĤôèťĖĺĲϙŜĖĲèôϙťēÍťϙÍŕŕŘĺŽÍīϙîÍťôîϙ͓͐ϙVŪĲôϙ͑͏͑͒ϟ bĺťôŜϙôČÍŘîĖĲČϙ®ôīīæĺŘôϙĺĲîĖťĖĺĲϡ -aIϱIϙťĺϙ͔͑͐͏ϙŕŜĖϙŕÍŜŜôîϙϼi@ϙſĖťĲôŜŜϽϙĺĲϙ͏͓ϙôŕϙ͑͏͑͒ -aIϱIϙťĺϙ͓͕͖͏ϙŕŜĖϙŕÍŜŜôîϙϼbĺĲϱi@ϙſĖťĲôŜŜϽϙŕÍŜŜôîϙĺĲϙ͏͑ϙVÍĲϙ͑͏͑͒ -æČϙFČŘϙiϙŕÍŜŜôîϙťĺϙ͔͏͏͏ϙŕŜĖϙ͑͒ϙ"ôèϙ͑͏͑͑ -͐ϱΫЋϙĖŘèϙ«ÍīŽôŜϙŜôťϙĖĲϙÍıèĺϙaa@ϱ͑ϙ@[aŜϙĺĲϙ͏͐ϙaÍŘϙ͐͗͘͘ -IϙīĺČϙŕŪīīôîϙ͐͗ϙVÍĲϙ͐͗͘͘ϟϙϙiϙèÍīīôîϙÍťϙѷ͔͏͏͏ϱċťϙa"ϟϙϙ@ĺĺîϙèĺĲťĖĲŪĺŪŜϙèôıôĲťϙċŘĺıϙѷ͕͏͏͏ϱċťϙ a"ϙťĺϙ͖͖͏͏ϱċťϙa"ϟ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ iæĤôèťĖŽôϡ ®ĖťēϙťēĖŜϙŕŕīĖèÍťĖĺĲϙċĺŘϙŪĲîŘƅϙŕŕŘĺŽÍīϙſôϙÍŘôϙŘôŗŪôŜťĖĲČϙťĺϙŕŪťϙϙĺĲϙaϙϱ͒͘ϙťĺϙŕôŘċĺŘıϙÍϙťŪæĖĲČϙ ŜſÍŕϙťĺϙŘôŜťĺŘôϙĖĲťôČŘĖťƅϟϙϙ®ĖťēϙċĺīīĺſϱŪŕϙaIŜϙťēĖŜϙŜēĺŪīîϙÍīīĺſϙċĺŘϙťēĖŜϙſôīīϙťĺϙæôϙŕŪťϙæÍèħϙťĺϙ®@ϙĖĲĤôèťĖĺĲϙ ŜôŘŽĖèôϟ ēĖŜϙŕŘĺèôîŪŘôϙîôťÍĖīŜϙťēôϙæôīĺſϙĺŪťīĖĲôϙĺċϙťēôϙŜèĺŕôϙĺċϙťēĖŜϙŕŘĺĤôèťϡ -Řôϱ®iϙſôīīſĺŘħϙťĺϙŕŘôŕϙÍĲîϙŜôèŪŘôϙſôīī -ŪīīϙôƄĖŜťĖĲČϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ((ϙ͗ŘîϙťæČ -ŪĲϙĲôſϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙŜťÍèħϙŕÍèħôŘϙèĺıŕīôťĖĺĲ -ôťŪŘĲϙſôīīϙťĺϙ®@ϙIĲĤôèťĖĺĲ ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼbĺĲϱŪĲîŘĖôîϙ®ĺŘħϽϡ ͐Ͻ īĖèħīĖĲô ÍϽ "ŘĖċťϙċĺŘϙæČϙŪťťôŘϙϼ͑ϟ͖͔͒ϱĖĲϽϙťĺϙ͖͓͔͏ϱċťϙa" æϽ iæťÍĖĲϙŪŕîÍťôîϙFϙſĖťēϙ͐͏ϱıĖĲϙŜťĺŕϙÍťϙ͖͓͔͏ϱċťϙa"ϙϼ͖͐͏͏ϱċťϙ«"Ͻϙſϯϙ͔ϱıĖĲϙČŘÍîĖôĲťϙŜťĺŕϙ Íťϙ͖͑͒͐ϱċťϙa"ϙϼ͕͘͏͏ϱċťϙ«"ϽϙÍĲîϙ͕͖͘͘ϱċťϙa"ϙϼ͕͔͏͏ϱċťϙ«"Ͻ èϽ ôťϙ³ϙŕīŪČϙÍĲîϙèÍťèēôŘϙĖĲϙ͑ϟ͖͔ϙЌ³ЍϙĲĖŕŕīôϙŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" îϽ ϙťæČϙťĺϙ͔͒͏͏ϙŕŜĖϙťĺϙôĲŜŪŘôϙŕīŪČϙĖŜϙŜôÍťôîϙĖĲϙŕŘĺƱīô ŘôϱĖČϙiŕôŘÍťĖĺĲŜϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ ͑Ͻ (ϱ[ĖĲô ÍϽ ŪťϙťæČϙѷ͖͔͔͑ϱċťϙa"ϙϼıĖîϱĤťϙĖĲϙ͐ ŜťϙċŪīīϙĤťϙÍæĺŽôϙÍħôŘϙaĺîôīϙϱ͒ϙŕħŘϙϼťıϯĺŕϙϳϙѷ͖͖͑͐ϯѷ͖͓͑͏ϱ ċťϙa"ϽϽ bi(ϡϙϙFÍŽôϙŕŪıŕϙÍŽÍĖīÍæīôϙĺĲϙīĺèÍťĖĺĲϙťĺϙîôťôŘıĖĲôϙĺŪŘϙÍæĖīĖťƅϙťĺϙèĖŘèŪīÍťôϙÍċťôŘϙťēôϙťæČϙèŪťϟϙϙIċϙ èĖŘèŪīÍťĖĺĲϙŘÍťôŜϙÍŘôϙĖĲŜŪƯĖèĖôĲťϠϙaϙťæČϙŕŪĲèēϙÍĲîϙŕŪĲèēϙÍæĺŽôϙťæČϙèŪťϙſēĖīôϙ(ϱ[ĖĲôϙĖŜϙŜťĖīīϙĺĲϙ īĺèÍťĖĺĲϟ ͒Ͻ >ŪīīæĺŘô ÍϽ īôôîϙæČϯIϙťĺϙ͏ϙŕŜĖ æϽ ĖŘèŪīÍťôϙťēôϙſôīīϙĺŽôŘϙťĺϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϙîĺſĲϙťēôϙťæČϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙ ťēŘĺŪČēϙťēôϙťæČϙèŪť bi(ϡϙϙæČϙ«ĺīϙϼѷ͕͓ϙææīŜϽϙϯϙIϙ«ĺīϙϼѷ͐͑͘ϙææīŜϽϟϙϙIċϙ>ϙĲôôîŜϙťĺϙæôϙŕīÍèôîϙĖĲϙſôīīϙÍèèĺŘîĖĲČϙťĺϙ ЍŜϙÍŘŘĖŽÍīϠϙèĺĲťÍèťϙi(ϙċĺŘϙÍîĤŪŜťôîϙX®>ϟϙϙ®ôϙĲôôîϙťĺϙèĖŘèŪīÍťôϙťēôϙſôīīϙħĖīīϙÍŜϙèīĺŜôϙÍŜϙ ŕĺŜŜĖæīôϙťĺϙЍŜϙÍŘŘĖŽÍīϙîŪôϙťĺϙťēôϙŕĺťôĲťĖÍīϙċĺŘϙæÍŘĖťôϙŜÍČϙſĖťēϙťēĖŜϙX®>ϙŜƅŜťôıϟ ͓Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ īôÍŘϙÍĲîϙīôŽôīϙŕÍîϙÍŘôÍϙĖĲϙċŘĺĲťϙĺċϙſôīīϟϙϙŕĺťϙŘĖČϙıÍťŜϠϙ͔͏͏ϙææīϙťÍĲħϠϙÍĲîϙèĺĲťÍĖĲıôĲťϟ æϽ "ϙſôīīϙēĺŪŜôϙÍĲîϙƲĺſīĖĲôŜϟϙϙīôÍŘϙÍĲîϙīôŽôīϙÍŘôÍϙÍŘĺŪĲîϙſôīīϟ èϽ aIϙèŘÍĲôϟϙϙôťϙ«ϟϙϙb"ϙťŘôôϙÍĲîϙbϙ͐͐Ћϙi(ϙŘĖŕīôϙťÍèħϙϼīĖĲîŜϙϯϙ͑ϱ͖ϯ͗ЋϙƄϙ͔Ћϙ«ϙϯϙ͒ϱ ΫЋϙĖŕôϙϯϙĲĲŪīÍŘϽϟϙϙbϙi(ϙēĺŪŜôϟϙϙŕĺťϙıŪîϙæĺÍťϟ bi(ϡϙϙ«ϙŕŘĺƱīôϙĖŜϙ͒ЋϙI® ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ®iϙŘĺèôîŪŘôϙϼŪĲîŘĖôîϙ®ĺŘħϽϡ aIϙϯϙôŜťϙi(ϡ ͐Ͻ aIϙFĖīèĺŘŕϙϠϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲťϠϙÍĲîϙīĖĲôŜϙťĺϙ͔͏͏ϙææīϙŘôťŪŘĲϙťÍĲħ ͑Ͻ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍĲîϙĖċϙ͏ϙŕŜĖϠϙŜôťϙϙŕīŪČϟϙϙIċϙĲôôîôîϠϙæīôôîϙÍĲƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺƯϙťæČϙÍĲîϙ èŜČϟϙϙĖŘèŪīÍťôϙ͐͒ϟ͔ϙX®>ϙîĺſĲϙťæČϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙIϙťēŘĺŪČēϙťēôϙťæČϙèŪťϙÍŜϙĲôôîôîϟ ͒Ͻ ôŜťϙi(ϙťĺϙ͓͔͏ϙŕŜĖϙ[ĺſϙϯϙ͓͔͏͏ϙŕŜĖϙFĖČēϠϙÍĲĲŪīÍŘϙťĺϙ͓͔͏ϙŕŜĖϙ[ĺſϙϯϙ͓͔͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèēϙ ŘÍıϯŽÍīŽôϙċĺŘϙ͔ϱıĖĲϽϟϙϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍĲîϙèēÍŘťϙťôŜťŜϟ ÍϽ bĺťĖċƅϙi@ϙ͓͑ϱēŘŜϙĖĲϙÍîŽÍĲèôϙĺċϙi(ϙťôŜťĖĲČ æϽ ĺĲƱŘıϙťôŜťϙŕŘôŜŜŪŘôϙŕôŘϙťēôϙŪĲîŘƅϙĺĲîĖťĖĺĲŜϙĺċϙŕŕŘĺŽÍī èϽ ôŘċĺŘıϙťôŜťŜϙÍŜϙŕôŘϙϙ͐ϙi(ϙôŜťϙŘĺèôîŪŘô îϽ ôŜťϙ«ŜϙĺĲϙ͒ϱΫЋϙϼôƄĖŜťĖĲČϙèĺıŕīôťĖĺĲϠϙſĺŘħŜťŘĖĲČϠϙÍĲîϙĲôſϙèĺıŕīôťĖĺĲϽϙťôŜťϙĤťϟϙϙôŜťϙĖŕôϙ ÍıŜϙĺĲϙ͒ϱΫЋϙťôŜťϙĤťϟ ôϽ ŪæıĖťϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙťĺϙi@ϙſĖťēĖĲϙϼ͔ϽϙîÍƅŜϙĺċϙi(ϙťôŜť ͓Ͻ ŪīīϙϙīŪČϟϙϙīôôîϙÍĲƅϙŕŘôŜŜŪŘôϙĺƯϙťæČϯIϙťĺϙťēôϙŘôťŪŘĲŜϙťÍĲħϟϙϙIċϙŘôŗЍîϠϙèĖŘèŪīÍťôϙÍîîĖťĖĺĲÍīϙ ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϟϙϙŪīīϙ«ϟϙϙ[ŪæŘĖèÍťôϙĖċϙŕŘôŜŜŪŘôϙĖŜϙôƄŕôèťôîϟ ŪīīϙŘĺîϙæČϡ ͔Ͻ aϙīÍĲîĖĲČϙĤťϙĺŘϙŜŕôÍŘϙÍĲîϙŪĲīÍĲîϙťæČϙēČŘ ͕Ͻ īĺŜôϙæÍČϙÍĲîϙèĖŘèŪīÍťôϙēĺīôϙŽĺīŪıôϙϼѷ͔͔͑ϙææīŜϽϙťĺϙŘôϱèĺĲîĖťĖĺĲϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®> ͖Ͻ ôèĺŽôŘϙťæČϙēČŘ ͗Ͻ aĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſ ͘Ͻ iiFϙīÍƅĖĲČϙîĺſĲϙôƄĖŜťĖĲČϙ͒ϱΫЋϠϙ͘ϟ͒ϭϠϙ[͗͏ϙ((ϙ͗ŘîϙťæČϙıÍĖĲťÍĖĲĖĲČϙēĺīôϙƱīīϙŕôŘϙťæČϙ îĖŜŕīÍèôıôĲťϟϙϙ®ÍŜēϙÍĲîϙťŘÍŜēϙÍīīϙĤťŜϙÍĲîϙĤôſôīŘƅϟ bi(ϡϙϙbĺϙŘôèĺŘîϙĺċϙ®ϙĺŘϙi®ϙċŘĺıϙbÍæĺŘŜϙ͑͑(ϙ ͐͏Ͻ bĺťôϙèĺĲîĖťĖĺĲϙĺċϙŕŘôϱ®iϙťæČϙèŪťϟϙϙaĺĲĖťĺŘϙſôīīϙċĺŘϙƲĺſϟ ŪĲϙ͒ϱΫЋϙťÍèħϙħŘϙôϱĺıŕīôťĖĺĲϡ ͐͐Ͻ aϙÍĲîϙIFϙſϯϙĲôſϙ®@ϙIĲĤϙèĺıŕīôťĖĺĲϡ ÍϽ ĺĺŘϙĺƅϙiŽôŘŜēĺťϙĺŘϙŜĖıĖīÍŘϙϼſϯϙťÍťťīôϙťÍīôϙŜēôÍŘϙŕĖĲŜϽϙŜôťŪŕϙċĺŘϙѷ͐͏ϱċťϙŜſÍīīĺſϙĺĲϙ͒ϱΫЋϙťæČϙ æôċĺŘôϙĲĺϱČĺϟ æϽ ĺŘťôîϙŪæ èϽ ͒ϱΫЋϙЌ³ЍϙĲĖŕŕīôϙŕŘĺƱīôϙϼ͑ϟ͗͐͒ГϙĺŘôϽϠϙ͘ϟ͒ϭϠϙ[͗͏ϙ((ϙ͗ŘîϠϙϙƄϙϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜ îϽ ͒ϱΫЋϠϙ͘ϟ͒ϭϙ[͗͏ϙ((ϙ͗ŘîϙŕĖĲϙƄϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙ«ÍıϙĺŕϙƄϱĺŽôŘ ôϽ ͖ЋϙƄϙ͒ϱΫЋϙF(ϙbϙFƅîϙôťϠϙôŘıϙħŘϙϼ͒ϱΫЋϠϙ͘ϟ͑ϭϙ«ÍıϙĺŕϙϙƄϙϽϙſϯϙ͐͏ϱċťϙēÍĲîīĖĲČϙŕŪŕŜ bi(ϡϙϙaĖîϱ(īôıôĲťϙŕīÍĲĲôîϙťĺϙæôϙŜôťϙѷ͖͓͑͐ϱċťϙa"ϙϼ˕Ϸċťϟa"ϟťĺϟiϟѷϟ͖͗͝ϷċťϽ ċϽ ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙ«ÍıϙĺŕϙƄϙ͓ϱΫЋϠϙ͐͑ϟ͕ϭϙ[͗͏ϙ((ϙ͗ŘîϙƄϱĺŽôŘ ČϽ ͐ϙĤťϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙťæČ ēϽ ͒ϱΫЋϙŜīĖîĖĲČϙŜīôôŽôϠϙ͘ŘϙϙĺŘϙ³ϙϼ͑ϟ͗͐͒Ћϙ³ϱŕŘĺƱīôϠϙ"iϽϠϙϙƄϙϙſϯϙ͐͏ϱċťϙƄϱĺŽôŘϙēÍĲîīĖĲČϙ ŕŪŕŜ bi(ϡϙϙŪĲϙŜīĖîĖĲČϙŜīôôŽôϙĖĲϙ[i("ϙŕĺŜĖťĖĺĲ ĖϽ ³³³ϙĤťŜϙ͒ϱΫЋϠϙ͘ϟ͑ϭϙ[͗͏ϙV>(ϙôÍŘϙťĺϙŜŪŘċÍèô ĤϽ ͒ϱΫЋϠϙ͘ϟ͑ϭϙV>(ϙôÍŘϙƄϱĺŽôŘϙťĺϙ͒ϱΫЋϠϙ͘ϟ͒ϭϙ((ϙ͗ŘîϙťĺϙıÍħôϙŪŕϙťĺϙťæČϙēČŘ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ͐͑Ͻ IFϙťĺϙīĺèÍťôϙťæČϙŜťŪæϙϼѷ͖͔͔͑ϱċťϙa"ϽϙſϯϙĺĺŘϙĺƅϙiŽôŘŜēĺťċťôŘϙīĺèÍťĖĲČϙťæČϙŜťŪæϙŕĖèħϙæÍèħϙŪŕϙťĺϙ ƱČŪŘôϙŜŪŘċÍèôϙŜŕÍèôϙĺŪť ͐͒Ͻ ĖŘèŪīÍťôϙēĺīôϙŽĺīŪıôϙϼѷ͔͔͑ϙææīŜϽϙťĺϙŘôϱèĺĲîĖťĖĺĲϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®> ͓͐Ͻ aϙťæČϙēČŘϙÍĲîϙīÍĲîϙťæČϙēČŘϟ ͔͐Ͻ I["ϙÍĲîϙīÍƅϙîĺſĲϙīÍĲîĖĲČϙĤťϟϙϙbĺťôϙϙÍĲîϙiϙſťŜϙĺĲϙťÍīīƅϟ ͕͐Ͻ ôŜťϙŕÍèħĺƯŜϙťĺϙ͔͏͏ϙŕŜĖϙ[ĺſϙϯϙ͔͏͏͏ϙŕŜĖϙFĖČē ͖͐Ͻ ôťϙ«ϙÍĲîϙıĺŽôϙϙĺƯϙťēôϙſôīī ĺŜťϱĖČϙŘĺèôîŪŘôϡ ͐Ͻ ®ôīīϙŪŕŕĺŘť ÍϽ "ϙıŪîϙæĺÍťϙÍĲîϙi(ϙēĺŪŜôϟϙϙaĺŽôϙťĺϙĲôƄťϙſôīīϙīĺèÍťĖĺĲϟ æϽ ϙŘÍĲôϙÍĲîϙb"ϙi( èϽ bϙ͒ϱ͐ϯ͗Ћϙ͔aϙťŘôôϟϙϙôŜťϙŽĺĖîϙťĺϙ͔͏͏ϙŕŜĖϙ[ĺſϙϯϙ͔͏͏͏ϙŕŜĖϙFĖČēϟϙϙŪīīϙ«ϟ îϽ "ϙèŘÍĲôϟϙϙaĺŽôϙ͔͏͏ϙææīϙŘôťŪŘĲŜϙťÍĲħϙÍĲîϙŘĖČϙıÍťŜϙťĺϙĲôƄťϙſôīīϙīĺèÍťĖĺĲϟ ͑Ͻ >ŪīīæĺŘô ÍϽ ϙťĺϙŕŪıŕϙîĺſĲϙIϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙťæČ æϽ "ĖŜŕīÍèôϙ͐͒ϟ͔ϭϙæÍŘĖťôϙıŪîϙX®>ϙċŘĺıϙIϙſϯϙѷ͓͐͏ϙææīŜϙ͗ϟ͔ϭϙIϙŜĺŪŘèôϙſťŘϙċĺīīĺſôîϙæƅϙѷ͔͒ϙ ææīϙîĖôŜôīϙ>ϙťēŘĺŪČēϙĺŘťôîϙŪæϙÍæĺŽôϙĺĺŘϙĺƅϙiŽôŘŜēĺť bi(ϡϙϙ(ĲŜŪŘôϙîĖŜŕīÍèôıôĲťϙŘÍťôϙĖŜϙѴ͓ϙæŕıϙϼ͔͐͏ϙċťϯıĖĲϙĖĲϙťēôϙ͖ЋϙƄϙ͓ϱΫЋϙĲĲŪīŪŜϽϙťĺϙıĖĲĖıĖƏôϙ ťēôϙŕĺŜŜĖæĖīĖťƅϙĺċϙîÍıÍČĖĲČϙťēôϙŕħŘϙôīôıôĲťŜϟϙϙIϙ«ĺīϙϼѷ͐͑͘ϙææīŜϽϟ ͒Ͻ ĺĖīôîϙŪæĖĲČ ÍϽ aIϙϙŪĲĖťϙÍĲîϙÍĲèĖīīÍŘƅϙôŗŪĖŕıôĲť æϽ ϙi(ϙŕôŘϙôŘŽĖèôϙĺĖīϙ®ôôħīƅϙiϙŘĺèôîŪŘôŜ ĖϽ bĺϙi@ϙĲĺťĖƱèÍťĖĺĲϙŘôŗŪĖŘôî ĖĖϽ ôèĺŘîϙi(ϙťôŜťϙŘôŜŪīťŜϙĺĲϙ͐͏ϱ͓͓͑ ĖĖĖϽ IċϙſĖťēĖĲϙťēôϙŜťÍĲîÍŘîϙ͖ϱîÍƅϙi(ϙťôŜťϙŕôŘĖĺîϠϙÍϙċŪīīϙæĺîƅϙťôŜťϙÍĲîϙċŪĲèťĖĺĲÍīϙťôŜťϙĺċϙťēôϙ ŘÍıŜϙĖŜϙŜŪƯĖèĖôĲťϙťĺϙıôôťϙŘôŗŪĖŘôıôĲťŜ èϽ aϙVbϙFϙÍĲîϙIFϙèĖŘèŪīÍťĖĲČϙ͗ϟ͔ϭϙŜĺŪŘèôϙſťŘϙťēŘŪϙťēôϙĲĺƏƏīôϙťÍħĖĲČϙŘôťŪŘĲŜϙċŘĺıϙťēôϙϙ ƄϙϙÍĲĲŪīŪŜ bi(ϡϙϙaĖĲϙI"ϙĺĲϙŜťÍèħϙŕħŘϙŘôϱèĺıŕīôťĖĺĲϙŜēĺŪīîϙæôϙ͑ϟ͗͐͒ϱĖĲϙæŪťϙèēôèħϙťÍīīƅϙċĺŘϙ èĺĲƱŘıÍťĖĺĲ îϽ ϯĺŪťϙ͐͒ϟ͒ϭϙæÍŘĖťôϙıŪîϙſϯϙ͗ϟ͔ϭϙŜĺŪŘèôϙſťŘϙÍīīϙťēôϙſÍƅϙťĺϙťēôϙ³ϙŕīŪČϙŜôťϙĖĲϙťēôϙ³ϱĲĖŕŕīôϙ ŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" ôϽ ĖŘèϙ͐ƄϙϙÍťϙıÍƄϙŘÍťôϙϼϙƄϙIϙŽĺīϙѱϙѷ͔͏ϙææīŜϽ ċϽ iiFϙſēĖīôϙèĺĲťĖĲŪĖĲČϙĺŽôŘϙîĖŜŕīÍèôıôĲťϙĺċϙŽĺĖîÍČô ČϽ "aiϙ ͓Ͻ īĖèħīĖĲô ÍϽ IFϙſϯϙ³ϙŕīŪČϙťĺϙŜôťϙĖĲϙ³ϱĲĖŕŕīôϙŕŘĺƱīôϙĤŪŜťϙæôīĺſϙĲôſϙŜťÍèħϙŕħŘ æϽ iĲèôϙ³ϙŕīŪČϙĖŜϙèĺĲƱŘıôîϙĺĲϙŜôÍťϠϙŕŘôŜŜŪŘôϙŪŕϙťēôϙťæČϙťĺϙŜôťϙŕħŘϙŕôŘϙŽôĲîĺŘϙŕŘĺèôîŪŘôŜ èϽ īôôîϙŕħŘϙŜôťťĖĲČϙŕŘôŜŜŪŘôϙĺƯϙťæČ îϽ ôŘċĺŘıϙaIϱϙϼ͕͔͒͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲϙèēÍŘťôîϽ ôϽ īôôîϙaIϱϙŕŘôŜŜŪŘôϙĺƯϙĺċϙťæČ ċϽ ĲŜôÍťϙ³ϙīŪČ ČϽ ôŘċĺŘıϙaIϱƄIϙϼ͕͔͒͏ϙŕŜĖϙϳϙ͒͏ϙıĖĲŜϙèēÍŘťôîϽϙıĺĲĖťĺŘĖĲČϙťæČϙċĺŘϙŕŘôŜŜŪŘô ēϽ ŕĺĲϙèĺıŕīôťĖĺĲϙĺċϙŜŪèèôŜŜċŪīϙťôŜťĖĲČϠϙiiFϙſϯϙ³ϙīŪČ ®ôīīϡ aϙϱ͒͘ "ϡ ͖͐͘ϱ͓͑͗ Iϡ ͔͏ϱ͏͑͘ϱ͓͑͑͗͘ϱ͏͏ϱ͏͏ "Íťôϡ ͑͐ϙVÍĲϙ͑͏͔͑ ĖϽ IFϙťĺϙŘôťŘĖôŽôϙèÍťèēôŘϙċŘĺıϙÍťĺŕϙ³ϙŕīŪČϙĖĲϙŕŘĺƱīôϙÍťϙ͖͖͑͑ϱċťϙa" ĤϽ IFϙťĺϙŕŪīīϙ³ϙŕīŪČϙċŘĺıϙŜÍıô bi(ϡϙϙŘôŜŜŪŘôϙŪŕϙťæČϙťĺϙѷ͖͔͐͏ϙŕŜĖϙæôċĺŘôϙŕŪīīĖĲČϙťēôϙŕīŪČϙŜĺϙÍŜϙıĖĲĖıĖƏôϙˏϙÍèŘĺŜŜϙťēôϙŕīŪČ ħϽ ŪŘĲϙſôīīϙĺŽôŘϙťĺϙiŕŜϙċĺŘϙiI ťťÍèēıôĲťŜϡ ͐Ͻ ŪŘŘôĲťϙ®ôīīæĺŘôϙèēôıÍťĖè ͑Ͻ ŘĺŕĺŜôîϙ®ôīīæĺŘôϙèēôıÍťĖè ͒Ͻ i(ϙèēôıÍťĖè _____________________________________________________________________________________ Revised By: TDF 5/28/2024 SCHEMATIC Milne Point Unit Well: MPU C-39 Last Completed: 1/29/1998 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80/ EUE 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 2,240’ X Nipple:Min ID = 3.813” 2 7,272’ X Nipple:Min ID = 3.813” 3 7,283’ 7” Baker Packer 4 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 5 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 6 7,465’ Baker Anchor Seal Assy 7 7,467’ 7” Baker S Packer 8 7,484’ XN Nipple W/ 2.75 No Go 9 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’(MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 2 4 9-5/8” 1 5 3 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 6&7 8 9 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E– 1/29/1998 _____________________________________________________________________________________ Revised By: TDF 5/29/2024 PROPOSED Milne Point Unit Well: MPU C-39 Last Completed: 1/29/1998 PTD: 197-248 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTS 8.835 Surface 4,821’ 7" Production 26 / L-80 / BTC 6.276 Surface 7,884’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80/ JFE Bear 2.937 Surface 7,497’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Sliding Sleeve 2 ±7,214’ Packer 3 ±X,XXX’ X Nipple: Min ID = 2.812” 3 ±X,XXX’ Overshot 4 7,283’ 7” Baker Packer 5 7,343’ GLM #2: CAMCO MMG-2 W/DVRK Latch 6 7,403’ GLM #1: CAMCO MMG-2 W/DVRK Latch 7 7,465’ Baker Anchor Seal Assy 8 7,467’ 7” Baker S Packer 9 7,484’ XN Nipple W/ 2.75 No Go 10 7,495’ WLEG:Btm @ 7,497’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. ‘C’ Sand 7,342’ 7,350’ 7,005’ 7,012’ 8’ 1/18/1998 Open Kup. ‘B’ Sand 7,435’ 7,445’ 7,089’ 7,098’ 10’ 1/18/1998 Open Kup. ‘A3’ Sand 7,513’ 7,529’ 7,161’ 7,176’ 16’ 1/18/1998 Open Kup. ‘A2’ Sand 7,539’ 7,568’ 7,185’ 7,211’ 29’ 1/18/1998 Open Perf Ref Log: USIT 01/18/98. 3-3/8” SWS 34B HJII RDX Deep Penetrating Jet Charges @ 60 / 120 Deg. Phasing (EHD=0.40”, TTP=21.9 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 1,565 sx PF ‘E’, 240 sx Class ‘G’ in 12-1/4” Hole 7” 255 sx Class G in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 21 to 24 deg. f/ 3,200’ to PBTD Max Hole Angle through perforations = 24 deg. TREE & WELLHEAD Tree 3-1/8” 5M WKM Wellhead 11” x 7-1/16” 5M FMC Gen 5A. Tbg Hng NSCT 4” CIW H BPV Profile Tbg. Hng. 7-1/16” x 3.5” FMC, 4.25” Acme lift Threads x 3.5” EUE btm, 3” CIW ‘H’ BPV Profile. TD = 7,922’(MD) / TD = 7,537’(TVD) 20” Orig. KB Elev.: 46.10’ / Orig. GL Elev.= 16.6’ RT to tbg. Hng.= 24.88’ (Nabors 22E) 7” 3 6 9-5/8” 2 7 5 9-5/8” HOWCO ‘ES’ Cementer @ 2,189’ Tubing Cut @ ±7,277’ PBTD = 7,796’ (MD) / PBTD = 7,420’(TVD) 8 9 10 4 1 GENERAL WELL INFO API: 50-029-22849-00-00 Drilled, Cased & Completed by Nabors 22E– 1/29/1998 Updated 1/21/2025 11” BOPE Shaffer 11'’-5000 3-1/2" Pipe CIW-U 4.30'Hydril GK 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual Milne Point ASR 11” BOP (Triple) 1/21/2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, January 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-39 MILNE PT UNIT C-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2024 C-39 50-029-22849-00-00 197-248-0 W SPT 6947 1972480 1737 3188 3189 3191 3190 568 673 674 673 REQVAR P Sully Sullivan 11/27/2023 2 year mit per AIO 10B.020 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:MILNE PT UNIT C-39 Inspection Date: Tubing OA Packer Depth 995 1965 1931 1927IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231130053152 BBL Pumped:1.3 BBL Returned:1.1 Tuesday, January 16, 2024 Page 1 of 1            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: PWI Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC-39) Date:Tuesday, June 20, 2023 8:47:14 AM Attachments:image001.png image002.png From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, June 15, 2023 2:44 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: PWI Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC-39) Mr. Wallace, AA, AIO 10B.020 was approved by AOGCC on 6/14/2023. This well will now be classified as OPERABLE for water injection only. Please respond with any concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, June 1, 2023 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, Per our conversation we will leave this well online as we pursue an AA for PWI only. Thanks, Ryan Thompson Milne/Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, May 4, 2023 10:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) is currently shut in. Per our conversation we will now bring this well onlineUNDER EVALUATION on water injection only and monitor for pressure communication. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi 3. CTU remove ice plug 4. Ops to place well on water injection Please respond with any comments or concerns. Thanks, Ryan Thompson MPU/Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Tuesday, January 31, 2023 12:52 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified asNOT OPERABLE. The well will be re-evaluated at a later time. 5. PPPOT-T Passed 6. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified asUNDER EVALUATIONand is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC-39) Date:Thursday, June 1, 2023 11:05:25 AM Attachments:image001.png image002.png From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, June 1, 2023 10:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, Per our conversation we will leave this well online as we pursue an AA for PWI only. Thanks, Ryan Thompson Milne/Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, May 4, 2023 10:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) is currently shut in. Per our conversation we will now bring this well onlineUNDER EVALUATION on water injection only and monitor for pressure communication. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi 3. CTU remove ice plug 4. Ops to place well on water injection Please respond with any comments or concerns. Thanks, Ryan Thompson MPU/Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Tuesday, January 31, 2023 12:52 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified asNOT OPERABLE. The well will be re-evaluated at a later time. 5. PPPOT-T Passed 6. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified asUNDER EVALUATIONand is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC-39) Date:Thursday, May 4, 2023 11:30:31 AM Attachments:image001.png image002.png From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, May 4, 2023 10:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure (MPC- 39) Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) is currently shut in. Per our conversation we will now bring this well online UNDER EVALUATION on water injection only and monitor for pressure communication. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi 3. CTU remove ice plug 4. Ops to place well on water injection Please respond with any comments or concerns. Thanks, Ryan Thompson MPU/Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Tuesday, January 31, 2023 12:52 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified asNOT OPERABLE. The well will be re-evaluated at a later time. 5. PPPOT-T Passed 6. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified asUNDER EVALUATION and is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 byreturn 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Date:Wednesday, February 15, 2023 4:19:41 PM Attachments:image001.png image002.png From: Wallace, Chris D (OGC) Sent: Wednesday, February 15, 2023 3:46 PM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: RE: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Jerimiah, Your plan to place the well back on water only injection after removing the hydrate plug is approved. For an AA determination, I would need to verify that the previous MITIA was completed with the current integrity issue – or you would need to complete a new MITIA. The MITIA mentioned of January 2, 2023 to 4670 psi hasn’t been entered into our database and I do not have a record to verify if it was witnessed or if witness was waived by AOGCC so that will need to be clarified for any AA. 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: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, February 15, 2023 2:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: FW: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, We have a coil tubing unit heading to this well in the next couple of days to thaw out a hydrate plug. We would like to put the well on water injection immediately after the coil unit leaves to continue evaluation for an AA. 1. Coil Tubing thaw hydrate/ice plug 2. Place well on water injection 3. Evaluate any IA repressurization 4. Submit AA for water only injection What are your thoughts with us proceeding with this plan forward? Thank you, Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, January 31, 2023 12:52 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified as NOT OPERABLE. The well will be re-evaluated at a later time. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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 acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Date:Tuesday, February 7, 2023 9:30:42 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, January 31, 2023 12:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG Injector MPU C-39 (PTD# 197-248) was identified as having TxIA communication while on gas. Initial diagnostics were not able to identify the source of the communication and the evaluation period was extended 14 days to evaluate for a water only Administrative Approval. Due to operational constraints, we are unable to bring the well on injection at this time. The well is now classified as NOT OPERABLE. The well will be re-evaluated at a later time. 1. PPPOT-T Passed 2. MIT-IA Passed to 4670 psi Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 1:42 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPU C-39 (PTD# 197-248) AA Evaluation Date:Tuesday, January 17, 2023 8:28:47 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, January 16, 2023 1:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: MPU C-39 (PTD# 197-248) AA Evaluation Mr. Wallace, I currently have a WAG injector at MPU C-39 (PTD# 197-248). It was place Under Evaluation on 20 December for TxIA communication while injecting gas. After some back and forth with the team here, we would like to pursue an AA for water only injection. On 2 January, we achieved a passing MIT-IA on this well to 4670 psi. I would like to extend the monitoring period for an additional 14 days and have the well placed on water injection to ensure we do not have communication there as well. With the passing pressure test, I do not think it is likely but want to rule it out before I submit an official AA request. I will give you a call tomorrow to follow up (apologies, I remembered today was a holiday after I called). Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 intendedrecipient 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 inerror, 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 messageand 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 asit considers appropriate. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230113 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-39 50029228490000 197248 1/1/2023 HALLIBURTON MFC24 PBU L-114B 50029230320200 222135 12/23/2022 HALLIBURTON RBT PBU W-26B 50029219640200 222151 12/31/2022 HALLIBURTON CAST Please include current contact information if different from above. By Meredith Guhl at 8:44 am, Jan 19, 2023 T37441 T37442 T37443 MPU C-39 50029228490000 197248 1/1/2023 HALLIBURTON MFC24 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.19 09:00:18 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Date:Tuesday, January 10, 2023 9:22:43 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, December 20, 2022 1:42 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector MPU C-39 (PTD# 197-248) Anomalous IA Pressure Mr. Wallace, WAG injector MPU C-39 (PTD# 197-248) was identified as having high inner annulus pressure. On 12/17/2022 the pressure was bled from 1960 psi to 540 psi for diagnostics. The well was bled again after reaching 1960 psi on 12/20/2022. This repressurization indicates possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28 day clock for diagnostics and resolution. The well is to remain online during the evaluation period. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics as required. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor�C� FROM: Adam Earl Petroleum Inspector (Z� -?"D/2'trz4 NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 3, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC C-39 MILNE PT UNIT C-39 Src: Inspector Reviewed By: P.I. Supry -3&0' Comm Well Name MILNE PT UNIT C-39 API Well Number 50-029-22849-00-00 Inspector Name: Adam Earl Permit Number: 197-248-0 Inspection Date: 11/21/2021 Insp Num: mitAGE21 1122161707 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-39 IType Inj W 'TVD 6947 Tubing 1889 1893 1889, 1891- 891PTD PTD1972480 - Type Test SPT Test psi 1737 IA 674 2651 2551 2539 . BBL Pumped: 1.4 BBL Returned: 1.3 - OA 328 392 - 397. 399 Interval 4YRTST p/F P Notes: MIT -IA dice zzz-v ) S 1- 5wcc Friday, December 3, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 07,2016 TO: Jim Regg P.I.Supervisor 1- e-f q. gt1( (l fv SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-39 FROM: Chuck Scheve MILNE PT UNIT KR C-39 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry g. NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-39 API Well Number 50-029-22849-00-00 Inspector Name: Chuck Scheve Permit Number: 197-248-0 Inspection Date: 9/4/2016 Insp Num: mitCS160906110407 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-39 Type Inj W" TVD 6947 - Tubing 2732 2732 2732 2732 PTD 1972480 Type Test[SPT Test psi 1737 IA 725 2290 • 2324 - 2315 Interval i4YRTST P/F P OA 264 370 384 386 - Notes: SCANNED JUN 2 0 2017, Wednesday,September 07,2016 Page 1 of 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 t i_aj.14 December 30, 2011 IMF C, 1 't {, t Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ia!+ h.,'lh�yJ' 333 West 7 Avenue Anchorage, Alaska 99501 rk° 44° Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, r 2 2 Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ ! Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC-09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC -20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 "--Ow MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 RE: MPC-39 (PTD #1972480) N~vidence of TxIA Comm on MI • Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer (NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 21, 2010 10:36 PM To: NSU, ADW Well Integrity Engineer; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: MPU, Well Operations Supervisor; Dittman, Gavin; MPU, Wells Ops Coord; Rupert, C. Ryan Subject: RE: MPC-39 (PTD #1972480) No evidence of TxIA Comm on MI Attachments: MPC-39 TIO and Injection PIot.ZIP Hi Tom and Jim, To follow up on MPC-39 (PTD #1972480), there is no evidence of TxIA communication while on MI injection. Attached is a TIO plot and injection plot. Given there are no indications of integrity concerns, the well has been removed from the Monthly Injection Report. «MPC-39 TIO and Injection PIot.ZIP» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, November 23, 2009 7:59 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Cc: MPU, Well Operations Supervisor; Dittman, Gavin; NSU, ADW Well Integrity Engineer; MPU, Wells Ops Coord Subject: MPC-39 (PTD #1972480) TxIA communication noted in the past when well on gas Hi Tom and Jim, Milne Point well MPC-39 (PTD #1972480) was noted to have TxIA communication while on gas injection in September 2004. Since then the well has been on water injection. Operations placed the well on gas injection yesterday while not being aware of the past history of communication. Given the process to use AOGCC Administrative Approvals to limit the well to water injection only has evolved since the communication was first noted, plans are to leave the well on gas injection and to monitor for TxIA communication. The well will be added to the Monthly Injection Report. Once TxIA communication is observed and confirmed, an AA will be requested and the well returned to water injection. A recent TIO plot and wellbore schematic have been included for reference. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 2/22/2010 • • MPC-39 (PTD #1972480) TIO Plot - .-..~.._....~.~....-.r-. -.- Tt9 i.. u mn -~- o^ ooa noon Dn 1~ 0889109 09/05.Y19 09/12/09 09.'19/09 09/?6/09 10/03/09 10/IOnM 1 10/17!09 a tO8AJ09 1[/31/09 11/0?/09 11!74109 '1817.79 \ ~ l ~ ~ t l..J MPC-39 (PTD #1972480) TIO Plot 4.000 I 3,000 s ~ 2,000 s 1A00 i I 02, MPC-39 (PTD #1972480) Injection Plot 9 500 9,000 8500 8.000 7SG0 7,000 6.500 6.0~ 5,500 a 5,000 4500 -0,000 500 3,000 2,50D 2,OCa 1.500 7,000 500 021 /~`~\~ -~- T6q -f- w oA OOA v OOOA On 1.300 1200 7.100 7.000 ~ 500 e~ $ - LJHIP I sw 700 ~ - MI 6W ~ -- GI o Olhd 500 ~ On 400 300 200 100 MEMORANDUM To~ Jim Regg G~ C~lG G(Z3~c~~ P.I. Supervisor ( G FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, Septemher 16, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-39 MILNE PT UNIT KR C-39 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~ Comm Well Name: MILNE PT UNIT ICR c-39 Insp Num• mitJCr080916074341 Rel Insp Num: API Well Number 50-029-22849-00-00 Permit Number 197-248-0 Inspector Name: John Crisp Inspection Date: 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-39 jType Inj. w I 'I'mo ! 6947 ' I IA ao ~ I I I 1972480 SPT P.T. I TypeTest Test psi 1736.75 O,~ 340 I Interval 4YRTST p~F, 1 Tubing 3zoo j ~ NOteS• 14.7 bbl's pumped in IA to fluid pack. I told the Operator I would not accept or witness MIT until well had stabilized. I requested we drive to NIPU I-08 to perform MIT & return for MIT on C-39. Tuesday, September 16, 2008 Page 1 of 1 MEMORANDUM To: Jim Regg ~~~ ~ ~(2~lUv) P.I. Supervisor FROM: john Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 16, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-39 MILNE PT UNIT KR C-39 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~j~-- Comm Well Name: MILNE PT UNIT KR C-39 Insp Num• mitJCro8o916075522 Rel Insp Num: API Well Number: 50-029-22849-00-00 Permit Number 197-248-0 ., Inspector Name: John Crisp Inspection Date• 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well c-39 jType Inj. ~ `~' TVD 6947 IA 80 3540 ~', 3420 3380 P.T. 1972480 TypeTest SPT TCSt pSl 1736.75 QA 420 810 ~ 790 770 Interval 4YRTST per, P ~ Tubing ~ 3200 3200 j 3200 3200 NOtes• 2.6 bbl's pumped to reach test pressure. Tuesday, September 16, 2008 Page 1 of 1 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 BL / EDE Disk MPU C - 39i Injection Profile 19-5ep-06 1) 2) 3) 4) 5) 6) 7) ", '. rEB '2. 1 '2.0G7 5f~~e.Ð U :LC- /0--:t -;}L/?J 4F It{ DoL¡ P.· ¡"",.- [~E: ~ '\ t...,'v Signed: c,¿L C J/f. r ~ fA ~ l.1:1:JA ,A V.(¿l A î:'"~~ ~ '1l ¡ Lv " 11. Z007 Da~~ 1__ ." Aii"" Uì 5t t:jas 1..:0015. \"¡Oïmm~¡CiJ Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?DSANCHORAGE@MEMOR.fLOG.COM WEBSITE : W1NW.MEMORYLOG.COM D:\Master ~ cOPY- 00 ]DSANC-2OxxIZ _ W ord\Distribution\Transmittal_ Sheets\Transmit_ OriginaLdoc RE: Milne Point Unit- SCP update for the week ending 10/3/04 Subject: RE: Milne Point Unit- SCP update for the week ending 10/3/04 From: "Sauve, Mark A" <mark.sauve@bp.com> Date: Fri, 08 Oct 2004 10:55:25 -0800 To: Thomas Maunder <tom - maunder@arlrn.in.state.ak.us> CC: Jim Regg <jim_regg@adrnin.state.ak.us> . Tom, Enclosed is the TIO plot for MPC-39i going back to June 1st. At the moment all I have for IA and OA pressures are the once a week readings that are recorded electronically. I will be on the Slope Monday and can then glean the daily IA&OA pressures from the operator read sheets. I will then send you a updated September "enhanced monitoring" sheet for MPC-39i and add this well to the monthly list. Mark Sauve Milne Point Artificial Lift BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com & Production Coordinator -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, October 08, 2004 10:38 AM To: Sauve, Mark A Cc: Jim Regg Subject: Re: Milne Point Unit- SCP update for the week ending 10/3/04 Mark, In my earlier note, I should have mentioned that C-39 should be added to the "monitoring list" that you presently send in every month. This should be the practice for any injector that shows evidence of communication, regardless if it is only gas and you change the well back to water. We are presently talking on the phone so most questions should be answered. Tom Maunder, PE Thomas Maunder wrote: Mark, Could you provide the TIO information on C-39?? The time frame should include at least 30 days prior to the conversion to MI. You should note that since this is an injection well, operation of it is governed by the Area Injection Order and the sustained casing pressure rules. Although annular pressures are of concern with both production and injection wells, the two well types are treated differently. You should consult a copy of AIO lOB and be aware of how the different wells are regulated. Call or message with any questions. Tom Maunder, PE AOGCC Sauve, Mark A wrote: Tom and Jim, Just an update on SCP wells at Milne Point. *MPC-39i (PTD#1972480)*- lof2 10/8/2004 11 :09 AM RE: Milne Point Unit- SCP update for the week ending 10/3/04 The AOGCC was notified on 9/27/04 of SCP in the IA. After converting the well back to water injection a successful IA-MIT confirmed that tubing-to-IA pressure communication exists only with regards to gas movement and not to liquid. Until such time as the gas-only leak path is eliminated the well will remain on water injection only. Mark Sauve *Milne Point Artificial Lift *BP Exploration - Alaska * *900 E. Benson Blvd * *Anchorage, AK 99519* *Work Ph #: 907-564-4660* *Work Fax #: 907-564-4440* *E-mail: sauvema@bp.com* & Production Coordinator* > .. MPC-39i T-I-O plot & Content-DescriptIOn:.. . d I InjectIon tren s.x s app Ii cali onlvnd .ms-ex ce I base64 MPC-39i T -1-0 plot & injeetion Content-Type: Content-Encoding: 2 of2 10/8/200411:09 AM MPC-39i T/I/O & injection rate trends 5000 4500 4000 3500 3000 2500 2000 1500 1000 .~. . 500 -+- Tbg inj pressure (psi) - IA pressure (psi) OA pressure (psi) -*- Gas inj rate (mcfd) --.- Water inj rate (bpd) '--'.. . 0 05/13/04 06/02/04 06/22/04 07/12/04 08/01/04 08/21/04 09/10/04 09/30/04 10/20/04 . well_name prod_date Tbg inj pre: IA pressure OA pressUi Gas inj rate (I Water inj rate (bpd) C39i 06/01/04 2977 0 1238 C39i 06/02/04 3121 0 1512 C39i 06/03/04 3131 0 1487 C39i 06/04/04 3131 1320 280 0 1438 C39i 06/05/04 3132 0 1424 C39i 06/06/04 3121 0 1308 C39i 06/07/04 3023 0 879 C39i 06/08/04 2996 0 890 C39i 06/09/04 2980 0 893 C39i 06/10/04 2979 0 922 C39i 06/11/04 2933 1380 310 0 908 C39i 06/12/04 2966 0 867 C39i 06/13/04 2959 0 876 C39i 06/14/04 2974 0 1011 C39i 06/15/04 2969 0 943 C39i 06/16/04 2954 0 920 C39i 06/17/04 2945 0 909 C39i 06/18/04 2943 1360 300 0 868 C39i 06/19/04 2946 0 881 C39i 06/20/04 2954 0 895 C39i 06/21/04 2903 0 825 C39i 06/22/04 2535 0 784 C39i 06/23/04 2932 0 900 C39i 06/24/04 2920 0 834 C39i 06/25/04 2676 0 541 C39i 06/26/04 2844 1360 320 0 509 C39i 06/27/04 0 0 0 C39i 06/28/04 0 0 0 C39i 06/29/04 0 0 0 C39i 06/30/04 0 0 0 C39i 07/01/04 0 0 0 C39i 07/02/04 0 1000 0 0 0 C39i 07/03/04 0 0 0 C39i 07/04/04 0 0 0 C39i 07/05/04 0 0 0 C39i 07/06/04 0 0 0 C39i 07/07/04 0 0 0 C39i 07/08/04 0 0 0 C39i 07/09/04 0 1000 0 0 0 C39i 07/10/04 0 0 0 C39i 07/11/04 0 0 0 C39i 07/12/04 0 0 0 C39i 07/13/04 0 0 0 C39i 07/14/04 0 0 0 C39i 07/15/04 0 0 0 C39i 07/16/04 0 500 0 0 0 C39i 07/17/04 0 0 0 C39i 07/18/04 0 0 0 C39i 07/19/04 0 0 0 C39i 07/20/04 0 0 0 C39i 07/21/04 0 0 0 C39i 07/22/04 0 0 0 C39i 07/23/04 0 960 0 0 0 C39i 07/24/04 0 0 0 C39i 07/25/04 0 0 0 C39i 07/26/04 0 0 0 C39i 07/27/04 0 0 0 C39i 07/28/04 0 0 0 C39i 07/29/04 0 0 0 C39i 07/30/04 0 960 20 0 0 C39i 07/31/04 0 0 0 C39i 08/01/04 0 0 0 C39i 08/02/04 0 0 0 C39i 08/03/04 0 0 0 C39i 08/04/04 0 0 0 C39i 08/05/04 0 0 0 C39i 08/06/04 0 940 0 0 0 C39i 08/07/04 0 0 0 C39i 08/08/04 0 0 0 C39i 08/09/04 0 0 0 C39i 08/10/04 0 0 0 C39i 08/11/04 0 0 0 C39i 08/12/04 0 0 0 C39i 08/13/04 0 940 0 0 0 C39i 08/14/04 0 0 0 C39i 08/15/04 0 0 0 C39i 08/16/04 0 0 0 C39i 08/17/04 0 0 0 C39i 08/18/04 0 0 0 C39i 08/19/04 0 0 0 C39i 08/20/04 0 700 100 0 0 C39i 08/21/04 0 0 0 C39i 08/22/04 0 0 0 C39i 08/23/04 0 0 0 C39i 08/24/04 0 0 0 C39i 08/25/04 0 0 0 C39i 08/26/04 0 0 0 C39i 08/27/04 0 960 0 0 0 C39i 08/28/04 0 0 0 C39i 08/29/04 0 0 0 C39i 08/30/04 0 0 0 C39i 08/31/04 0 0 0 C39i 09/01/04 0 0 0 C39i 09/02/04 4338 346 0 C39i 09/03/04 4244 980 0 680 0 C39i 09/04/04 4250 681 0 C39i 09/05/04 4265 713 0 C39i 09/06/04 4272 708 0 C39i 09/07/04 4270 677 0 C39i 09/08/04 4271 673 0 C39i 09/09/04 4274 661 0 C39i 09/10/04 4273 1000 0 631 0 C39i 09/11/04 4269 614 0 C39i 09/12/04 4299 962 0 C39i 09/13/04 4371 1348 0 C39i 09/14/04 4433 1714 0 C39i 09/15/04 4499 1950 0 C39i 09/16/04 4518 1936 0 C39i 09/17/04 4536 800 100 1807 0 C39i 09/18/04 4528 1858 0 C39i 09/19/04 4546 1833 0 C39i 09/20/04 4552 1827 0 C39i 09/21/04 4545 1751 0 C39i 09/22/04 4548 1827 0 C39i 09/23/04 4556 1872 0 C39i 09/24/04 4549 1960 20 1744 0 C39i 09/25/04 4544 1714 0 C39i 09/26/04 4530 1664 0 C39i 09/27/04 4537 1635 0 C39i 09/28/04 3563 864 523 C39i 09/29/04 2719 0 1597 C39i 09/30/04 2789 0 1616 C39i 10/01/04 2878 0 1758 C39i 10102/04 2740 980 240 0 1092 C39i 10/03/04 2672 0 1070 C39i 10/04/04 2897 0 1698 C39i 10/05/04 2890 0 1415 C39i 10/06/04 2775 0 915 C39i 10107/04 2771 1040 340 0 932 . . ~ ~ . c¡ 1-() '--/ D " MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount O.7J'" DATE: July 12, 2000 Commissioner I ! I/o/bc.) THRU: Blair Wondzell, Q3~ P. I. Supervisor ,gf1(õo FROM: ~ (;;!t J Jeff Jones ~.. SUBJECT: Safety Valve Tests Petroleuml sp c r Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. :3}V(:.>~ r-<--k-5t- 21 well houses were inspected, no failures. . 'þ" Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc r'. ~ .)..I Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Date: 7/9/00 Operator Rep: Larry Niles FieldlUnitlPad: Kuparuk River/MPU/C-Pad AOGCC Rep: Jeff Jones Separator psi: LPS 140 HPS ;;.(,~;i "tJ'WtliiJi),?f: " , ~B~~~¥ ~Ì!i£.l'¡è: "e) ,at ,ii/,.. < " ,J:O , " , ) ~~.~ " I"";,;,.,,,.' ,¡t'" Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE ~ Ø....{H~~I":" 1811430 140 100 95 P P OIL ,/ C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 VI v7iram.x1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing_ Repair well _ Other X WAG SWAP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 46 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__x Miline Point Unit 4. Location of well at surface 4471' FNL, 2333' FEL, Sec. 10, T13N, R10E, UM (asp's 558130, 6029090) MPC-39 At top of productive interval \ 9. Permit number / approval number 5069' FNL, 3970' FEL, Sec. 10, T13N, R10E, UM (asp's 556499, 6028450) ~ 197-248 At effective depth 10. APl number 5123' FNL, 4101' FEL, Sec. 10, T13N, R10E, UM (asp's 556368, 6028425) ~ 50-029-22849-, ~ At total depth 11. Field / Pool 5180' FNL, 4225' FEL, Sec. 10, T13N, R10E, UM (asp's 556245, 6028367) Miline Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 7922 feet Plugs (measured) Tagged TD @ 7557 (12/08/2002) true vertical 7537 feet Effective depth: measured 7557 feet Junk (measured) true vertical 7198 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arcticset 1 (approx) 145' 145' Surface 4790' 9-5/8" 1565 sx PF 'E', 240 sx 4821' 4674' Class 'G' Production 7854' 7" 255 sx Class 'G' 7884' 7502' Perforation depth: measured Open Parrs 7342'-7350', 7435'-7445', 7513'-7529', 7539'-75,~ i-,,~,~r,~ j~, ~% Covered with fill 7557'-7568'. I ELEIVCL) true vertical Open Perfs 7005'- 7012', 7089'- 7098', 7161'- 7176', 7185'- 7198' Covered with fill 7198'- 7209' ,~H ~ ~ 2003 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 TBG to 7497' MD. Alaska 0ii & Gas Co~'~s. Anchor~rlp Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker Packer @ 7283' & 7" x 3-1/2" SABL-3 Baker Packer @ 7467. 3.5" H.E.S. 'X' Nipple @ 2240'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or niect on Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/20/2002 1865 3109 Subsequent to operation 01/20/2003 1704 $6/4Nhli~D FFR ¢) 4 ?rlr);t 4717 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge._ .,~~~ ,~J~ Title: TechnicalAssistant Date danuarv3O, 2003 DeWayne R. Schnorr Prepared b~/DeWar/ne R Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE MPC-39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/13/2002 04/09/2002 05/29/2002 07/10/2002 09/04/2002 09/13/2002 WAG SWAP --- GAS TO WATER INJECTION WAG SWAP --- WATER TO GAS INJECTION WAG SWAP --- GAS TO WATER INJECTION WAG SWAP --- WATER TO GAS INJECTION WAG SWAP --- GAS TO WATER INJECTION SLICKLINE --- DRIFT FOR IPROF 09/25/2002 MAINTENCE --- FREEZE PROTECT--- PUMP 10/17/2002 SLICKLINE --- INJECTION SURVEY 12/08/2002 SLICKLINE --- DRIFT FOR IPROF 12/24/2002 WAG SWAP --- WATER TO GAS INJECTION EVENT SUMMARY 01/13/02 WELL SUPPORT RIGGED UP AN SWAPPED BLINDS AND TORQUED TO SPEC. HB&R RIGGED UP AND PRESSURE TESTED TO 5000 PSI. SWITCHED TO SOURCE WATER. PUMPED 80 BBLS @ 3.5 TO 4.5 BPM FROM 4325 TO 2750 PSI. SWITCHED TO METHANOL AND PUMPED 2 BBLS TO FREEZE PROTECT UNIT. JOB WAS COMPLETED WITH NO PROLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. 04/09/02 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUED FLANGES TO SPEC. FLUSHED CENSlNG LINES AND SERVICED TREE. MIRU HB&R. PT'd TO 3500 PSI. PUMPED 2 BBLS METHANOL DOWN THE FLOW LINE @ 0.5 BPM AND 20 BBLS METHANOL DOWN THE TUBING @ 1.5 BPM AT 2200 TO 3550 PSI. RDMO. PUT ON INJECTION @ 2000 MCFPD. 05/29/02 PJSM. S/I & SAFED OUT SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR WEATER INJECTION AND TORQUED FLANGES TO SPEC. MIRU HB&R PT'd TO 4500 PSI. PUMPED 80 BBLS SOURCE WATER & 15 BBLS METHANOL DOWN THE TUBING @ 2 BPM, 4200 TO 2775 PSI. RDMO. PUT ON INJECTION @ 1500 BPD. 07/1 O/02 WELL SUPPORT SWAPPED BLINDS, FLUSHED SENSOR LINES, AND GREASED TREE. ALL FLANGES WERE TORQUED TO SPEC. HB&R RIGGED UP AND PUMPED 2 BBLS METHANOL DOWN THE WATER LEG AND PUMPED 20 BBLS METHANOL DOWN THE TUBING. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON INJECTION. 09~4~2 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUED TO SPEC. MIRU FESCO. PT'd TO 4800 PSI. PUMPED 5 BBLS METHANOL @ 1.0 BPM AT 3600 PSI. SWITCHED TO SOURCE WATER & PUMPED 90 BBLS @ 1.0 TO 2.0,3600 TO 3800 PSI & 2 BBLS METHANOL @ 1.4 SCANNED FEB 0 & 2003 Page 1 09/04/02 (CONTINUED) 09/13/02 09/25/02 10/17/02 12/08/02 12/09/02 12/24/O2 MPC-39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS OPERATOR TO BE PUT ON INJECTION. JOB WAS COMPLETED WITH NO PROBLEMS. PUT ON INJECTION AT 1500 BPD. DRIFTED TUBING TO TD WITH 2.69" GAUGE RING. CORRECTED TD TO 7556' MD. 12 FT OFA2 SANDS ARE COVERED. WILL BE ABLE TO RUN INJECTION SURVEY. OBJECTIVE: FREEZE PROTECT WELL FOR HIGH PRESSURE HEADER TIE IN WORK. OPERATION: ARRIVED ON LOCATION, HELD PRE-JOB SAFETY MEETING. PRESSURED TESTED TO 3500 PSI. STARTED DOWN TUBING WITH 22 BBLS OF METHANOL @ 1.5 BPM, 3000 PSI MAXIMUM. CONCLUSION: TUBING FREEZE PROTECTED WITH METHANOL FOR SHUT DOWN. OBLECTIVE: RUN PDS INJECTION SURVEY. OPERATION: 1.875" TOOL STRING. MIRU, CONDUCT TGSM. PURGE PILOTS WITH METHANOL. RIG UP HEATER WITH WELL HOUSE COVER. P/T EQUIPMENT TO 3000#. GOOD TEST. RIH WITH 2" DD BAILER TO TD @ 7539' WLM. POOH WITH FULL BAILER, SAVED SAMPLE. RIH WITH PDS LOGGING TOOL. PERFORM STOP COUNT MEASUREMENTS AND UP AND DOWN PASSES. POOH, CONFIRMED SUCCESSFUL DATA. RDMO. DRIFT FOR IPROF. INJECTION RATE @ 2000 BBLS PER DAY. DRIFTED TUBING WITH 2.70" GAUGE. TAGGED TD @ 7557 FT ELMD. 11 FT OF KUPARUK A-2 SAND IS COVERED. OBJECTIVE: RUN PDS INJECTION SURVEY. OPERATION: INJECTION RATE - 2060 BBLS PER DAY. TGSM, RIG UP HES. PU PDS LOGGING STRING. PERFORM STOP COUNT MEASUREMENTS AND UP AND DOWN PASSES. POOH. RIG HES DOWN. PDS DATA IS USEABLE - GOOD DATA. PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION. TORQUED FLANGES TO SPEC. MIRU FESCO. PT'd TO 4000 PSI. PUMPED 20 BBLS METHANOL DOWN THE TUBING @ 1.2 BPM, 3500 TO 3650 PSI AND 2 BBLS METHANOL DOWN THE WATER LEG FOR FREEZE PROTECT. RDMO. WELL WAS SWAPPED TO GAS AND PUT ON INJECTION. BUT, WELL CURRENTLY IS NOT REGISTERING ANY GAS INJECTION INTO THE WELL. IA PRESSURE CAME UP FROM 100 TO 1000 PSI AFTER WELL WAS PUT ON INJECTION. SCANNED FEB 0 A 2003 Page 2 MPC-39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS DISCRIPTION '122 METHANOL 250 SOURCE WATER 372 TOTAL SCANNED FEB 0 '~ 2003 Page 3 ON-'OR BEFORE PL W M ATE IA L U N D ER TH IS M ARK E R C:LORI/IVlFILM. DOC ~~ ' . . MEMORANDUM State of Alas ka Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0'0 DATE: July 12, 2000 Commissioner' 0- /lo/CJc:.v THRU: Blair Wondzell, ~~ P. I. Supervisor . 9f 1(o(J FROM: ~dt¡ Jeff Jones ,.r SUBJECT: Safety Valve Tests Petroleum'l sp c !.r Milne Point Unit 8 & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU 8-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hokJ DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 JI,-P... r-<-~5>f- 21 well houses were inspected, no failures. --'tf' Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 BPS 7/9100 ~ ,/ . . '. . <,' '--:~~;:!~Y:~:,' ". .,'IIS \1-; '.' "$~I¥;':' I~:~:,~,I/~ :~'::;'l'f( ~~, ~~ lV ell/ryþe: :\~ . '~lell Data .. ' . . ," . :- ~ . I '. " Pilots . :' . I' a ~ Wcll Pcrmit Scpar Sct LIP Tcst Test Test Number Numbcr PSI PSI Trip Code Code Code Oil, WAG, GIN.I, GAS or CYCLE ;; ,<#~Ðl!:~~!<\."~ 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day We lIs: Rcmarks: Wells #- C-02 & C-06 are listed as water injection wells, and are not in this database Well #- C-28 SV could not be pressure tested because the tree cap a-ring leaked. The SV on well #- C-07 recorded a slow closing tin1e;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7 lOa Paoe 1 of 1 b V 1 v7irqm.xls Well Report --~6~p. 01 /21 /1998 MILNE POINT UNIT Completion Status: WAGIN C-39 Current Status 029-22849-00 197-248-0 BP EXPLORATION MD 0792Z TVD 07537 Name Interval Sent Received BO 8407 ~1,2 SPERRY MPT/GR/EWR4/CNP/SLD 3/25/98 3/25/98 8616 L~ I SCHLUM ?CD 8/17/98 8/20/98 9269 ~ PDS INJP 8/12/99 8/12/99 DGR/CNP/SLD-MD zL/' FINAL 113-7923 4/1/98 4/1/98 DGR/CNP/SLD-TVD ~/FINAL 112-7537 4/1/98 4/1/98 DGR/EWR4-MD ~/~INAL 113-7923 4/1/98 4/1/98 DGR/EWR4-TVD L/L/ FINAL 112-7537 4/1/98 4/1/98 INJP L,~L//FINAL 7186-7683 8/8/99 8/12/99 8/12/99 D MWD SRVY ~ SPERRY 0-7922. 1/22/99 1/25/99 USIT LL/' FINAL BL(C) 4821-7700 i/[ ~/~ 3/23/98 3/25/98 Daily WellOps ]/¢///c]~ / ~~cttod Are Dry Ditch Samples Required? yes (~_~...~AndReceived?.-qes--m~--- Was the well cored? yes ~ Analysis Description Re ' °~v~l$--3q~'-n~~ Sample SetWr-- Comments: Monday, January 10, 2000 Page 1 of 1 TRANSMITTAL: ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE · Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed · Print Nam ProActive Diagnostic Services, LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT{S) Open Hole I I 1 ! qg' ~ 9~ ~ ~~ Res. Eval. CH I I I 1 · Inc., Pouch 340112, P~US_,5oe 9a¥, .~ 99?34 Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C:WIy Documents~xcel_Word_Documents\Distribution_FonnsXBp_milpt_fom~.doc STATE OF ALASKA :;-.:~ ~-;/,, ~._, ,¢, ,¢ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION :,'i':~.., iE i 'b" ~;7 WELL COMPLETION OR RECOMPLETION REPORT AND LOG .~ :~,,",~ 25' 1~9 1. Status of Well Classification of Service Well I--IOil t~Gas I--iSuspended [--I Abandoned [~Service Water & Gas In~¢tO¢ 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-248 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22849 ~ .T~Di~ 9. Unit or Lease Name 4. Location of well at surface ~- ',-7 ~":' :.'--.,-i..: '~, ~~ ~:~ Milne Point Unit 10, I N, 10 ,UM , .... At top of productive interval : ~,~,~ 10. Well Number 211' NSL, 3970' WEL, SEC. 10, T13N, R10E, UM '~'~' MPC-39 At total depth~ "~"- ""~'""~.~'~~ 11. Field and Pool 100' NSL, 4223' WEL, SEC/10, T13N, R10E, UM ~ -'/-~--~ ...... : ..... .~ -' Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 46.10'I ADL047434 12. Date Spudded1/8/98 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 16' N°' °f C°mpleti°nsl/14/98 1/21/98 N/A MSL One 17. Total Depth (MD+TVD)118. Plug BaokDepth(MD+TVD)19. DirectionalSurvey 120. Depth where SSSV set121. Thickness of Permafrost 7922 7537 FTI 7796 7420 FT [~Yes [~]No 'x' nipple 2240' MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD, USlT, GR/Resistivity/Dens/Neutron 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-Iq-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1¢ H-40 33' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 4821' 12-1/4" 1565 sx PF 'E', 240 sx Class 'G' 7" 26# L-80 30' 7884' 8-1/2" 255 sx Class 'G' , , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 7495' 7" Baker S Packer @ 7467' MD TVD MD TVD 7" Baker Packer @ 7283';' 7539' - 7567' 7182' - 7207' 7513' - 7529' 7158' - 7173' 126. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7435' - 7445' 7086' - 7095' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7342' - 7350' 7001' - 7008' Freeze protect with 63 bbls Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 9, 1998I Other (explain) Water and Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ion Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 7204' 6875' Top Kuparuk 'B2' 7447' 7097' Top Kuparuk 'A2' 7540x 7183' 31. List of Attachments Summary of Daily Drilling Reports, Surveys Signed Charles R. Mallary ~/ Title Drilling Superintendent Date MPC-39 '97-248 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. iNSTRUCTIONS GENERAl.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 ~,ND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 04 Jan 98 05 Jan 98 06 Jan 98 07 Jan 98 08 Jan 98 09 Jan 98 10 Jan 98 Progress Report M Pt C Pad Well MPC-39 _ Page Date 20:00-22:00 Duration Activity 2 hr Rig moved 0.00 % 22:00-22:30 22:30-23:00 23:00-00:00 00:00-02:00 02:00-04:30 04:30-06:00 06:00-11:00 11:00-19:00 19:00-21:00 21:00-23:00 23:00-01:00 01:00-04:00 04:00-06:00 06:00-10:00 10:00-12:00 12:00-14:00 14:00-15:30 15:30-17:00 17:00-20:00 20:00-00:00 00:00-03:00 03:00-06:00 06:00-10:30 10:30-11:00 11:00-18:00 18:00-18:30 18:30-21:00 21:00-06:00 06:00-06:30 06:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-18:00 18:00-18:30 18:30-00:30 00:30-01:30 01:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-11:00 11:00-13:00 1/2 hr 1/2 hr lhr 2hr 2-1/2 hr 1-1/2 hr 5hr 8hr 2hr 2hr 2hr 3hr 2hr 4hr 2hr 2hr 1-1/2 hr 1-1/2 hr 3hr 4hr 3hr 3hr 4-1/2 hr 1/2 hr 7hr 1/2hr 2-1/2 hr 9hr 1/2 hr 10hr 1/2 hr lhr 1/2 hr lhr 1/2 hr 9hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 8hr 1/2 hr 6hr lhr 2-1/2 hr lhr lhr 1/2 hr 1-1/2 hr 3hr 2hr Held safety meeting Rig moved 0.00 % Rig moved 0.00 % Rig moved 0.00 % Rig moved 0.00 % Rig waited · Production facilities Rig waited · Other delays Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Serviced Top drive Serviced Block line Rigged up Divertor Rigged up Bell nipple Repaired Top drive Ran Drillpipe to 0.0 ft (5in OD) Racked back Drillpipe Held safety meeting Racked back Drillpipe Held safety meeting Made up BHA no. 1 Drilled to 1025.0 ft Held safety meeting Drilled to 2508.0 ft Circulated at 2508.0 ft Pulled out of hole to 600.0 ft Held safety meeting Serviced Top drive R.I.H. to 2508.0 ft Drilled to 3714.0 ft Circulated at 3714.0 ft Pulled out of hole to 2500.0 ft Held safety meeting Pulled out of hole to 1487.0 ft Serviced Top drive R.I.H. to 3714.0 ft Drilled to 4477.0 ft Held safety meeting Drilled to 4840.0 ft Circulated at 4840.0 ft Pulled out of hole to 900.0 ft Serviced Top drive R.I.H. to 4000.0 ft Held safety meeting Circulated at 4840.0 ft Pulled out of hole to 600.0 ft Pulled BHA 1 21 January 99 Facility M Pt C Pad Date/Time 13:00-15:00 15:00-15:30 15:30-20:30 20:30-21:30 21:30-22:00 22:00-23:00 23:00-00:00 11 Jan 98 00:00-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-14:00 14:00-20:00 20:00-03:30 12 Jan 98 03:30-04:30 04:30-06:00 06:00-06:30 " 12:30-14:00 14:00-15:00 15:00-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-06:00 13 Jan 98 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:30 10:30-11:00 11:00-18:00 18:00-18:30 18:30-20:00 20:00-23:30 23:30-06:00 14 Jan 98 06:00-06:30 06:30-07:30 07:30-09:00 09:00-09:30 09:30-11:00 11:00-11:30 11:30-13:00 13:00-15:00 15:00-18:00 18:00-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-02:30 15 Jan 98 02:30-03:30 06:00-10:30 10:30-13:00 13:00-15:00 Duration 2hr 1/2 hr 5hr lhr 1/2 hr lhr lhr 2-1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 2hr 5hr 6hr 7-1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr lhr 2hr 1/2 hr 7hr 1/2 hr 1-1/2 hr 3-1/2 hr 6-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2hr 3hr lhr 1-1/2 hr 1/2 hr lhr 4-1/2 hr lhr 4-1/2 hr 2-1/2 hr 2hr Progress Report Well MPC-39 Rig Page 2 Date 21 January 99 Activity Installed Casing handling equipment Held safety meeting Ran Casing to 4820.0 ft (9-5/8in OD) Circulated at 4820.0 ft Held safety meeting Mixed and pumped slurry - 201.000 bbl Circulated at 2186.0 ft Mixed and pumped slurry - 450.000 bbl Removed Casing handling equipment Rigged down Divertor Held safety meeting Removed Divertor Installed Tubing head spool Rigged up BOP stack Tested BOP stack Installed Well control Tested Well control Made up BHA no. 2 Held safety meeting R.I.H. to 4730.0 ft Circulated at 4730.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float collar Circulated at 4860.0 ft Performed formation integrity test Drilled to 6485.0 ft Held safety meeting Pulled out of hole to 4820.0 ft Serviced Top drive Serviced Top drive pipe handler R.I.H. to 6380.0 ft Drilled to 7056.0 ft Held safety meeting Drilled to 7245.0 ft Circulated at 7245.0 ft Drilled to 7817.0 ft Held safety meeting Drilled to 7922.0 ft Circulated at 7922.0 ft Flow check Circulated at 7922.0 ft Flow check Circulated at 7922.0 ft Flow check Circulated at 7922.0 ft Flow check Pulled out of hole to 6581.0 ft Flow check R.I.H. to 7922.0 ft Circulated at 7922.0 ft Pulled out of hole to 5922.0 ft Pulled out of hole to 600.0 ft Pulled BHA Rigged up Casing handling equipment Facility M Pt C Pad Progress Report Well MPC-39 Page Date 3 21 January 99 Date/Time 16 Jan 98 17 Jan 98 18 Jan 98 19 Jan 98 20 Jan 98 15:00-01:00 01:00-02:00 02:00-02:45 02:45-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-14:00 14:00-15:00 15:00-15:30 15:30-19:00 19:00-22:00 22:00-23:00 23:00-04:30 04:30-06:00 06:00-08:30 08:30-13:30 13:30-15:30 15:30-18:00 18:00-18:30 18:30-22:00 22:00-02:00 02:00-06:00 06:00-06:30 06:30-10:00 10:00-14:00 14:00-18:00 18:00-19:30 19:30-23:00 23:00-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-13:00 13:00-22:00 22:00-22:30 22:30-06:00 06:00-06:30 06:30-10:00 10:00-15:00 15:00-16:30 16:30-17:00 17:00-18:00 18:00-20:00 20:00-22:00 22:00-01:00 Duration 10hr lhr 3/4 hr 3/4 hr 1/2 hr 2hr 1/2 hr 4-1/2 hr lhr 2hr lhr 1/2hr 3-1/2 hr 3hr lhr 5-1/2 hr 1-1/2 hr 2-1/2 hr 5hr 2hr 2-1/2 hr 1/2 hr 3-1/2 hr 4hr 4hr 1/2 hr 3-1/2 hr 4hr 4hr 1-1/2 hr 3-1/2 hr 3hr 3-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 4hr 9hr 1/2 hr 7-1/2 hr 1/2hr 3-1/2 hr 5hr 1-1/2 hr 1/2 hr lhr 2hr 2hr 3hr Activity Ran Casing to 7883.0 ft (7in OD) Circulated at 7883.0 ft Mixed and pumped slurry - 53.000 bbl Displaced slurry - 289.000 bbl Tested Casing Wait on cement Held safety meeting Wait on cement Bullhead well Flow check Bullhead well Flow check Removed Casing handling equipment Removed BOP stack Installed Tubing head spool Rigged up BOP stack Tested BOP stack Tested Top ram Singled in drill pipe to 2000.0 ft Serviced Block line Singled in drill pipe to 3034.0 ft Held safety meeting Singled in drill pipe to 7795.0 ft Circulated at 7795.0 ft Pulled out of hole to 0.0 ft Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Perforated Perforated Perforated Rigged down Lubricator Held safety meeting Rigged down Lubricator Ran Drillpipe to 7617.0 ft (3-1/2in OD) Laid down 7795.0 ft of Drillpipe Rigged up Tubing handling equipment Ran Tubing to 4500.0 ft (3-1/2in OD) Held safety meeting Ran Tubing to 7496.0 ft (3-1/2in OD) Removed BOP stack Installed Xmas tree Removed Accessories Circulated at 0.0 ft Circulated at 0.0 ft Tested Tubing Installed Accessories Performance Enquiry Report Operator BP Exploration Date 21:40, 22 Jan 99 Page 1 The analysis is from - 18:30, 12 Jan 98 - to - 18:30, 12 Jan 98 Programs in Result Table: MPC-39 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPC-39 Event 18:30, 12 Jan 98 18:30, 12 Jan 98 0 hr 0 min Obtained leak off 12.6 Hole Size MDR 8-1/2 SPERRY-SUN DRILLING SERVICES SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 .PAGE DATE OF SURVEY: 011498 MWD SURVEY JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -46.10 0 0 N .00 E .00 .00N .00E .00 112.00 112.00 65.90 0 0 N .00 E .00 .00N .00E .00 151.85 151.85 105.75 0 6 N 82.67 W .25 .00N .03W .03 209.43 209.43 163.33 0 9 S 78.76 W .12 .00S .16W .15 300.72 300.72 254.62 0 42 N 62.19 E .94 .23N .21E -.27 393.27 393.24 347.14 1 54 N 63.43 E 1.31 483.30 483.18 437.08 2 55 N 69.77 E 1.16 573.32 573.09 526.99 2 50 N 62.01 E .44 662.30 661.97 615.87 2 39 N 72.39 E .60 757.67 757.26 711.16 1 58 N 87.48 E .95 1.18N 2.08E -2.37 2.65N 5.58E -6.16 4.49N 9.70E -10.67 6.14N 13.61E -14.91 6.88N 17.34E -18.66 849.06 848.62 802.52 0 30 S 52.63 E 1.77 939.21 938.75 892.65 1 31 S 41.14 E 1.16 1030.20 1029.71 983.61 1 31 S 38.62 E .07 1121.85 1121.33 1075.23 1 18 S 34.36 E .27 1213.69 1213.15 1167.05 1 19 S 34.28 E .00 6.71N 5.57N 3.70N 1.88N .14N 19.23E -20.36 20.34E -20.97 21.89E -21.75 23.25E -22.35 24.44E -22.83 1306.97 1306.40 1260.30 1 31 S 40.78 E .27 1399.81 1399.22 1353.12 0 21 S 14.74 W 1.46 1491.97 1491.38 1445.28 0 40 N 88.17 W .74 1585.52 1584.92 1538.82 0 36 N 76.34 W .16 1677.41 1676.81 1630.71 0 27 N 79.76 W .17 1.68S 2.89S 3.15S 3.01S 2.84S 25.85E -23.48 26.58E -23.73 25.97E -23.07 24.95E -22.16 24.13E -21.46 1770.46 1769.84 1723.74 1 28 S 87.53 W 1.11 1864.22 1863.54 1817.44 2 30 S 83.80 W 1.12 1955.50 1954.69 1908.59 3 31 S 83.80 W 1.11 2047.90 2046.81 2000.71 5 18 S 80.84 W 1.94 2141.46 2139.91 2093.81 6 1 S 80.23 W .77 2.82S 22.57E -20.02 3.10S 19.33E -16.90 3.61S 14.56E -12.26 4.60S 7.53E -5.35 6.12S 1.58W 3.69 2234.31 2232.21 2186.11 6 24 S 71.64 W 1.08 2325.78 2322.99 2276.89 7 41 S 64.48 W 1.70 2418.38 2414.58 2368.48 9 tl S 63.86 W 1.62 2513.16 2508.08 2461.98 9 37 S 64.08 W .46 2605.00 2598.65 2552.55 9 26 S 64.71 W .22 8.58S 11.29W 13.63 12.82S 21.65W 24.82 18.75S 33.88W 38.37 25.54S 47.79W 53.80 32.12S 61.51W 68.97 2697.95 2690.20 2644.10 10 26 S 66.76 W 1.13 2788.74 2779.26 2733.16 11 56 S 68.61 W 1.70 2880.93 2869.17 2823.07 13 33 S 70.67 W 1.82 2973.68 2958.92 2912.82 15 35 S 73.17 W 2.29 3067.72 3049.03 3002.93 17 36 S 75.46 W 2.25 38.70S 76.15W 85.00 45.37S 92.45W 102.61 52.43S 111.53W 122.95 59.63S 133.72W 146.24 66.86S 159.58W 172.96 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 2 SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 MWD SURVEY JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3159.88 3136.33 3090.23 3250.74 3221.42 3175.32 3340.13 3304.24 3258.14 3436.06 3392.64 3346.54 3531.22 3480.44 3434.34 19 42 21 17 22 54 22 47 22 34 S 74.60 W 2.31 74.49S 188.05W S 72.74 W 1.89 83.45S 218.58W S 70.28 W 2.08 94.14S 250.46W S 69.51 W .34 106.94S 285.44W S 69.77 W .25 119.71S 319.84W 202.26 233.96 267.55 304.80 341.48 3626.65 3568.69 3522.59 22 9 3724.30 3659.16 3613.06 22 2 3817.37 3745.63 3699.53 21 21 3912.64 3834.29 3788.19 21 35 4008.12 3923.09 3876.99 21 30 S 69.61 W .43 132.31S 353.90W S 69.91 W .16 145.03S 388.37W S 70.28 W .76 156.75S 420.74W S 68.53 W .71 169.02S 453.38W S 67.00 W .59 182.29S 485.84W 377.79 414.53 448.94 483.81 518.87 4104.52 4012.49 3966.39 4199.86 4100.48 4054.38 4295.08 4188.43 4142.33 4389.06 4275.29 4229.19 4486.71 4365.32 4319.22 22 26 22 51 22 12 22 41 22 53 S 68.17 W 1.07 196.03S 519.19W S 69.20 W .60 209.37S 553.38W S 68.74 W .71 222.46S 587.43W S 67.58 W .70 235.81S 620.73W S 66.99 W .31 250.42S 655.62W 554.94 591.64 628.12 664.00 701.81 4580.59 4451.90 4405.80 22 34 4673.81 4538.07 4491.97 22 16 4753.80 4612.13 4566.03 22 8 4899.98 4746.26 4700.16 24 43 4995.18 4832.82 4786.72 24 28 S 66.53 W .38 264.73S 688.96W S 66.59 W .33 278.88S 721.59W S 66.92 W .23 290.81S 749.36W S 71.23 W 2.12 311.45S 803.66W S 70.72 W .34 324.36S 841.12W 738.07 773.60 803.81 861.90 901.49 5090.54 4919.61 4873.51 24 28 5186.10 5006.70 4960.60 24 8 5281.31 5093.71 5047.61 23 46 5376.28 5180.79 5134.69 23 15 5472.64 5269.54 5223.44 22 36 S 71.70 W .43 337.09S 878.51W S 70.41 W .65 349.85S 915.71W S 70.77 W .41 362.70S 952.18W S 70.90 W .56 375.14S 987.97W S 69.91 W .78 387.72S 1023.33W 940.95 980.25 1018.89 1056.76 1094.28 5568.69 5358.37 5312.27 22 6 5663.24 5446.03 5399.93 21 55 5758.57 5534.61 5488.51 21 27 5854.24 5623.74 5577.64 21 10 5949.91 5713.05 5666.95 20 50 S 69.56 W .54 400.37S 1057.59W S 68.21 W .57 413.14S 1090.64W S 68.46 W .49 426.14S 1123.39W S 68.53 W .30 438.89S 1155.74W S 69.81 W .59 451.09S 1187.79W 1130.79 1166.23 1201.46 1236.23 1270.52 6046.20 5803.19 5757.09 6141.58 5891.80 5845.70 6236.51 5979.27 5933.17 6330.53 6066.20 6020.10 6427.43 6156.10 6i10.00 20 19 23 4 22 38 22 7 21 41 S 68.01 W .84 463.26S 1219.38W S 71.67 W 3.21 475.35S 1252.49W S 72.36 W .53 486.74S 1287.58W S 71.55 W .64 497.83S 1321.63W S 71.46 W .46 509.30S 1355.92W 1304.37 1339.62 1376.44 1412.20 1448.32 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA · PAGE 3 SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 MWD SURVEY JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6525.27 6247.11 6201.01 21 24 S 72.91 W .61 6618.45 6333.26 6287.16 23 19 S 73.33 W 2.06 6714.01 6421.38 6375.28 22 12 S 74.12 W 1.20 6809.47 6509.91 6463.81 21 42 S 74.72 W .58 6904.39 6598.22 6552.12 21 19 S 75.50 W .50 520.30S 1390.13W 1484.19 530.59S 1424.05W 1519.53 540.95S 1459.54W 1556.37 550.54S 1493.92W 1591.88 559.49S 1527.56W 1626.47 6998.52 6685.24 6639.14 23 31 S 70.08 W 3.20 7093.59 6772.61 6726.51 22 54 S 70.17 W .64 7188.12 6859.93 6813.83 22 8 S 71.39 W .95 7283.77 6947.82 6901.72 24 19 S 67.49 W 2.79 7379.20 7034.99 6988.89 23 42 S 66.83 W .70 570.17S 1561.79W 1662.25 582.91S 1597.03W 1699.72 594.84S 1631.22W 1735.90 608.13S 1666.50W 1773.61 623.21S 1702.30W 1812.43 7474.65 7122.53 7076.43 23 15 S 66.59 W .48 7569.39 7209.69 7163.58 22 55 S 65.88 W .46 7664.31 7297.35 7251.25 22 10 S 64.85 W .89 7760.00 7386.11 7340.01 21 42 S 64.84 W .49 7855.22 7474.75 7428.65 21 9 S 65.41 W .61 638.25S 1737.23W 1850.44 653.22S 1771.24W 1887.56 668.38S 1804.32W 1923.89 683.58S 1836.67W 1959.55 698.21S 1868.24W 1994.27 7870.69 7489.18 7443.08 21 4 S 65.33 W .61 7922.00 7537.06 7490.96 21 4 S 65.33 W .04 700.53S 1873.30W 1999.83 708.23S 1890.06W 2018.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2018.40 FEET AT SOUTH 69 DEG. 27 MIN. WEST AT MD = 7922 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 248.75 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 7,922.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 4 SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -46.10 1000.00 999.52 953.42 2000.00 1999.11 1953.01 3000.00 2984.27 2938.17 4000.00 3915.54 3869.44 .00 N .00 E .00 4.33 N 21.39 E .48 .48 3.91 S 11.84 E .89 .41 61.68 S 140.49 W 15.73 14.84 181.12 S 483.10 W 84.46 68.73 5000.00 4837.21 4791.11 6000.00 5759.87 5713.77 7000.00 6686.60 6640.50 7922.00 7537.06 7490.96 325.02 S 843.00 W 457.25 S 1204.49 W 570.37 S 1562.34 W 708.23 S 1890.06 W 162.79 78.33 240.13 77.34 313.40 73.27 384.94 71.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.10 .00 N .00 46.10 46.10 .00 .00 N .00 146.10 146.10 100.00 .00 N .02 246.10 246.10 200.00 .02 S .24 346.11 346.10 300.00 .53 N .77 E .00 E .00 .00 W .00 .00 W .00 .00 E .01 .01 446.17 446.10 400.00 1.99 N 3.80 546.30 546.10 500.00 3.86 N 8.52 646.42 646.10 600.00 5.92 N 12.91 746.50 746.10 700.00 6.87 N 16.96 846.54 846.10 800.00 6.72 N 19.21 E .07 .06 E .20 .13 E .32 .12 E .40 .09 E .44 .04 946.56 946.10 900.00 5.42 N 20.46 1046.60 1046.10 1000.00 3.36 N 22.17 1146.63 1146.10 1100.00 1.41 N 23.57 1246.65 1246.10 1200.00 .49 S 24.86 1346.68 1346.10 1300.00 2.45 S 26.50 E .46 .02 E .50 .04 E .53 .03 E .55 .03 E .58 .03 1446.69 1446.10 1400.00 3.14 S 26.46 1546.70 1546.10 1500.00 3.11 S 25.34 1646.70 1646.10 1600.00 2.88 S 24.36 1746.71 1746.10 1700.00 2.80 S 23.18 1846.76 1846.10 1800.00 3.01 S 20.09 E .59 .01 E .60 .01 E .60 .01 E .61 .01 E .66 .05 1946.89 1946.10 1900.00 3.56 S 15.08 2047.19 2046.10 2000.00 4.59 S 7.59 2147.69 2146.10 2100.00 6.23 S 2.22 2248.28 2246.10 2200.00 9.07 S 12.76 2349.10 2346.10 2300.00 14.16 S 24.46 E .79 .13 E 1.09 .30 W 1.59 .50 W 2.18 .60 W 3.00 .82 2450.31 2446.10 2400.00 20.99 S 38.45 2551.72 2546.10 2500.00 28.36 S 53.59 2653.12 2646.10 2600.00 35.50 S 68.76 2754.85 2746.10 2700.00 42.82 S 85.95 2857.20 2846.10 2800.00 50.58 S 106.28 W 4.21 1.21 W 5.62 1.41 W 7.02 1.40 W 8.75 1.74 W 11.10 2.35 2960.37 2946.10 2900.00 58.60 S 130.30 3064.65 3046.10 3000.00 66.63 S 158.68 3170.26 3146.10 3100.00 75.42 S 191.42 327?.22 3246.10 3200.00 86.31 S 227.77 3385.58 3346.10 3300.00 100.12 S 267.10 W 14.27 3.17 W 18.55 4.28 W 24.16 5.61 W 31.12 6.97 W 39.48 8.35 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA . PAGE SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3494.03 3446.10 3400.00 3602.26 3546.10 3500.00 3710.21 3646.10 3600.00 3817.87 3746.10 3700.00 3925.34 3846.10 3800.00 114.77 S 306.45 129.11 S 345.27 143.21 S 383.40 156.81 S 420.91 170.73 S 457.73 W 47.93 8.45 W 56.16 8.23 W 64.11 7.95 W 71.77 7.67 W 79.24 7.47 4032.85 3946.10 3900.00 4140.89 4046.10 4000.00 4249.34 4146.10 4100.00 4357.42 4246.10 4200.00 4465.85 4346.10 4300.00 185.83 S 494.19 201.19 S 532.08 216.19 S 571.28 231.16 S 609.45 247.25 S 648.16 W 86.75 7.51 W 94.79 8.04 W 103.24 8.45 W 111.32 8.08 W 119.75 8.43 4574.31 4446.10 4400.00 4682.48 4546.10 4500.00 4790.56 4646.10 4600.00 4899.81 4746.10 4700.00 5009.77 4846.10 4800.00 263.77 S 686.75 280.19 S 724.61 296.18 S 762.36 311.42 S 803.59 326.36 S 846.82 W 128.21 8.46 W 136.38 8.18 W 144.46 8.08 W 153.71 9.24 W 163.67 9.96 5119.64 4946.10 4900.00 5229.26 5046.10 5000.00 5338.52 5146.10 5100.00 5447.25 5246.10 5200.00 5555.44 5346.10 5300.00 340.87 S 889.95 355.76 S 932.33 370.26 S 973.88 384.37 S 1014.16 398.63 S 1052.92 W 173.54 9.87 W 183.16 9.62 W 192.42 9.26 W 201.15 8.73 W 209.34 8.19 5663.31 5446.10 5400.00 5770.91 5546.10 5500.00 5878.22 5646.10 5600.00 5985.27 5746.10 5700.00 6092.17 5846.10 5800.00 413.15 S 1090.67 427.80 S 1127.59 442.06 S 1163.80 455.44 S 1199.59 469.17 S 1234.77 W 217.21 7.87 W 224.81 7.60 W 232.12 7.31 W 239.17 7.05 W 246.07 6.90 6200.56 5946.10 5900.00 6308 . 83 6046.10 6000.00 6416.66 6146.10 6100.00 6524.19 6246.10 6200.00 6632.43 6346.10 6300.00 482.55 S 1274.38 495.24 S 1313.87 508.04 S 1352.14 520.18 S 1389.75 532.17 S 1429.35 254.46 8.40 262.73 8.26 270.56 7.84 278.09 7.53 286.33 8.24 6740.72 6446.10 6400.00 6848.41 6546.10 6500.00 6956.00 6646.10 6600.00 7064.81 6746.10 6700.00 7173.19 6846.10 6800.00 543.72 S 1469.25 554.33 S 1507.81 564.84 S 1546.06 579.11 S 1586.49 593.04 S 1625.89 294.62 8.29 302.31 7.70 309.90 7.59 318.71 8.81 327.09 8.38 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE 7 SHARED SERVICES DRILLING MPU / MPC-39 500292284900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011498 JOB NUMBER: AKMM80077 KELLY BUSHING ELEV. = 46.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7281.88 6946.10 6900.00 7391.33 7046.10 7000.00 7500.30 7146.10 7100.00 7608.92 7246.10 7200.00 7716.93 7346.10 7300.00 607.84 S 1665.79 W 335.78 8.69 625.13 S 1706.78 W 345.23 9.45 642.27 S 1746.53 W 354.20 8.97 659.51 S 1785.27 W 362.82 8.62 676.80 S 1822.25 W 370.83 8.01 7824.50 7446.10 7400.00 7922.00 7537.06 7490.96 693.60 S 1858.15 W 378.40 7.57 708.23 S 1890.06 W 384.94 6.54 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11434 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 8/17/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPB-25 (,~1 (--'-- ~.-~(.o~' 98411 PDCGR 980101 1 MPC-39 ~ ~'(,e((-o' 98410 PDCGR 980118 1 ,, , , , . .... ,, , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED, : AUG ~0 1998 NaskaOit & Gas Gons. Comm~IU~,:~,":::. :'!:i:' ,:, a nnh~m~e Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1"199 Received To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Tavlor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-39, ~,M~-MM-80077 April 1, 1998 MPC-39: 2" x 5" MD Resistivi~ and Gamma Ray Logs: 50-029-22849-00 2" x 5" TVD Resistivitv and Gamma Ray Logs: 50-029-22849-00 2" x 5" MD Neutron and Density Logs: 50-029-22849-00 2" x 5" TVD Neutron and Density Logs: 50-029-22849-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: z.//1 /~ i~ 5631 Silverado Way. Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries. Inc. I~ F! I I_1-- I IM C3 S G= Ft~/I r- El S WELL LOG TRANSMITTAL To: State of Alaska 3Jaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 25, 1998 MPC-39, AK-MM-80077 I LDWG formatted Disc with verification listing. APl#: 50-029-22849-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETI'ER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: ,_.,2/~ff//~dv 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (907)563-3256 · Fax(907)563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11950 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3~23~98 Field: Milne Point (Cased Hole) Colored Well Job # Log Description Date Print RF Sepia LIS Tape ~PB-25 981 47 USIT 9801 01 I 1 MPC-36 981 47 USIT 980205 I 1 MPC-39 98147 USlT 980118 1 1 MPG-09 981 47 USlT 980220 1 1 MPJ-17 98147 USlT 971119 I 1 MPL-33 98147 USlT 971008 I 1 MPL-42 981 47 USIT 980224 I 1 -- -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~~~/{/'~ / MEMORANDUM TO: David Joh0~/ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 11, 1998 THRU' Blair Wondzell, ~ FILE NO: P. I. Supervisor ~('~ol~ ~ FROM' John Spauldin¢'~.¢~, SUBJECT: Petroleum Insp¢/ awolakfe.doc Confidential: Yes BOPE Test Nabors 22E BPX MPU C-39i PTD 97-248 ,NoX Sunday Jan. 11, 1998: I traveled to BPX's Milne Point Unit to witness the BOPE Test on Nabors Rig 22E. The AOGCC BOPE Test .Report is attached for reference. As noted on the test report form,,3 failures were observed. Two valves on th choke manifold and the upper kelly IBOP located in the top drive unit. Also I air pump located on the accumulator was not operating too well and needed attention. Repairs were made on all items and the North Slope AOGCC office was notified within 12 hours. The pad area around the rig is quite small and congested but was well organized. Summary: I witnessed the successful BOPE Test on Nabors 22E, 30 valves, 6.5 hours, 3 failures. Attachments: awolakfe.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initia X Workover: Nabors Rig No. 22E PTD # BPX Rep.: MPC - 39i Rig Rep.: Set @ Location: Sec. X Weekly Other DATE: 1/11/97 97-248 Rig Ph.# 659-4446 Ron Jaye Larry Wurdeman lO T. 13N R. IOE Meridian Urniat Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign ok Upper Kelly/IBOP Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly / IBOP PTD On Location ok Hazard Sec. ok - Ball Type Standing Order Posted ok ' Inside BOP Quan. Pressure P/F 500/5,000 F* 500/5,000 P 500/5,000 P 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 300/3,000 500/5,000 5O0/5, OOO 500/5,000 500/5,000 500/5,000 500/5,000 P P P P 2 P P CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 500/5,000 P* 44 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,050 P Pressure After Closure ~,600 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 30 Trip Tank ok ok System Pressure Attained 2 minutes 55 Pit Level Indicators ok ok Blind Switch Covers: Master: yes Remote: Flow Indicator ok ok Nitgn. Btl's: 8 @ ~900 avg, Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok / sec. sec. yes Number of Failures: 3 ,Test Time:~6.5 Hours. Number of valves tested 30 Repair or Replacement of Failed Equipment will be made within I days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: 2 valves failed on choke manifold; IBO.~ on top drive failed; 1 koomey air pump needs attention valves and IBOP repaired, AOGCC notified 1/12/97 AM Distribution: orig~Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021 L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Awolakfe.xls John H. Spaulding TONY KNOWLE$, GOVERNOR AL&SKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 22, 1997 Chip Alvord Senior Drilling Engincer BP Exploration Alaska. Inc. P O Box 196612 Anchorage, AK 99519-6612 ae~ Milne Point Unit MPC-39i BP Exploration Alaska. Inc. Permit No. 97-248 Sur. Loc. 808'NSL. 2333'WEL. Sec. 10. T13N. RIOE. UM Btmhole Loc. 85'NSL. 4192'WEL. Sec. 10. TI3N. R10E. UM Dear Mr. Alvord: Encloscd is the approved application for permit to drill thc above refercnccd well. The permit to drill docs not exempt you from obtaining additional permits required bv law from other governmental agcncics, and docs not authorize conducting drilling operations until all other required permitting dcterminatio.ns are made. The blowout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be dcmonstratcd under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of thc BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission ma,,' witness thc tests. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosurc CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Consen'ation w/o cncl. STATE OF ALASKA ALASK~ :OIL AND GAS CONSERVATION CU,~MISSION PERMIT TO DRILL 20 AAC 25.005 ila. Type of work [] Drill I--I Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ' [] Re-Entry [] DeepenI []Service I--I Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 45.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047434 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 808' NSL, 2333' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 141' NSL, 4049' WEL, SEC. 10, T13N, R10E, UM MPC-39i At total depth 9. Approximate spud date Amount $200,000.00 85' NSL, 4192' WEL, SEC. 10, T13N, T10E, UM 12/26/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025516, 85'] No Close Approach 2560 7849' MD /7472' ']-VD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 1900' MD Maximum HoleAngle 22.26° Maximum surface 2833 psig, At total depth (TVD) 7097'/3542 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1 # H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4802' 31' 31' 4833' 4680' 1305 sx PF 'E', 185 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 7819' 30' 30' 7849' 7472' 226 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: truemeasuredvertical feetfeet Plugs(measured) 0RJGJNAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor RECEIVED Intermediate Production Liner D~C 79 1997 AJaska Oil & Gas Cons. Anchorage Perforation depth: measured true vertical 120. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the.,f~jregoing~~rect to the best of my knowledge Signed,//~~ ~,,~)~_ .__ Chip Alvord Title Senior Drilling Engineer Date ~c,- ~..'~ / ve,~'J~ Commission Use Only Permit Number I AP, Ndmber Approval Date [ See cover letter ~-- ~.. ~' 50- ~ ~_ ~--, ~ ~ ~' z_./' ~ [~.~ ~_¢) ~ for other requirements Conditions of Approval: Samples Required []Yes I~lNo Mud Log Required []Yes I~ No Hydrogen Sulfide Measures []Yes 'J~ No Directional Survey Required ~Yes r-INo Required Working Pressure for BOPE []2M; I-I3M; ~;~5M; I--ll0M; []15M Other: Original Signed By .,0~.~:id,W .J~hnstOn by order of Approved By L/a~/I[I-W. 'JoRrIs[0, Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: James E. Robertson IMP C-39i Well Plan Summary IType of Well (producer or injector): KUPARUK INJECTOR 564-5159 Surface Location: 808 FSL, 2333 FEL, S10 T13N R10E UM Target Location: 141 FSL, 4049 FEL, S10 T13N R10E UM Bottom Hole Location: 85 FSL, 4192 FEL, S10 T13N R10E UM I AFE Number: 1337119 I I Rig: I Nabors22E Estimated Start Date: 126 DEC 97 I I Operating days to complete: 17 4 ' I I w: I I Well Desitin: Formation Markers: 12.0 IKBE: I 45.7 ft I Kapurak Injector Formation Tops MD TVDSS KOP 3OO 3OO Base of Permafrost 1845 1800 Top of Ugnu Top M Sand Top NA (Target) 4309 4195 Top of Schrader Bluff Sands (EMW 8.6 ppg) OA 4525 4395 Top Seabee 4633 4495 Base of Schrader Bluff Sands (EMW 8.3 ppg) Top of HRZ 6909 6602 MK-19 7071 6752 Top of Kuparuk 'D' 7147 6822 Kuparuk Cap Rock Top of Kuparuk 'C' 7277 6942 Top of Kuparuk 'B' 7312 6975 Top of Kuparuk 'A' 7444 7097 Target Top of Miluveach 7549 7194 Base of Kuparuk TD 7849 7472 TD at 300' MD past base of Kuparuk Casin~l/Tub in~l Program: Hole Size Csg/ WtJFt Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 12-1/4" 9-5/8" 40.0# L80 BTC 4802' 31731' 4833' / 4680' 8-1/2" 7" 26# L80 BTC-MOD 7819' 30'/30' 7849' / 7,472' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at +7097' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 3542 psi (9.6 ppg EMW), is 2833 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: MWD directional from spud to 12-1/4" TD and LWD (GR/Resistivity) from top of Schrader Bluff to 12-1/4" TD. MWD directional and LWD (GR/Resistivity/Density/Neutron/ROP) from top of Kuparuk to 8-1/2" TD with a controlled drilling speed of no more than 200 ft/hr across the Kuparuk sands Cement bond log Mudloggers are NOT required for this well. Mud Program: I Special design considerations I None-SPUD MUD I Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 15 8 10 9 8 to to to to to to to 9.4 80 35 15 30 10 15 Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.0 50 20 10 20 9.5 4-6 Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Also well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 11900' MD Maximum Hole Angle: Close Approach Well: Waste Management: t22.26 NONE Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on B-Pad have been permitted for annular injection. . . . , . . . 11. MP C-391 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 221= drilling rig. NU and function test 20" diverter. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD and LWD GR/Res across Schrader Bluff Sands. Run and cement 9-5/8" casing. ND 20" diverter. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 4000 psig for 30 min. POST DRILL AND CASE: Nabors Rig 22E will run the completion on this well. 1. Complete well with 3-1/2" tubing and a single packer. Details to follow 2. Install Surface Lines and Wellhouse and turn well over to production. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point B-Pad Data Sheet prepared by Pete Van Dusen for information on B pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'C' PAD TO DATE. If hydrates are encountered the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP C-39i. 3. Lost Circulation: There were no reports of lost circulation while DRILLING in the production intervals of previous "C" PAD wells. Several wells at Milne Pt. 'C' Pad have experienced partial to full lost returns while running, circulating and cementing 7" casing. Have the LCM materials on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. 4. Stuck Pipe Potential: Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the corresponding depths at which they were stuck were: C-09 @ 4,427' ss with a mudweight of 9.4 ppg. It was felt the reason for sticking on this well was inadequate hole cleaning. Milne Pt. Well# C-02 @ 3,911' ss with 9.2 ppg mudweight. It was felt the reasons for sticking on this well were hole geometry and new BHA. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: THE KUPARUK IS EXPECTED TO BE NORMALLY PRESSURED. The expected pore pressure for this well is 9.6 ppg EMW (3535 psi @ 7083' TVDSS) in the KUPARUK sands and may be slightly depleted. 6. Directional Drillinq Concerns MP C-39i will be another 12-1/4" by 8-1/2" hole to TD at 7849' md. KOP is 1900' md and a variable build rate from that point will yield a sail angle of 22.26° at 2,870' md. This angle will be maintained to 8-1/2" TD. MP C-39i will have a horizontal displacement of 1993'. 7. Cement Surface hole will be cemented in 2-stages. A 'C' cement for the second stage tail cement will be incorporated into the cementing program only if hydrates are encountered. The 8-1/2" hole will be cemented in a single stage to bring cement 1000' md above the top of the Kuparuk 'C' Sands. MP C-39i 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls spacer weighted to mudweight in the hole. STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 395 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME TOP OF TAIL CEMENT TO ES CEMENTER AT 2100' MD +30% EXCESS. ' STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM 'G' 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE SCHRADER BLUFF + 30% EXCESS + 80'md 9-5/8", 40# capacity for float joints. EST TOC 4200' md STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX #SACKS: YIELD:2.17 ft3/sx MIX WATER: 11.63 910 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 2100' MD TO SURFACE+ 200% EXCESS. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost E NOTE: TOP JOB WILL BE PUMPED IF T,'-'~RS.~.R£ HO C.",'~.'-;,;T RETiJR;~ ~ CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement~spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP C-39i Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 226 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 21 joints of 7" casing (42). This will cover _+300' above the KUPARUK 'C' Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. Anadril 1 Schl umberge~~ 1Zll Eas~ BOls, b: Avenue AJlchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTrO~AL WELL PI~I low SHARED SERVICES DRILLING Well ......... ; ~P0-39 {P05) Field ........ : Mitne Point C~ta~ion..: Minimum ~ature Units ........ : FEET Surface Lat,,: 70,49009329 Surface Lon~.: 149,52481127 Target BHL Legal Description LOCkTIONS - ALASKA Zone: X- Coord 808 FSL 2333 FEL 810 Ti3N R10E UM 141 FSL 4049 FEL S10 T13N RIOE U~ 85 FSL 4L92 FEL $10 T13N R10B UM 558129.~2 556420.00 556277.56 4 Y-Coord 5029090-51 6028~10.00 6028353.29 PROPOSSD ~IIgLL PROFILE STATION MEA~IJRED INCLN DIRF-X~TION IDENTIFECATION DEPTH ANGL~ ~ 0.0O 0.00 BASE PE~F~ST 1845.70 KOP/C~ 1,~0//00 L~0O.00 O.00 248.74 2000.00 L.00 2~8.74 C~ 1.50/lO0 2100,00 2.00 248.74 VERTICAL-DEPTHS TVD SIrS-SEA 0.00 -45.70 1545.70 1800.00 1900.DO 1854_30 1999.99 195~.29 2099.96 2054.26 cxmvm 2.oo/~oo 2200.00 3,50 2~$.7~ 2300.00 5.00 248.74 2400.00 7.00 248.74 2500.00 9.00 ~48.74 2600.~0 11.00 248.74 2199.8{ 2154.~4 2299.56 2253.06 2399.01 2353.31 2498.03 2452.33 2596.51 2550.81 2700.00 15.00 2600.00 15.00 DEPART 0.00 0.00 -0-O0 0.87 3-49 (A31adrill (c)97 MPC39~05 3,2b.5 2:58 PM P) Prepared ..... : 15 Dec 1997 Ve~t sect az.: 248.74 KB elevation.: 45.70 ft Magnetic Dcln: 427.865 (E) Scale Factor.: 0.99990364 Convergence..: +~.~{790633 ANADR1LL AKA-DPC APPROVED FOR PERMITTING ONLY .. COORD/AIATES-FROM A~SKA Zone 4 WE~J~HEAD x Y O.OO N O.OO E 578129.42 6029090.51 O.00 N O.OO ~ 558L29-42 6029090,~1 0.00 N 0.00 E 558129-42 6029090.~1 0.32 8 0.81 N 558~28.61 6029090.19 1.27 S 3,25 W 558126.18 6029089.22 8.29 3-01 S 7.72 15.70 5-69 S 14.63 26.15 9,48 S 24.37 40.07 14.53 S 37.34 57.43 20.81 S 53.52 248.74 2694-32 2648,62 78,22 28.36 248.74 2791.34 2745,64 102.~1 37.13 558121-72 6029087.~ 558114.84 6029084.70 558]05.13 6029080.84 558092.20 6029075.69 558076.07 6029069.27 F~C~ lllb 0.00 lllL 0,00 ZllL D.go 11IL 1.O0 111b lllL 1,50 1IlL 1.50 HS 2. OD HS 2.00 HS 2.00 72.90 W 558056,75 6029061.58 H$ 2.00 95.4~ W 558034.28 6029052.64 HD 2.00 ]~PC-39 [POS) 15 D~c 1997 Page 2 Z <3: STATION MEASURED I~CLk~ DIRECTION VERTICAL-D~/KS ID]KNTIFICATION DEPTH AN~LE AZ/Mb-TH TVD 2900.00 17.00 248.74 2887.46 2841.76 3000.00 19.00 248.74 2982.56 2936.86 3100.00 21.00 248.74 3076.53 3030.83 ~ 2-00/500 L-'UR',ZE 3162.89 22.26 248.74 3134.99 3059.29 NA 4309.00 22.26 248.74 4195.70 4150.80 OA 4525.10 22.26 BAS~ OB 4633.15 22,26 9-5/8' CASIN~ POINT 4833.15 22.26 THRZ 6909.7~ 22.26 B~RZ 6974.62 22.26 MK-19 7071.86 22.26 TKIlD 7147.50 22.26 TKITC 7277.16 22.26 Tk'73'B 7312.81 22.26 SECTION COORDINATES-FROM ALASKA Zone 4 TOOL OL/ DBPART ~EX!,KWJ~D X Y FAC~ 100 129.97 47.13 S 121.53 W 558888.67 6029042.~4 8S 2.00 360.88 58.~3 S 14g.93 W 557979.97 6029031.01 ES 2.00 195.08 70.73 S 181.80 ~ 557948.20 60290~8.37 ~S 2.00 218.26 79.14 S 203.40 N 557926.66 6029DO9.79 ~S 2.00 652.37 236.54 S 607.98 W 557523.37 6028549.24 HB 0.00 248.7~ 246.7~ 24~.74 2~$.74 248.74 ~395~70 4350.00 4495,70 4450.00 4680,80 4635.10 6602.70 6557.00 6662.70 6617.80 734.23 266.22 $ 6~4.26 W $$7447.33 6028815.97 }IS O.OO 775.25 2~1.06 ~ 72~.40 W 55740~.31 6828803.84 ~S 0.00 8~0.91 30~.53 S 793.00 W 5573~8.93 6028~75.~2 BS 0.00 1637.48 593.73 S 1526.05 W 556608.20 6028484.92 ES 0.00 1662.84 602.64 S ~548.94 W 556585.39 6028475.84 ES 248.74 6752.70 6707.00 248.74 6822.70 6777.00 248.74 6942.70 6897.00 ~48.74 6975.70 6930.00 248.74 7097.70 7052.00 1698.87 615.99 $ L583.26 W $56551.~7 6028462.22 1727.52 626.38 S 16D9.96 W 556524.56 6028~51.62 I-IS O.OD 1776.63 644.I9 $ 165~.73 W 556478.93 6028~3.46 HS 0.00 1790.14 6~9.09 S 1668.3~ ~ 556466.3~ 6028428.47 HS 0.00 1848.07 667.19 S 1714.85 ~ 556420.00 602~410.00 HS 0.O0 ~IfA3 7444.64 22.26 TKA2 7469.49 22.26 TKAI 7524.59 22.26 T~LV 7549°45 22.26 T~D 7819.45 ]2.26 (Anadrill (c)97 MPC39PO5 3.2b.5 2:58 l:q,! P) 248.74 7097.70 7052.08 248.74 7L20.70 7075.00 248.74 717~.70 7126.00 248.74 7194.70 7149.00 248.74 7472.35 7426.65 1840.07 667.19 S ~714.85 ~ 556~0.00 60254~0.00 HS 0.00 1849.48 670.60 S ~723.63 W 556~11.26 6028406.52 }IS 0.D0 1870.36 678.17 S 1743.08 W 556391.86 6028395.80 H~ 0.00 lS79.77 68[.58 S 1751-85 W 556383.12 6028395,32 H$ 0.00 1993.~0 722.79 S 1857.75 W 556277.56 6028353.29 0.00 ANADR1LL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN 5 i MPC-39 (PO5) ~ VERTICAL SECTION VIEW. section at:' ~4~.74 TVD Scale · 't inch - ~000 feet_ o-- . .... Dep Scale.' J. :inch : '1000 feet Drawn · J5 Dec ~997 b--- . , AnadP i 11 ~-'- ., MaM~ep ]denttf~cai~on MD BKB SECTN [N~LN A) KB 0 0 0 O. O0 Fi) KOP/OUI:IVE 1,O0/JO0 ~qo0 ~go0 -0 0,00 ~-- -- -- ~ m mm m m -- _ -- -- m m m ~ ---- ~ m m m mm---- -- 8 -' -~t'p~ M~Sl" ~ C) CURVE ~,50/~00 2~00 2~00 3 2.00 C _. D) CURVE 2.00/~00 2300 2300 16 5.00 £J END 2.00/JO0 CURVE 3~83 3~35 2~8 2~,26 D '- F) 9-B/8" CASING POINT ~833 468J 85t 22.26 GJ TARGET~**~,~,~**~ 7445 7098 1~40 2~, 26 ~ .... H] TO 7849 747~ J993 22.26 I ~- . APPROVi~D .'l-- . ~;;. .......... _ ~-,J~ FO J PEoNLyJM J~"T~N,:..- - ' ~-~,~ PL,~N ~+ ~ B~ OB 4498 --~ ~. . :: ...... - .... .. .. ~. .... Section Departure . . ~97 H~gP~5 3.~,5 2:'53 ~ ~ ' " ' .... (~nadrill ! 1;"0 39~'d Od(][ ]]I~d~N~ 091:g-~g-LOG l:P :'l;'l; LGGT,/8T,/'E,T, .... !SHARED SERV CE'S DR'Z'LLIN$ " '.',~ i . i i i ii II. ii . mi I I III I Ill II I VERTICAL SECTION VIEW io - ' '~ ........ ~"~ ........ '=~-' ~-'~'~ Section at: 24B,74' TVD Scale.: ! inch = 100 fee~ )o -- Dap Sca]e,: 1 inch ~ lO0 feet ............... h~-~ga ~rawn ..... : ~,5 Dec Jgg7 , O-- N~rkee Id~n~fJ~n MD BK~ SECTN INDLN j A] TARGET~***~ 7~45 70g~ ~B40 2~, 2G J B) TD 7B49 7472 ]gg3 2~. 26 0-~ . ,, ~A~ ' ~ ~ i , _ ~=,m_ _ ~ ...... , ~ '~ 'T~r -fif ............... I ~ " 0 1650 t700 t750 ~800 ~O50 t900 t950 ~000 2050 2~00 ~I50 2200 2250 8300 I ~ .... ~-~.. Section Departure . -- i ~ _._ mi GO 3Dk~cl O~(I 33121CIk/N~ OCj'[:2:-'J;,J;,l~-Z. 06 ~b 'P'I: LS6T,/BT,/gT, i J--- "SHAREd ..... SER /-TCE'S"DI Z'L'LING ~'_..__'.__~ ....... ~'__..~:~::~-:..:---~".. ~:: ..... :. ........ .::~ ...... ~ A) KB 0 0 ~ 0 E ~' B) KOP/CU~E ~.00/~00 ~0 0 H 0 E ~ C~ ~VE ~.50/~00 ~100 1 S ~ H m ~] ~URVE 2.O0/i00 ~300 6 S 15 H E) END 2.00/~00 CURVE 3{63 79 S 203 ~ F) 9-5/8" CASING ~INT 4B~3 309 S 79~ N ~J I~RGEf~*~*~ 7445 667 S J7t5 H R] rD 7849 723 s [8~ H Q_ ANADRiLL AKA-DPC APPROVED FOR P~RMITTING ONLY PLAN ~ ....... ~ ..... j iiii .i II I Jill I I II I Anadr ~ 1] Sch ] u~berger PLAN VlE~ IIIII _ CLOSU~tE. · 1993 feet at Azimuth 248.74 DECL~NAT]DN.' +27.865 [E) SCALE ' ! inch: 300 feet DRAWN ' 15 Dec 1997 2550 2400 2250 2100 t950 JB00 2650 1500 1~0 1200 JO50 900 750 GO0 4§0 300 ~50 O ~50 <- WEST ' EAST -> (~ ~o~ ~.m.~ ~: ~ ~ p) .................................... DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 111897 CA111897F 100.00 100.00 PYMT COMMENTS: accompany 'permit to d?il!' application HANDLINQ INST: s/h kathy campoamo~, x5i22 HE Alt'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ ~ t mm mm t mm mm o WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~_~'.~,.~",/~>~__~ INIT CLASS WELL NAME,,~,,~__~ -- ~-~¢2" PROGRAM: exp [] dev [3 redrll [] serv~wellbore seg E: ann. disposal para req [', GEOL AREA ~"~,~ UNIT# ,///,~',,-~ ON/OFF SHORE <~/L) ADMINISTRATION 1 1 AB D ,TE 1 1. Permit fee attached ...................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit .......... 8. If deviated, is wellbore plat included ............ 9. Operator only affected party ................... 0. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ........ 2. Permit can be issued without administrative approval ...... 3. Can permit be approved before 15-day wait ........... N Y N Y N ENGINEERING APPR D?¢2./~....' 14. Conductor string provided ................... ~ NN 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & sud csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ...... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ...... ,~-.-~4~',-,, ...... 26. BOPE press rating appropriate; test to ~u v[.,,, psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... YY N,/ ~ ) ,,/-7 31 Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones. ; ; ............ ; ...~ 33. Seabed condition survey (if off-shore)..' Y N 34, Contact name/phone for we.eklyprogress repods ....... Y N lexploratory only] REMARKS GEOLOGY' ENGINEERING: COMMISSION: JDH ~ RNC~ CO Comments/Instructions' HOW/lit - A \FC)RM?,~r'tu4,1 ~:t rr, v (~!/(~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER ....... SCHLUMBERGER COMPANY NAME : BP EXPLORATION INC. WELL NAME : MPC-39 FIELD NAME : MILNE POINT BOROUGH . NORTH SLOPE STATE : ALASKA API NUMBER : 500292284900 REFERENCE NO : 98410 Date LIS Tape v~rification Listing Schlumberger Alaska Computing Center 17-AUG-1998 gl :20 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/17 ORIGIN : FLIC REEL NAME : 98410 CONTI.~JATION # : PREVIOUS REEL : CO~ : BP EXPLORATION INC, MPC-39, MILNE POINT, API #50-029-22849-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/17 ORIGIN : FLIC TAPE NAME : 98410 CONTINUATION # : 1 PREVIOUS TAPE : CO~2~=NT : BP EXPLORATION INC, MPC-39, MILNE POINT, API #50-029-22849-00 TAPE HEADER Milne Point CASED HOLE WIRELINE LOGS WELL NA2~E : MPC-39 API NU~iBER: 500292284900 OPERATOR: BP Exploration Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE '. 17 -AUG- 98 JOB N-UMBER: 98410 LOGGING ENGINEER: Carl o Yon OPERATOR WITNESS: Herb Thacker SURFACE LOCATION SECTION: 10 TOWNSHIP '. 13N RANGE: 10E FNL : FSL: 808 FEL: 2333 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 47.10 DERRICK FLOOR: 46.10 GROUND LEVEL: 16.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 7884 . 0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape v~rification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NU~CBER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: 17-AUG-1998 ~1:20 .......... EQUIVALENT UNSHIFTED DEPTH .......... CONTAINED HEREIN IS THE LDWG FORMATTED EDIT OF THE PDC GAI4MA RAY DATA ACQUIRED ON BP EXPLORATIONS MPC-39 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL LOG FOR THIS WELL. ONLY THE MAIN LOG FILE IS PRESENTED, NO REPEAT FILE DATA IS AVAILABLE FROM THE FIELD ENGINEER. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUIVIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO?4~ARY LDWG TOOL CODE START DEPTH STOP DEPTH CET 7700.0 3785.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NO?4BER : BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... CET LIS Tape ~=rification Listing Schlumberger Alaska Computing Center 17-AUG-1998 Al :20 PAGE '. REMARKS: THIS FILE CONTAINS THE MAIN PASS PDC GAMMA RAY. NO DEPTH CORRECTIONS HAVE BEEN MADE TO THIS DATA. ALL CURVES HAVE BEEN CLIPPED OF INVALID READING PRIOR TO FIRST TOOL READING AND AFTER LAST READING. THIS IS THE PRIMARY DEPTH CONTROL DATA FOR THIS WELL. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAFZE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022563 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1022563 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1022563 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1022563 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7700.000 GRCH. CET -999.250 TENS. CET 2725.000 CCL.CET 0.385 LIS Tape verification Listing Schlumberger Alaska Computing Center DEPT. 7000.000 GRCH. CET DEPT. 6000.000 GRCH. CET DEPT. 5000. 000 GRCH. CET DEPT. 4000.000 GRCH. CET DEPT. 3785.000 GRCH. CET 17-AUG-1998 11:20 102.580 TENS.CET 69.916 TENS. CET 38. 552 TENS. CET 18.950 TENS . CET 21.033 TENS. CET 2570. 000 2315.000 2005.000 1741.000 1661.000 CCL.CET CCL.CET CCL.CET CCL.CET CCL.CET PAGE: -0. 192 -2.219 0.079 -0. 010 0.075 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/08/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NANZE : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/08/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH USIT 7700.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH .......... 3785.0 18-JAN-98 8C0-609 1200 18-JAN-98 7781.0 LIS Tape ~=rification Listing Schlumberger Alaska Computing Center 17-AUG-1998 1~ :20 PAGE: TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 3785.0 7700.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA2~MA RAY USIT ~TRA SONIC IMAGER $ TOOL NUMBER SGH-K 465 USIC-A 722 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 7884.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Brine NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): THIS IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. SPERRY SUN LOG WAS USED ONLY AS A REFERENCE. PBTD WAS NOT TAGGED BECAUSE OF USIT SUB AT BOTTOM OF TOOL STRING. LOGGED FROM 7700', CE~NT TOP WAS FOUND @ 5000'. THIS FILE CONTAINS THE RAW MAIN LOG DATA. $ LIS Tape v~rification Listing Schlumberger Alaska Computing Center 17-AUG-1998 iL :20 PAGE: 6 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022563 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1022563 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 1022563 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 1022563 O0 000 O0 0 2 1 1 4 68 0000000000 Ttff4~PS1 IN 1022563 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7712.000 THMN. PS1 0.343 DEPT. 7000.000 ~.PS1 0.346 DEPT. 6000.000 TP24N. PS1 0.353 GR.PS1 GR.PS1 GR.PS1 63.801 TENS.PSI 2301.000 CCL.PS1 102.580 TENS.PSi 2570.000 CCL.PS1 69.916 TENS.PSi 2315.000 CCL.PS1 O. 026 - O. 192 -2.219 LIS Tape ~=rification Listing Schlumberger Alaska Computing Center 17-AUG-1998 IA :20 PAGE: DEPT. 5000.000 THMN. PS1 0.354 DEPT. 4000.000 77flVlN. PS1 0.342 DEPT. 3784.000 TH~fN. PS1 0.346 GR. PS1 GR. PS1 GR. PS1 38.552 TENS.PSi 18.950 TENS.PSi 15.575 TENS.PSi 2005.000 1741.000 1706.000 CCL. PS1 CCL. PS1 CCL.PS1 O. 079 -0. 010 0.003 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE · 98/08/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 98/08/17 ORIGIN ' FLIC TAPE NAME : 98410 CO~FfI~ffJATION# : ! PREVIOUS TAPE : COMMF2VT ' BP EXPLORATION INC, MPC-39, MILNE POINT, API #50-029-22849-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/17 ORIGIN ' FLIC REEL NAME : 98410 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION INC, MPC-39, MILNE POINT, API #50-029-22849-00 Sperry-Sun Drilling Services LIS Scan Utility Mon Mar 23 13:14:00 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80077 PIEPER JAYE D~to...~~_ MPC- 39 500292284900 BP EXPLORATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 23-MAR-98 MWD RUN 2 AK-MM-80077 PIEPER LOCKWOOD 10 13N 10E 8O8 2333 .00 46.10 16.60 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 4821.0 8.500 7922.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7922'MD, 7537'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORYIATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 800 - 1200 PPM 8.4 - 10.5 PPG 14545 PPM 1.0 G/CC 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 46.0 FET 103.5 RPD 103.5 RPM 103.5 RPS 103.5 RPX 103.5 ROP 103.5 FCNT 4813.0 NCNT 4813.0 NPHI 4813.0 PEF 4813.5 DRHO 4813.5 RHOB 4813.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 46.0 56.0 3800.0 3810.0 3821.0 3829.5 3831.5 3839.0 3873.5 ~- 3881.0 3894.5 3903.0 3944.0 3954.5 3981.0 3991.0 4038.0 4040.0 4062.5 4069.5 4076.5 4087.0 4196.5 4203.5 4461.5 4471.5 4492.5 4499.5 4536.5 4543.0 4576.0 4582.5 4581.5 4586.5 4809.0 4817.5 4812.5 4819.5 4846.0 4851.0 4849.5 4853.5 4853.0 4858.0 4856 5 4863.5 4872 5 4879.5 4875 0 4883.5 4928 5 4934.5 4931 5 4938.0 4936 5 4943.5 4988 5 4997.5 4991 0 4999.0 5005 0 5011.5 5091 0 5098.0 5093 0 5100.5 5095 5 5101.5 5405 0 5410.5 STOP DEPTH 7858.5 7839.0 7839.0 7839.0 7839.0 7839.0 7921.0 7814.5 7814.5 7814.5 7847.5 7847.5 7847.5 EQUIVALENT UNSHIFTED DEPTH ...... 5541.0 5549.0 5556.5 5671.0 5718.0 5720.0 5721.0 5748.5 5813.0 5977.5 5979.0 5982.5 5985 5 5991 0 6022 0 6185 0 6306 0 6308 0 6312.0 6564.5 6566.0 6578.5 6581 5 6584 0 6585 5 6596 5 6606 0 6608 5 6612 5 6616.0 6620.0 6621.0 6630.0 6634.0 6636.0 6639.5 6643.0 6646 0 6675 0 6684 5 6693 5 6702 5 6705 0 6709 5 6718 5 6721.0 6727 5 6730 5 6734 0 6737 5 6740 0 6742 0 6746 5 6748 5 6750 5 6752 5 6766.0 6774.5 6780.0 6784.5 6787.5 5548.5 5558.0 5564.0 5679.0 5726.5 5728.0 5730.5 5756 5 5819 5 5982 0 5985 0 5989 5 5991 5 5994.0 6024.0 6190.5 6312.0 6314.0 6317.0 6567.0 6568.5 6583.5 6586.5 6589.5 6590.5 6601.0 6611.5 6613.5 6617.0 6621.0 6624.5 6627.5 6634.0 6638.5 6640.5 6643.5 6648.5 6651.5 6679.5 6688.0 6698.5 6707.0 6708.5 6713.5 6722.5 6726.0 6733.0 6736.0 6738.0 6742.5 6744.5 6746.0 6752.0 6753.0 6755.0 6756.5 6770.0 6779.5 6784.5 6789.5 6792.5 6791 6794 6796 6799 6801 6803 6805 6809 6836 6839 6841 6844 6846 6849 6851 6855 6859 6864 6867 6870 6873 6876 6879 6881 6884 6886 6889 6893 6895 6897 6902 6903 6905 6908 6910 6913 6915 6919 6920 6923 6926 6929 6931 6934 6936 6938 6939 6942 6946 6949 6951 6955 6956 6983 6988 6994 6996 7000 7003 7006 7009 .0 .0 .5 .5 .0 .5 .0 .5 .0 .0 .5 .0 .0 .5 .5 .0 .0 .0 .5 .0 .5 .5 .0 .0 .0 .5 .5 .5 .5 .5 .0 .0 .0 .0 .5 .5 .5 .0 .5 .5 .5 .5 .5 .0 .5 0 5 0 5 0 0 0 5 5 0 0 5 5 0 0 0 6795.0 6798.5 6802 0 6804 0 6806 0 6807 5 6809 0 6814 5 6840 0 6843.5 6847.0 6848.0 6850.5 6854.0 6857.0 6861.0 6863.5 6868.0 6872.5 6874 5 6878 5 6881 0 6882 5 6886 5 6888 5 6891 5 6894 0 6898 0 6899 5 6902 0 6906 0 6907 5 6909 0 6912 5 6915 0 6917 5 6920 0 6923.5 6926 5 6928 5 6931 5 6934 0 6936 5 6939 5 6941 0 6944 0 6945 0 6947 0 6951 5 6954 0 6955.5 6959.5 6961 5 6988 0 6993 0 6999 0 7002 5 7007 0 7007 5 7010 0 7014 5 7013.0 701 7021.5 702 7023.5 702 7026.0 703 7028.5 703 7030.0 703 7096.0 710 7099.5 710 7101.5 710 7106.0 710 7120.0 712 7123.0 712 7125.0 712 7144.0 714 7146.0 715 7148.0 715 7150.0 715 7152.0 715 7153.5 715 7155.5 715 7157.0 716 7163.5 716 7176.5 718 7200.0 720 7208.0 721 7216.5 722 7233.5 723 7237.0 724 7240.0 724 7243.0 724 7245.0 724 7251.0 725 7285.5 728 7287.0 729 7322.5 732 7325.0 732 7331.0 733 7333.0 733 7335.5 733 7337.0 734 7339.0 734 7345.0 734 7348.5 735 7350.0 735 501.0 750 7503 .5 750 7510.0 751 7514.0 751 7516.5 751 7519.5 752 7524.0 752 7525.5 752 7530.0 753 7533 .5 753 7536.0 754 7542.0 754 7543.5 754 7551.0 755 7553.0 755 7555.0 755 7561.0 756 9.5 6.0 8.0 1.5 3.0 4.0 1.5 3.5 5.0 9.0 5.0 7.0 9.5 8.5 0.0 2.5 4.5 6.0 8.0 9.5 1.5 8.0 0.5 4.0 2.5 1.0 8.0 1.5 4.0 7.5 9.0 4.5 9.0 0.5 6.5 9.0 4.5 7.5 9.0 0.5 4.0 9.0 2.0 4.0 4.0 6.5 3.5 6.0 9.5 3.5 6 0 9 0 6 0 7 5 0 0 6 0 7 0 5 0 6 5 8 5 4.5 7563.5 7565.5 7576.5 7600.0 7602.0 7604.5 7607.5 7609.0 7611.0 7612.5 7616.5 7618.5 7858.5 $ MERGED DATA SOURCE' PBU TOOL CODE $ REMARKS: 7567 0 7570 5 7580 0 7603 5 7605 0 7607 5 7610 5 7611 5 7613 5 7616 0 7618 5 7621 5 7861 5 BIT RUN NO MERGE TOP MERGE BASE 1 113.0 4839.0 2 4839.0 7923.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHM~ 4 1 68 RPD MWD OH~M 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 46 7921 ROP 5.0362 7504.1 GR 12.739 465.078 RPX 0.2874 2000 RPS 0.1795 2000 Mean Nsam 3983.5 15751 253.945 15636 73.1405 15626 6.65546 15472 8.44432 15472 First Reading 46 103.5 46 103 .5 103 .5 Last Reading 7921 7921 7858.5 7839 7839 RPM 0.1523 2000 11.6774 15472 RPD 0.0775 2000 27.0394 15472 FET 0.1207 67.3725 1.39692 15472 NPHI 18.9528 81.7622 43.0532 6004 NCNT 2112 3608 2639.22 6004 FCNT 418 1195 630.462 6004 RHOB 1.5267 3.0301 2.40485 6069 DRHO -0.124 0.3086 0.0319193 6069 PEF 0.8661 6.8305 2.27525 6069 103.5 103.5 103.5 4813 4813 4813 4813.5 4813.5 4813.5 7839 7839 7839 7814.5 7814.5 7814.5 7847.5 7847.5 7847.5 First Reading For Entire File .......... 46 Last Reading For Entire File ........... 7921 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 56.0 4780 0 FET 113.5 4773 0 RPD 113 . 5 4773 0 RPM 113 . 5 4773 0 RPS 113.5 4773 0 RPX 113 . 5 4773 0 ROP 113.5 4839 0 $ LOG HEADER DATA DATE LOGGED: 10-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND cASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 4839.0 113.0 4839.0 .1 22.9 TOOL NUMBER P0918CRG8 P0918CRG8 12.250 12.3 S PUD 9.20 64.0 9.0 2500 4.8 1.700 1.600 1.600 1.900 30.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD ROP FET MWD 1 MBID 1 MWD 1 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 20 24 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 56 12.739 0 2874 0 1795 0 1523 0 1458 5 0362 0 1207 Max Mean 4839 2447.5 108.978 55.3382 52.4403 8.72123 184.153 12.081 2000 17.772 2000 23.9192 7504.1 267.85 5.5361 0.718088 Nsa/R 9567 9449 9320 9320 9320 9320 9452 9320 First Reading 56 56 113.5 113.5 113.5 113.5 113.5 113.5 Last Reading 4839 4780 4773 4773 4773 4773 4839 4773 First Reading For Entire File .......... 56 Last Reading For Entire File ........... 4839 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4690.5 RPD 4690.5 RPM 4690.5 RPS 4690.5 RPX 4690.5 GR 4711.0 ROP 4769.0 STOP DEPTH 7842.0 7842.0 7842.0 7842.0 7842.0 7861.5 7923.0 FCNT 4820.0 NCNT 4820.0 NPHI 4820.0 PEF 4820.5 DRHO 4820.5 RHOB 4820.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIM UMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7817.5 7817.5 7817.5 7850.5 7850.5 7850.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMI~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 14-JAN-98 5.07 5.46 MEMORY 7923.0 4839.0 7923.0 20.3 24.7 TOOL NUMBER P0915CRLGM6 P0915CRLGM6 P0915CRLGM6 P0915CRLGM6 8.500 8.5 WTED LSND 10.40 45.0 9.8 1000 4.0 2.2O0 1.480 1.800 2.300 50.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 AAPI 4 1 RPX MWD 2 OHMM 4 1 RPS MWD 2 OH/~M 4 1 RPM MWD 2 OHMM 4 1 RPD MWD 2 OHMM 4 1 NPHI MWD 2 P.U. 4 1 ROP MWD 2 FT/H 4 1 FET MWD 2 HOUR 4 1 FCNT MWD 2 CNTS 4 1 NCNT MWD 2 CNTS 4 1 RHOB MWD 2 G/CC 4 1 DRHO MWD 2 G/CC 4 1 PEF MWD 2 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max Mean DEPT 4690.5 7923 6306.75 GR 29.2564 491.754 99.2258 RPX 0.5975 2000 3.0879 RPS 0.5736 2000 2.91236 RPM 0.5119 58.7105 2.72425 RPD 0.0775 2000 68.5842 NPHI 18.939 81.7622 43.0443 ROP 10.3308 900.976 236.562 FET 0.2286 67.8136 4.08285 FCNT 418 1195 630.522 NCNT 2112 3608 2638.69 RHOB 1.5267 3.0301 2.40499 DRHO -0.124 0.3086 0.0319885 PEF 0.8661 6.8305 2.27501 First Last Nsam Reading Reading 6466 4690.5 7923 6302 4711 7861.5 6304 4690.5 7842 6304 4690.5 7842 6304 4690.5 7842 6304 4690.5 7842 5996 4820 7817.5 6309 4769 7923 6304 4690.5 7842 5996 4820 7817.5 5996 4820 7817.5 6061 4820.5 7850.5 6061 4820.5 7850.5 6061 4820.5 7850.5 First Reading For Entire File .......... 4690.5 Last Reading For Entire File ........... 7923 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/03/23 Origin .................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File