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Home My WebLink About224-043Nolan 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241205 Well API #PTD #Log Date Log Company Log Type AOGCC ESet AN 15(GRANITE PT ST 18742 15) 50733200700000 167082 11/18/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 10/24/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/21/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/30/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 11/8/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 11/12/2024 AK E-LINE Plug/Perf END 2-72 50029237810000 224016 10/16/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 10/18/2024 HALLIBURTON COILFLAG MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL MPU F-109 50029235960000 218014 10/28/2024 READ CaliperSurvey MPU J-02 50029220710000 190096 11/16/2024 READ CaliperSurvey MPU J-47 50029238010000 224120 11/9/2024 READ LeakPointSurvey MPU D-01 50029206640000 181144 10/23/2024 AK E-LINE TubingPunch MPU F-02 50029226730000 196070 11/18/2024 READ CaliperSurvey MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24 MRU M-25 50733203910000 187086 11/15/2024 AK E-LINE Plug NCIU A-21 50883201990000 224086 11/9/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/19/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Plug/Perf PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT PBU H-36A 50029226050100 200025 10/26/2024 HALLIBURTON RBT PCU 02A 50283200220100 224110 11/24/2024 AK E-LINE Perf Please include current contact information if different from above. T39808 T39809 T39810 T39810 T39811 T39812 T39813 T39813 T39814 T39815 T39816 T39817 T39818 T39819 T39820 T39820 T39821 T39822 T39823 T39823 T39823 T39823 T39824 T39825 T39826 T39827 PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.05 14:52:46 -09'00' 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: 10/10/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 06-07A PTD: 224-043 API: 50-029-20299-01-00 FINAL LWD FORMATION EVALUATION LOGS (08/28/2024 to 09/11/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 224-043 T39650 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.10 13:37:52 -08'00' 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 06-07A Hilcorp Alaska, LLC Permit to Drill Number: 224-043 Surface Location: 20' FSL, 1040' FEL, Sec 02, T10N, R14E, UM, AK Bottomhole Location: 1999' FSL, 146' FWL, Sec 06, T10N, R15E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for 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. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this day of May 2024. 15th Drilling Manager 05/02/24 Monty M Myers By Grace Christianson at 12:29 pm, May 02, 2024 MGR13MAY24 DSR-5/2/24 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug place- ment with fully cemented liner and all drilling within the PB oil pool. * Post rig perforating gun length limited to 500' or less. 50-029-20299-01-00 SFD 5/14/2024 224-043 JLC 5/14/2024 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: May 1, 2024 Re:06-07A Permit to Drill Approval is requested for drilling a CT sidetrack lateral from well 06-07 with the Nabors CDR3. Proposed plan for 06-07A Producer: See 06-07 Sundry request for complete pre-rig details - Prior to drilling activities, Slickline will drift for a whipstock and run a caliper, E-line will perform a tubing punch just below the packer at ~10341' MD. Service coil will then lay cement from ~11,003' MD in the 9-5/8" casing and brought up inside the 4-1/2" tubing tail to ~10,341' MD in preparation for a 2.74" pilot hole and whipstock. A coil tubing sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will mill a 2.74" pilot hole to ~10,800', run a caliper to confirm contact with the 9-5/8" casing, then run and set the 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 2-3/8 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in May 15, 2024) Reference 06-07 Sundry submitted in concert with this request for full details. 1. Slickline : Set DGLVs, Drift, Caliper 2. E-Line : TBG Punch 3. Coil : Lay in CMT for pilot hole 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in September 3, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2. Mill 2.74" pilot hole to ~10,800' MD and Caliper. 3. Set 3-1/4" whipstock at ~10,722' MD and mill 2.74 Window. 4. Drill production lateral: 3.25" OH, ~2104' (12 deg DLS planned). 5. Run 2-3/8 13Cr liner to TD, release off liner and POOH. 6. RIH and sting into ORCA valve. Pump primary cement job: 18 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~30) and RPM. This completionp , p will target isolating and abandoning the parent Ivishak perfs. Sundry 324-266 PTD 224-043 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 (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 (10722' MD -8,609' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,387 psi 4,387 psi 9.8 B - ECD 965 psi 0 psi 0.09 C 3,850 psi 3,850 psi 8.6 B+C Mud + ECD Combined 4,815 psi 3,850 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: The estimated reservoir pressure is expected to be 3,267 psi at 8,800 TVD. (7.1 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,387 psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4 screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 3.25" (2.74" pass) hole for the entirety of the production hole section. Liner Program: 2-3/8", 4.6#, 13Cr/Solid: 10,045' MD 12,826' MD (2,781' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. A X-over shall be made up to a 2" safety joint including a TIW valve for all tubulars ran in hole. 2" 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" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: Directional plan attached. Maximum planned hole angle is 108°. Inclination at kick off point is 36°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line ~22,000' Distance to nearest well within pool 570 ft Logging: MWD directional and Gamma Ray will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: ~30' perforated post rig (see attached post rig perf procedure). 1.56" Perf Guns at 6 spf 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. The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. Anti-Collision Failures: All wells pass Hilcorp's anti-collision risk rules Hazards: 06 is an H2S pad. H2S reading on 06-07: 27 ppm on 09/22/2019. Max H2S recorded on DS/Pad: 100 ppm.. 0 fault crossings expected. Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka 06 is an H2S pad. H2S g Max H2S recorded on DS/Pad: 100 ppm.. p and resistivity (per R. Ciolkosz email dated 5/14/2024). SFD Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. 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 Kuparuk 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 doesnt 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. Prudhoe Oil Pool. SFD Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram $) $) $) $)$) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $)$) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $ $)$)$)$)$)$)$)$)$) $)$) $)06-07A_BHL 06-07A_TPH 06-07A_SHL Oil Rim PAGas Cap PA Lisburne PA ADL028311 ADL028308 ADL028329 ADL028326 DS6 SIP PAD 3 U010N014E U011N014E Sec. 1 Sec. 12 Sec. 2 Sec. 11 Sec. 36 Sec. 35 Sec. 6 (609) Sec. 7 (612) Sec. 31 (607) PRUDHOE BAY UNIT 13-18 06-23 06-22 06-20 06-19 06-18 06-15 06-13 06-11 06-1006-09 06-08 06-07 06-05 06-04 06-03 06-01 02-24 02-21 02-20 02-19 02-11 02-07 02-03 01-24 01-23 01-20 OWDW-C 06-24B 06-23C 06-23B 06-23A 06-22B 06-22A 06-20A 06-19A 06-18A 06-13A 06-10A 06-08B 06-08A 06-04B 06-04A 06-03B 06-03A 06-01A 02-35B 02-24A 02-21B 02-21A 02-13C 02-12D 02-12C 02-12B 02-12A 02-11A 02-07A 02-03A 01-24A 01-08A OWDW-SW PWDW1-2A PR121014 PR021014 Map Date: 2/16/2024 Prudhoe Bay Unit 06-07A Well wp04 0 690 1,380 Feet Legend $)06-07A_BHL 06-07A_SHL 06-07A_TPH $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint PA Boundary CO_341J AIO_4G South(-)/North(+) (1000 usft/in)4000 4500 5000 5500 6000 6500 7000 7500 8000 True Vertical Depth (400 usft/in)3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1 Davies, Stephen F (OGC) From:Ryan Ciolkosz <ryan.ciolkosz@hilcorp.com>Sent:Tuesday, May 14, 2024 10:30 AMTo:Davies, Stephen F (OGC)Cc:Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC); Joseph LastufkaSubject:RE: [EXTERNAL] PBU -06-07A (PTD 224-043) - Questions Steve, My mistake, we WILL if fact be running resis vity logs while drilling to help with reservoir evalua on. Thanks, Ryan Ciolkosz | Drilling EngineerC: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, May 13, 2024 4:43 PM To: Ryan Ciolkosz <ryan.ciolkosz@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL] PBU 06 07A (PTD 224 043) Questions Ryan, Im reviewing Hilcorps applica on to drill PBU 06 07A. In the logging program, I no ce that only MWD direc onal, PWD, and gamma ray tools are speci ed. Doesnt Hilcorp plan to run resis vity tools across the reservoir interval? If not, how can Hilcorp iden fy and evaluate the reservoir? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE:This e mail message, including any a achments, contains informa on from the Alaska Oil and Gas Conserva on Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain con den al and/or privileged informa on. The unauthorized review, use or disclosure of such informa on may violate state or federal law. If you are an unintended recipient of this e mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907 793 1224 or steve.davies@alaska.gov You don't often get email from ryan.ciolkosz@hilcorp.com. Learn why this is important 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. 2 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. Prudhoe Bay, Prudhoe Oil 224-043 Prudhoe Bay PBU 06-07A WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 06-07AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240430PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes Surf Loc & Top Prod Int lie in ADL0028311; TD lies in ADL0028329.2 Lease number appropriateYes3 Unique well name and numberYes4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalNA13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 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)Yes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.18 Conductor string providedYes All drilling on this sidetrack will below existing surface casing shoe.19 Surface casing protects all known USDWsYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.20 CMT vol adequate to circulate on conductor & surf csgYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.21 CMT vol adequate to tie-in long string to surf csgYes This well is a in zone CTD sidetrack from an existing well. Full integrity above sidetrack.22 CMT will cover all known productive horizonsYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.23 Casing designs adequate for C, T, B & permafrostYes CDR3 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 324-26625 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan identifies no close approaches26 Adequate wellbore separation proposedNA All drilling below the surface casing shoe. No diverter required.27 If diverter required, does it meet regulationsYes MPD but reservoir pressure below water gradient.28 Drilling fluid program schematic & equip list adequateYes CT Packoff, flow cross, annular, blind shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29 BOPEs, do they meet regulationYes 7-1/16" 5000 psi stack pressure tested to 3500 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes Flanged choke and kill lines between dual combi's w remote choke31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes Monitoring will be required33 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No H2S measures are required. DS 06 wells are H2S-bearing.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.1 ppg. Well will be drilled with MPD and 8.4 ppg mud. Lost circulation36 Data presented on potential overpressure zonesNA risk judged to be low.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/13/2024ApprMGRDate5/14/2024ApprSFDDate5/13/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 5/14/2024