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225-005
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT H-29B JBR 06/10/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 2 3/8 X 3 1/2" VBR's had to be functioned. FP Test Results TEST DATA Rig Rep:N. Wheeler/T.JonesOperator:Hilcorp North Slope, LLC Operator Rep:J.Perl/D. Johnson Rig Owner/Rig No.:Nabors CDR2AC PTD#:2250050 DATE:4/22/2025 Type Operation:DRILL Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE250425104447 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2323 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8 P Annular Preventer 1 7 1/16 P #1 Rams 1 blind/shear P #2 Rams 1 2 3/8 ps P #3 Rams 1 2 3/8 X 3 1/2 FP #4 Rams 1 2 3/8 ps P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 2 2 1/16 P Kill Line Valves 2 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2275 200 PSI Attained P19 Full Pressure Attained P60 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@ 1990 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P4 #1 Rams P4 #2 Rams P5 #3 Rams P5 #4 Rams P5 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9 9999 FP 2 3/8 X 3 1/2" VBR's From:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:RE: [EXTERNAL] Re: KU 41-08 (PTD# 224-005) - Comingle Date:Tuesday, June 24, 2025 5:16:00 PM Attachments:image003.png Approved. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <Stefan.Reed@hilcorp.com> Sent: Tuesday, June 24, 2025 3:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] Re: KU 41-08 (PTD# 224-005) - Comingle Thanks Bryan, Also, we are going to move the plug set depth up hole to10290’ from the proposed ~10,300’ to avoid a collar. Still within 50’ of the top perforation (10,323’) if we need to abandon the lower pool for some reason. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, June 24, 2025 8:08 AM To: Stefan Reed <Stefan.Reed@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] Re: KU 41-08 (PTD# 224-005) - Comingle Stefan, Approved. Bryan Sent from my iPhone On Jun 23, 2025, at 10:34 AM, Stefan Reed <Stefan.Reed@hilcorp.com> wrote: Bryan, The attached approved sundry (325-363) for well KU 41-08(PTD# 224-005) calls for 25’ of cement on top of the proposed CBP @ ~10,310’ isolating Tyonek Gas Pool 1. Hilcorp requests to forgo the 25’ of cement, treat this as commingling of pools and perform required production logs per CO 510C Rule 5. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 <image001.png> Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate. <KU 41-08 AOGCC 10-403 325-363 PTD 224-005 Approved 06-20-25.pdf> The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' From:Lau, Jack J (OGC) To:Brenden Swensen Cc:Torin Roschinger; Oliver Sternicki; Joseph Lastufka; PB Wells Integrity Subject:RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Date:Friday, May 30, 2025 12:32:05 PM Thanks for the update Brenden. You’re proposed change is noted. Jack From: Brenden Swensen <Brenden.Swensen@hilcorp.com> Sent: Friday, May 30, 2025 12:30 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Hello Jack, H-29B is currently flowing competitively after the 3rd set of perforations. This set of perforations is flowing roughly 29mmscf/d into the high pressure header. Wireline is scheduled to set our patch middle of next week. With the current production rate, we will not need a full set of gas lift valves. I intend to swap out the POGLM portion of the patch for blank pipe which will open up the ID restriction from ~1.90” to 2.37” ID. This will give us better optionality for plug sets and future perforations. We will reflect this in our final 10-404/10-407 paperwork on the final schematic. If you have any questions or concerns with this change, please let me know. Thanks, Brenden Swensen GC2 Main Field Ops Engineer (HJNQRU pads) 907-748-8581 From: Brenden Swensen <brenden.swensen@hilcorp.com> Sent: Monday, May 19, 2025 3:41 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Jack, Just to include you on updates. We executed the extended add perforation over the weekend. Tests today look uncompetitive. We are planning to do the first contingent perforation interval from our table below with wireline, likely tomorrow or Wednesday. If you have any questions, please reach out. Thanks, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Brenden Swensen GC2 Main Field Ops Engineer (HJNQRU pads) 907-748-8581 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, May 14, 2025 11:39 AM To: Brenden Swensen <brenden.swensen@hilcorp.com> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Brenden – Your request below is approved for: Utilizing the approved extended perforating procedure in the 10-401 for next perf interval in the same pool Continuation of 30 day under evaluation period 30 day extension from this request on submittal of 10-407 for PTD# 225-005 Jack From: Brenden Swensen <brenden.swensen@hilcorp.com> Sent: Monday, May 12, 2025 3:14 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Hello Jack, Summary of request Utilize extended perforating procedure in 10-401 for next perf interval Continuation of 30 day under evaluation period 30 day extension from this request on submittal of 10-407 for PTD# 225-005 Justifications After the initial perforations, we placed H-29B online on 5/11/2025. The well came online at 95% water cut producing marginal oil rate. Total fluid was 4,563 bfpd and 20.8mmscf/d formation gas. Based on these rates we plan to proceed with the next perforation interval. The 10-401 / PTD #225-005 includes the service coil extended add perforation procedure. I would like to utilize the PTD to perform the next interval as the 10-403 #325-265 for the cement squeeze only covered the toe perforation and did not contain extended add perforation verbiage. The first perforations were Ivishak Zone 2C and perforated 11,795-11,810’ MD (15’). The next set of proposed perforations are 120’ in Ivishak Zone 4. Sand TOP MD BOT MD TOP TVDss BOT TVDss Pool Order to Shoot Comments Gross Interval Net Guns Z4A 11100 11220 8682 8681 Ivishak 1 Ext Perf Run 120 120 Z2C 10184 10214 8826 8821 Ivishak Cont.Normal Perf Run 30 30 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Z2C 9440 9460 8828 8835 Ivishak Cont.Normal Perf Run 20 20 I would like to continue the existing 30 day under eval period for the next set of perforations. The reasoning for continuing under eval is the same – if the next interval is uncompetitive, perforating with 2” guns prior to setting the POGLM is preferred. I anticipate being able to perforate the next stage in the next 5-7 days. Thanks, Brenden Swensen GC2 Main Field Ops Engineer (HJNQRU pads) 907-748-8581 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, May 12, 2025 1:45 PM To: Brenden Swensen <brenden.swensen@hilcorp.com> Subject: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm From: Lau, Jack J (OGC) Sent: Thursday, May 8, 2025 7:59 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com> Subject: RE: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Oliver, Your plan below to flow with TxIA is approved for a 30 day flow period. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, May 8, 2025 7:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com> Subject: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Jack, H-29B (PTD# 225005) was recently sidetracked by CTD in April 2025. The upper wellbore has known TxIA comm at GLM station #3 ( 6080’ MD) that we have been unable to fix with gas lift work and will require a POGLM to be set across the mandrel for repair. The well passed a CMIT-TxIA on 2/23/2025 to 2664 psi proving secondary barrier integrity. There are some prospective toe perfs in the new well that we would like to test prior to setting the POGLM due to the risk that if these initial perfs are unproductive. With the ID of the POGLM at 1.905” and spent 2” perf guns swell at 2.171”, we would have to remove the POGLM to reperf and then have to reset the POGLM. We would like to request permission to flow the well for up to 30 days to test production of these initial perforations prior to repairing the leak at GLM #3. Gas lift may be required. IA pressure will be maintained below NOL. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 anintended 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 havereceived 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 thismessage. 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 thismessage 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 virusand other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended 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 havereceived 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 thismessage. 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 thismessage 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 virusand other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended 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 havereceived 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 thismessage. 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 thismessage 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 virusand other checks as it considers appropriate. David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU H-29B PTD: 225-005 API: 50-029-21813-02-00 FINAL LWD FORMATION EVALUATION LOGS (04/10/2025 to 04/22/2025) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. 225-005 T40446 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.27 11:10:33 -08'00' From:Lau, Jack J (OGC) To:Brenden Swensen Cc:Torin Roschinger; Oliver Sternicki; Joseph Lastufka; PB Wells Integrity Subject:RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Date:Wednesday, May 14, 2025 11:39:00 AM Brenden – Your request below is approved for: Utilizing the approved extended perforating procedure in the 10-401 for next perf interval in the same pool Continuation of 30 day under evaluation period 30 day extension from this request on submittal of 10-407 for PTD# 225-005 Jack From: Brenden Swensen <brenden.swensen@hilcorp.com> Sent: Monday, May 12, 2025 3:14 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Hello Jack, Summary of request Utilize extended perforating procedure in 10-401 for next perf interval Continuation of 30 day under evaluation period 30 day extension from this request on submittal of 10-407 for PTD# 225-005 Justifications After the initial perforations, we placed H-29B online on 5/11/2025. The well came online at 95% water cut producing marginal oil rate. Total fluid was 4,563 bfpd and 20.8mmscf/d formation gas. Based on these rates we plan to proceed with the next perforation interval. The 10-401 / PTD #225-005 includes the service coil extended add perforation procedure. I would like to utilize the PTD to perform the next interval as the 10-403 #325-265 for the cement squeeze only covered the toe perforation and did not contain extended add perforation verbiage. The first perforations were Ivishak Zone 2C and perforated 11,795-11,810’ MD (15’). The next set of proposed perforations are 120’ in Ivishak Zone 4. Sand TOP MD BOT MD TOP TVDss BOT TVDss Pool Order to Shoot Comments Gross Interval Net Guns Z4A 11100 11220 8682 8681 Ivishak 1 Ext Perf Run 120 120 Z2C 10184 10214 8826 8821 Ivishak Cont.Normal Perf Run 30 30 Z2C 9440 9460 8828 8835 Ivishak Cont.Normal Perf Run 20 20 I would like to continue the existing 30 day under eval period for the next set of perforations. The reasoning for continuing under eval is the same – if the next interval is uncompetitive, perforating with 2” guns prior to setting the POGLM is preferred. I anticipate being able to perforate the next stage in the next 5-7 days. Thanks, Brenden Swensen GC2 Main Field Ops Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. (HJNQRU pads) 907-748-8581 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, May 12, 2025 1:45 PM To: Brenden Swensen <brenden.swensen@hilcorp.com> Subject: [EXTERNAL] FW: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm From: Lau, Jack J (OGC) Sent: Thursday, May 8, 2025 7:59 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com> Subject: RE: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Oliver, Your plan below to flow with TxIA is approved for a 30 day flow period. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, May 8, 2025 7:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com> Subject: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Jack, H-29B (PTD# 225005) was recently sidetracked by CTD in April 2025. The upper wellbore has known TxIA comm at GLM station #3 ( 6080’ MD) that we have been unable to fix with gas lift work and will require a POGLM to be set across the mandrel for repair. The well passed a CMIT-TxIA on 2/23/2025 to 2664 psi proving secondary barrier integrity. There are some prospective toe perfs in the new well that we would like to test prior to setting the POGLM due to the risk that if these initial perfs are unproductive. With the ID of the POGLM at 1.905” and spent 2” perf guns swell at 2.171”, we would have to remove the POGLM to reperf and then have to reset the POGLM. We would like to request permission to flow the well for up to 30 days to test production of these initial perforations prior to repairing the leak at GLM #3. Gas lift may be required. IA pressure will be maintained below NOL. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 anintended 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 havereceived 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 thismessage. 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 thismessage 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 virusand other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended 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 havereceived 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 thismessage. 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 thismessage 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 virusand other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:Oliver Sternicki Cc:PB Wells Integrity; Hunter Gates Subject:RE: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Date:Thursday, May 8, 2025 7:59:22 AM Oliver, Your plan below to flow with TxIA is approved for a 30 day flow period. Jack From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, May 8, 2025 7:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com> Subject: H-29B (PTD# 225005) Request to place on production under evaluation with TxIA comm Jack, H-29B (PTD# 225005) was recently sidetracked by CTD in April 2025. The upper wellbore has known TxIA comm at GLM station #3 ( 6080’ MD) that we have been unable to fix with gas lift work and will require a POGLM to be set across the mandrel for repair. The well passed a CMIT-TxIA on 2/23/2025 to 2664 psi proving secondary barrier integrity. There are some prospective toe perfs in the new well that we would like to test prior to setting the POGLM due to the risk that if these initial perfs are unproductive. With the ID of the POGLM at 1.905” and spent 2” perf guns swell at 2.171”, we would have to remove the POGLM to reperf and then have to reset the POGLM. We would like to request permission to flow the well for up to 30 days to test production of these initial perforations prior to repairing the leak at GLM #3. Gas lift may be required. IA pressure will be maintained below NOL. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.28 15:30:02 - 08'00' Torin Roschinger (4662) PRUDHOE OIL RUSH 325-265 By Grace Christianson at 7:39 am, Apr 29, 2025 10-407 SFD 4/29/2025 Send CBL log and interpretation to the AOGCC DSR-4/29/25JJL 4/29/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.30 14:58:22 -08'00' 04/30/25 RBDMS JSB 050125 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Sean Mclaughlin Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay, Prudhoe Oil, PBU H-29B Hilcorp North Slope, LLC Permit to Drill Number: 225-005 Surface Location: 1006’ FNL, 1265’ FEL, Sec. 21, T11N, R13E, UM, AK Bottomhole Location: 729’ FSL, 539’ FWL, Sec. 16, T11N, R13E, UM, AK Dear Mr.McLaughlin Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for all well logs run must be submitted to the AOGCCwithin 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this day of )HEUXDU\, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.10 15:26:15 -09'00' 8650, 9990, 10370, 10835 Unknown, 9100, 10835 (x3) Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.28 16:03:13 - 09'00' Sean McLaughlin (4311) By Grace Christianson at 7:57 am, Jan 29, 2025 DSR-1/31/25JJL 2/10/25 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for BHA length < 500'. *Window milling approved on service coil 225-005 50-029-21813-02-00 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Variance to 20 AAC 25.036 (c)(2)(A)(iv) approved for work performed before 3/31/25 with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. A.Dewhurst 04FEB25 *&: 2/10/2025 2/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.10 15:26:28 -09'00' RBDMS JSB 021325 12,169' 8,953' 8,953'8,953' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 28, 2025 Re:H-29B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well H-29A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for H-29B Producer: See H-29A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock, pull PX plug, and MIT. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window will be milled. The well will kick off drilling in the Shublik and lands in Ivishak Zone 2. The lateral will continue in Zone 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perforations. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference H-29A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and pull PX plug 2. E-Line : Set 4-1/2" Packer Whipstock at 8,953’ MD at 275 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil : Mill XN nipple to 3.80" and Window (if window not possible, mill with rig). See attached procedure. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in March 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,323 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~182' (30 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~3,034' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 42 bbls, 14.8 ppg Class G, yield 1.33 ft3/sk, TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : RPM log, perforate (~40’) 3. Slickline : Run GLVs, set LTP (if necessary), set Nipple Reducer & TTP 4. Eline : Set patch over tubing leak @ 6090' MD 5. Slickline : MITT, pull TTP Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3”/3-1/8” (big hole) & 2-3/8” (slim hole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (8953' MD -8,608' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,387 psi 4,387 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 537 psi 0 psi 0.09 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,849 psi 3,849 psi 8.6 B+C Mud + ECD Combined 4,387 psi 3,849 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 537 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,203 psi at 8,800 TVD. (7.0 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,323 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 4.25" hole for the entirety of the production hole section. Liner Program: x 3-1/2", 9.3#, 13Cr/Solid: 8,550' MD – 8,925' MD (375' liner) x 3-1/4", 6.6#, 13Cr/Solid: 8,925' MD – 9,500' MD (575' liner) x 2-7/8", 6.5#, 13Cr/Solid: 9,500' MD – 12,169' MD (2,669' liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 2,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Solid 2-7/8” Liner Running Ram Change: Change out 3”/3-1/8” pipe/slip rams (for drilling) to 2-3/8” x 3- 1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-installed TIW valve). When closing on a 2 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 101°. Inclination at kick off point is 35°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 27,102 ft x Distance to nearest well within pool – 789 ft Logging: x MWD directional, Gamma Ray and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x 40' perforated post rig – See attached extended perforating procedure. x 2.0" Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe Pool. x Formations: Top of Prudhoe Pool MD in the parent 8,865’ MD. Anti-Collision Failures: x Anti-Collision Summary – x H-16 fails at 9,734’ MD (H-16 depth) – P&A’d above for H-16B Hazards: x H-Pad is not an H2S pad. The last H2S reading on H-29A: 20 ppm in 2024. x Max H2S recorded on H-Pad: 64 ppm. x 1 fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Pre-Rig – Service Coil – Window Milling The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire window milling operation. Notes for window milling: x Window milling with service CTU operations will fully comply with 20 AAC 25.286(d)(3), including the use of pressure control equipment, all BHAs fully lubricated and at no point will any BHA be open-hole deployed. Window Milling Procedure: 1. Kill well with 1% KCL if necessary. Well may already be killed from previous operations. 2. MU and RIH with window milling assembly – Window mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s window milling BHAs. 3. RIH & TAG whipstock pinch point, calculate distance till string reamer is out of the window, paint coil flag and note in WSR. 4. Mill window per vendor procedure. – Make note of any WHP changes while milling window in the WSR. 5. Make multiple reciprocating passes through the kickoff point to dress liner exit and eliminate all burs. Perform gel sweeps as necessary to keep window clean. Maximum approved distance to reciprocate beyond the window is 15 ft to ensure confidence the window is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire window with coil flag and note bottom of window and total milled depth in WSR. 7. FP well to 2,500’ TVD with 60/40 MeOH while POOH. 8. Once on surface inspect BHA, measure OD of mill and string reamer & document in WSR. 9. RDMO 10. Communicate to Operations to tag wing valve “Do Not POP”. Pre-Rig – Service Coil – Window Milling – BOP Diagram Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram 050010001500200025003000South(-)/North(+) (1000 usft/in)-4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 West(-)/East(+) (1000 usft/in)400044004800520056006000640068007200760080008400880092009210H-2984008800H-29A88008987H-29B wp0686008700880089009000True Vertical Depth (200 usft/in)1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 Vertical Section at 300.00° (400 usft/in)H-29AH-29B wp06Top of Window - 8953'MDEnd 30dls - 9135'MDTD - 12169'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 8953.00 35.03 61.97 8608.81 1059.12 -819.34 0.00 0.00 1239.132 8973.00 35.23 58.86 8625.17 1064.80 -809.34 9.00 -85.00 1233.313 9043.00 41.88 26.53 8680.44 1096.50 -781.30 30.00 -85.00 1224.884 9135.00 53.45 352.19 8743.31 1161.85 -772.44 30.00 -78.00 1249.885 9308.00 56.16 326.93 8844.10 1292.33 -821.63 12.00 -90.00 1357.726 9670.30 90.00 297.82 8950.11 1513.67 -1076.29 12.00 -45.00 1688.937 9851.00 92.95 276.32 8945.41 1566.40 -1247.94 12.00 -82.00 1863.958 10031.00 98.22 297.38 8927.71 1617.87 -1418.40 12.00 75.00 2037.309 10311.00 99.60 263.38 8883.05 1667.10 -1686.28 12.00 -85.00 2293.9110 10491.00 100.95 285.30 8850.56 1680.35 -1861.74 12.00 84.50 2452.4911 10701.00 99.89 259.69 8811.96 1689.18 -2066.25 12.00 -90.00 2634.0212 10881.00 99.56 281.61 8781.18 1691.19 -2242.51 12.00 89.00 2787.6713 11071.00 99.19 258.50 8749.81 1691.33 -2428.64 12.00 -89.00 2948.9314 11170.42 90.00 266.13 8741.84 1678.15 -2526.67 12.00 140.00 3027.2315 11271.00 84.93 277.10 8746.30 1680.95 -2626.93 12.00 115.00 3115.4616 11451.00 76.28 257.01 8775.95 1672.28 -2803.18 12.00 -115.00 3263.7617 11691.00 76.09 286.69 8834.50 1679.69 -3033.21 12.00 94.00 3466.6818 11871.00 71.58 264.68 8885.18 1697.07 -3203.93 12.00 -105.00 3623.2219 12051.00 70.71 287.50 8944.06 1714.91 -3371.96 12.00 96.00 3777.6620 12169.00 66.47 272.98 8987.33 1734.57 -3479.64 12.00 -110.00 3880.74Project: Prudhoe BaySite: HWell: H-29Wellbore: PLAN: H-29BPlan: H-29B wp06WELLBORE DETAILSParent Wellbore:H-29ATop of Window: 8953.00H-29B wp06Depth From Depth To Survey/Plan Tool98.38 8498.37 1 : Sperry-Sun BOSS gyro multi (H-29) 3_Gyro-SR-GMS18520.00 8953.00 3 : MWD - Standard (H-29A) 3_MWD8953.00 12169.00 H-29B wp06 (PLAN: H-29B) 3_MWDWELL DETAILSNorthing: 5959783.00Easting: 643318.00Lattitude: 70° 17' 51.4319 NLongitude: 148° 50' 21.6980 WH-29B wp06SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well H-29, True NorthVertical (TVD) Reference: KB @ 72.37usft (H-29A OKB)Measured Depth Reference: KB @ 72.37usft (H-29A OKB)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !""# $ " % & # ' " # ( )*+ ( , , - .# /$ !!" #$% &'% () *#+ + 0 ,-. +- /0 1 2/ /+ ( #$% &'% () *#+ % $ ( 3 2 / ' 1 +' & / 2 '+'4 5 %)/6 + 05 %) 0* * 4+ 4 72/02 2/ 8-9 " 4 :3( 4 :: ( 3 ' " " 0 4 % $ 0 5 0 1 # .0 2555' ( ( ( ;5&-< =- > >% >% & > .95 '..&-% -&-- %-;5%?'-&->>5 59<;>5?5 &<- 3 , , " 0 " 5 0 % $ 0 ( 657, 6%7 4 ( ( (1 ". 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" # $ % + ' ,- 7 " 0 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 225-005 PRUDHOE BAY PBU H-29B PRUDHOE OIL WELL PERMIT CHECKLIST Company Hilcorp North Slope, LLC Well Name:PRUDHOE BAY UNIT H-29B Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Program DEVField & Pool Well bore seg Annular DisposalPTD#:2250050 PRUDHOE BAY, PRUDHOE OIL - 640150 NA1 Permit fee attached Yes ADL0282842 Lease number appropriate Yes3 Unique well name and number Yes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined pool Yes5 Well located proper distance from drilling unit boundary NA6 Well located proper distance from other wells Yes7 Sufficient acreage available in drilling unit Yes8 If deviated, is wellbore plat included Yes9 Operator only affected party Yes10 Operator has appropriate bond in force Yes11 Permit can be issued without conservation order Yes12 Permit can be issued without administrative approval Yes13 Can permit be approved before 15-day wait NA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For s NA15 All wells within 1/4 mile area of review identified (For service well only) NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only) NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) Yes18 Conductor string provided Yes19 Surface casing protects all known USDWs NA20 CMT vol adequate to circulate on conductor & surf csg NA21 CMT vol adequate to tie-in long string to surf csg Yes22 CMT will cover all known productive horizons Yes23 Casing designs adequate for C, T, B & permafrost Yes24 Adequate tankage or reserve pit Yes Variance approved in PTD25 If a re-drill, has a 10-403 for abandonment been approved Yes26 Adequate wellbore separation proposed NA27 If diverter required, does it meet regulations Yes28 Drilling fluid program schematic & equip list adequate Yes Variance approved in PTD29 BOPEs, do they meet regulation Yes30 BOPE press rating appropriate; test to (put psig in comments) Yes31 Choke manifold complies w/API RP-53 (May 84) Yes32 Work will occur without operation shutdown No33 Is presence of H2S gas probable NA34 Mechanical condition of wells within AOR verified (For service well only) No H-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measures Yes Anticipating 7.0 ppg EMW pressure gradient in reservoir. One fault crossing expected.36 Data presented on potential overpressure zones NA37 Seismic analysis of shallow gas zones NA38 Seabed condition survey (if off-shore) NA39 Contact name/phone for weekly progress reports [exploratory only] Appr ADD Date 2/4/2025 Appr JJL Date 2/10/2025 Appr ADD Date 2/4/2025 Administration Engineering Geology Geologic Commissioner:Date:Engineering Commissioner:Date Public Commissioner Date ($8JLC 2/10/2025
