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225-054
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: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' T R A N S M I T T A LL FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7 th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska RE: 3S-705 225-047 DATE:9/26/2025 Transmitted: 3S-705 Via SFTP Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM CC: 3S-705 - e-transmittal well folder 225-047 T40927 Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska | Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.26 12:36:25 -08'00' 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: 09/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU F-06B PTD: 225-054 API: 50-029-20097-02-00 FINAL LWD FORMATION EVALUATION LOGS (07/20/2025 to 07/28/2025) 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. 225-054 T40850 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.04 13:15:21 -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: 08/26/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250826 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 24 50133206390000 214112 7/15/2025 AK E-LINE PPROF T40803 BR 11-86 50733207370000 225057 7/30/2025 AK E-LINE Hoist T40804 BR 11-86 50733207370000 225057 8/4/2025 AK E-LINE Perf T40804 BR 11-86 50733207370000 225057 8/9/2025 AK E-LINE Perf T40804 BRU 212-35T 50283200970000 198161 8/4/2025 AK E-LINE Perf T40805 BRU 212-35T 50283200970000 198161 6/28/2025 AK E-LINE Perf T40805 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/5/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 7/27/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE Punch T40806 KTU 43-6XRD2 50133203280200 205117 7/26/2025 AK E-LINE Perf T40807 MPL-13A 50029223350100 223017 8/10/2025 READ CaliperSurvey T40808 NCIU A-21 50883201990000 224086 1/14/2025 AK E-LINE Plug/Perf T40809 ODSN-16 50703206200000 210053 8/10/2025 READ CaliperSurvey T40810 PBU 01-30A 50029216060100 225050 8/7/2025 HALLIBURTON RBT-COILFLAG T40811 PBU 06-11A 50029204280100 225042 7/13/2025 HALLIBURTON RBT-COILFLAG T40812 PBU 11-37A 50029227160100 219062 7/27/2025 HALLIBURTON RBT T40813 PBU 14-43A 50029222960100 225041 7/31/2025 HALLIBURTON RBT-COILFLAG T40814 PBU F-06B 50029200970200 225054 8/5/2025 HALLIBURTON RBT-COILFLAG T40815 PBU L1-10A 50029213400100 225032 8/1/2025 HALLIBURTON RBT-COILFLAG T40816 PCU 02A 50283200220100 224110 7/27/2025 AK E-LINE Perf T40817 SRU 241-33 50133206630000 217047 7/28/2025 AK E-LINE Perf T40818 WhiskeyGulch 1 50231200790000 221046 6/18/2025 AK E-LINE Packer T40819 Please include current contact information if different from above. T40815PBU F-06B 50029200970200 225054 8/5/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 08:12:23 -08'00' 2025-0730_Safety_Joint_Drill_Nabors_CDR2AC_PBU_F-06B_jh Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 7/30/2025 P. I. Supervisor FROM: Josh Hunt SUBJECT: Safety Joint Drill Petroleum Inspector Nabors CDR2AC PBU F-06B; PTD 2250540 Hilcorp North Slope LLC 7/30/2025: I traveled to Nabors CDR2AC over well PBU F-06B to witness a safety joint well control drill prior to picking up perforation guns. Once they were ready, the rig crew and company man John Pearl gathered in the doghouse and had a good safety meeting discussing everyone’s roles, responsibilities, and the importance of this drill. Halliburton service hands were also included in this meeting and drill since they will be on the rig floor helping to run the perforation guns and have a crossover that will be stabbed and made up on top of the guns before the safety joint is made up. This crossover will be made up by Halliburton while the rig hands pick up the safety joint. Once the meeting was done, we headed out to the rig floor for the simulation drill. Halliburton was ready with their crossover while the safety joint was picked up. The correct slips and elevators were on the rig floor and were double checked for the different size pipe. The 23/8-inch safety joint was made up with a TIW valve on top and was pressure tested to 3500 psi. The drill went well. Afterwards I went to the pipe shed with John Pearl to confirm the Halliburton crossover was the correct one and screwed onto the perforation guns as well as the safety joint. The crossover was placed back on the rig floor where it is easily accessible if/when needed. Mr. Pearl informed me that they will run a live drill once they have guns in the hole. I think it’s a great idea to do these pre-job drills prior to having a live well and tools in the hole. Attachments: none 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 Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Unit Field, Prudhoe Oil, PBU F-06B Hilcorp Alaska, LLC Permit to Drill Number: 225-054 Surface Location: 2772' FNL, 2879' FEL, Sec. 02, T11N, R13E, UM, AK Bottomhole Location: 1010' FSL, 483' FEL, Sec. 34, T12N, 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 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, Jessie L. Chmielowski Commissioner DATED this 9th day of June 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.09 13:56:34 -08'00' 3-1/2"x3-1/4" By Grace Christianson at 2:45 pm, May 15, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.05.15 14:22:26 - 08'00' Sean McLaughlin (4311) *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 with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams DSR-6/3/25 225-054 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for max gun length of 500'. *Window milling approved on service coil 50-029-20097-02-00 A.Dewhurst 06JUN25JJL 6/9/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.09 13:56:46 -08'00'06/09/25 06/09/25 RBDMS JSB 061225 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 15, 2025 Re:F-06B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well F-06A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for F-06B Producer: See F-06A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock 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 mill the window pre-rig, 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 pre-rig, the rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 4. The lateral will continue in Zone 4 and up through the Shublik and into the Sag to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 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 perfs. 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 F-06A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 10,390’ MD at 325 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil : Mill 3.80" XN nipple (at 10,130' MD) and 3.80" 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 July 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,364 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, ~388' (32 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,595' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2"x3-1/4” x 2-7/8” L-80 solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 34.7 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. 7. Perforate Liner with rig (~1500') - will perforate with service coil under this PTD if needed 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. Slickline : Liner Lap Test, set LTP* (if necessary). Set live GLVs. 3. Testing : Portable test separator flowback. 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 (10,390' MD -8,791' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,480 psi 4,480 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 623 psi 0 psi 0.09 C DƵĚ,LJĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,931 psi 3,931 psi 8.6 B+C Mud + ECD Combined 4,555 psi 3,931 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 549 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,244 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,364 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#, L-80/Solid: 10,120' MD – 10,140' MD (20' liner) x 3-1/4", 6.6#, L-80/Solid: 10,140' MD – 10,900' MD (760' liner) x 2-7/8", 6.5#, L-80/Solid: 10,900' MD – 12,985' MD (2,085' 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 110°. Inclination at kick off point is 52°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 9,120 ft x Distance to nearest well within pool – 510 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 1500' perforated with rig or service coil – See attached extended perforating procedure if done post rig. x 2" 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 is 10,312’ MD in the parent Anti-Collision Failures: x F-19B Fails AC at 10,390’ MD (F-06B depth) and 12,494’ MD (F-19B depth) o Center to center distance is 400’ o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Pad operator will be aware of the failed anticollision scan and is prepared to shut in well F-19B in the event of a collision. o At least 200 bbls of KWF (offset tubing volume) is on location at all times while drilling by well. o The potential of intersection and proper response will be been discussed with the crew. Hazards: x F Pad is an H2S pad. The last H2S reading on F-06A: 16 ppm in 2024. x Max H2S recorded on F Pad: 160 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 % Prudhoe Bay Unit ADL028281 ADL028280 ADL028278 ADL028277 Sec. 35 Sec. 2 Sec. 34 Sec. 3 U011N013E U012N013E F PAD T PAD F-06B_SHL F-06B_TPH F-06B_BHL F-06B Legend F-06B_BHL F-06B_SHL %F-06B_TPH Other Surface Holes (SHL) Other Bottom Holes (BHL) Other Well Paths Pad Footprint Oil and Gas Unit Boundary AIO 3C CO 341J Map Date: 5/2/2025 0 320 640 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxNAD 1927 StatePlane Alaska 4 FIPS 5004 Prudhoe Bay Unit F-06B Well wp03 u 1:9,500 280032003600400044004800South(-)/North(+) (800 usft/in)-3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 West(-)/East(+) (800 usft/in)F-13C68007200F-4168007200F-41PB15200560060006400F-37APB18000840088009146F-06A76008000840088009199F-06640068007200760080008400F-3764006800720076008000840088009 1 4 9F-42A56006000640068007200F-36840088009172F-328750F-19B640068007200760080008400F-2164006800720076008000F-21PB18800F-42B wp0388008697F-06B wp03Top of Window - 10390'MDEnd 32dls - 10778'MDTD - 12985'MD865087008750880088508900True Vertical Depth (100 usft/in)-400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 Vertical Section at 260.00° (400 usft/in)F-06AF-06F-06B wp03Top of Window - 10390'MDEnd 32dls - 10778'MDTD - 12985'MDF-06B wp03F-06B wp03Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 10390.00 52.67 34.06 8791.15 3923.06 -716.56 0.00 0.00 24.452 10410.00 54.15 32.79 8803.07 3936.47 -707.72 9.00 -35.00 13.413 10480.00 73.23 19.59 8834.07 3992.60 -680.78 32.00 -35.00 -22.874 10777.77 92.00 284.67 8883.87 4219.46 -807.58 32.00 -89.50 62.615 11165.63 110.00 240.70 8806.47 4177.02 -1174.39 12.00 -64.00 431.226 11245.63 110.00 230.49 8779.11 4134.60 -1236.33 12.00 -90.00 499.587 11404.47 92.00 236.90 8748.90 4042.93 -1361.56 12.00 160.00 638.838 11570.00 91.37 256.77 8743.98 3978.17 -1512.92 12.00 91.50 799.139 11730.00 91.95 237.57 8739.29 3916.41 -1659.63 12.00 -88.00 954.3410 12050.00 91.95 276.00 8728.39 3844.65 -1965.17 12.00 90.00 1267.7011 12250.00 91.95 251.98 8721.57 3823.87 -2162.50 12.00 -90.00 1465.6412 12490.00 91.95 280.80 8713.39 3808.93 -2399.37 12.00 90.00 1701.5013 12730.00 91.95 251.98 8705.22 3793.98 -2636.24 12.00 -90.00 1937.3714 12985.00 91.95 282.60 8696.53 3782.08 -2887.78 12.00 90.00 2187.16Depth From Depth To Survey/Plan Tool161.00 5961.00 F-06 Srvy 1 CB-GYRO-MS (F-06PB1) 3_CB-Film-GMS26061.00 8761.00 F-06 Srvy 1 CB-GYRO-MS (F-06) 3_CB-Film-GMS28839.00 10390.00 F-06A Srvy 1 MWD+IFR+MS-WOCA (F-06A)3_MWD (BP MWD+IFR+MS-WOCA)10390.00 12985.00 F-06B wp03 (F-06B) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: FWell: F-06Wellbore: F-06BPlan: F-06B wp03REFERENCE INFORMATIONCoordinate(N/E) Reference: Well F-06, True NorthVertical (TVD) Reference: KB @ 66.61usft (F-06A)Measured Depth Reference: KB @ 66.61usft (F-06A)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: F-06ATop of Window: 10390.00Northing: 5974028.00Easting: 651961.00Lattitude: 70° 20' 9.8421 NLongitude: 148° 46' 1.3771 WNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILS !""# $% & # ' " # ( )*+ ( , , - $.# $ % ! 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"# $ % &' ( + / ) * +- +, - .+ + ( "# $ % &' ( 0 % ( / . -.%%? 3 *$ 3 < 13? %$ < <2$% 9 <?$11 % 223$ $ $ :B 9$11 & %%2?3$92 & ,'?3 $9<.C, 9% 1$3<5 %2 3$99+( -.%3 ? 32%$%< < 133 ? $ 91 19$< * ?%3$9* 2 %?1$3 $ $ :B%$<1 & %223?$ 9 & ,'?32 $ 2.C, *?%<$1?5 2%?1$*1+( -.%2 ? 391$11 < 13? 23$ < <<1$% 9 2 $?? % *2 $ ? $ $ :B*<$11 & %%*31$*3 & ,'?3< $9 .C, 9 < $315 %*9 $ 1+( -.2 ? 3 $2% < 133 393$ 91 13$2 * 33 $<< 2 3??$ $ $ :B<$19 & %2??9$9< & ,'? 11$1<.C, *33 $ %5 23??$%9+( * + % 7$ (9 $ + % 7$ (9 # / + ' 7C9 + ' 7C90' # / 23A?=? 1 $<%%2 1?<$ 2 3A? 9 %A9 $ + % 7$ (9 * + % 7$ (9 546, 7$ (9 506 7$ (9 " # # '' % *1 $ ? 31%$%< * 12*$ 3% $< .&/) % *1 > , % 333$33 ? ??*$?3 9 2%1$9 ? 3$<? +*2 % 33?> , %2 1?<$ ? 1 $<* * 3?2$ ? 2 ??3$3? ., %21?<> , ! !"# $ !"# !"# %& " ' ( ( ! " #$)*+' (% &' , ( ! " #$+' (' ( ( - ' ( " .( ) * / (' 0( 1 + , 0.( " ' 02 + 2(-.)/) (- " . ' + 3 ( 01 1'' )*+' ( 4 ( + 3( ' . ( ( .'( ! ( 2 ' 1. -& 34 54 2(-6 7, &"& 8 ", ). 2* +9 " !1: !+:;9 " ) < & " !=:9 + " 01 2( 30 3/./ ( + &&& - > 3 ( ! 5' 6 /) 3 + )-/5026 ) 5' 6 + 9?:?++9 1/ 5) +++5 6 , '!! 9:! * ! 5@4) #% !$ 1/ 5) +++5 6 , '! ;A! * ! 5@4) #$ 1/). # % ).B2B) 4 $!)C?2 =6 55) & ;;1: !1: * ! ).B2B) 4 # 1/).!)C?2 =6 55) & !1: !+:;9 01 # $ 1'' 0"02"+ 3 ' + 5' 6 1'' + 5' 6 % 5' 6 % . 5' 6 ! 0 3 - + + + +4 " , + + +4 " , + +% ! +% !4 " , 1 1 1 4 " , 1 1 14 " , = = =4 " , = = =4 " , = =% ! =% !4 " , = = = 4 " , 9 9 9 4 " , 9 9 94 " , 9 9 9 4 " , !!=!A A; !+;= + ++A A; !A; :9 = 9 - !!== !+A ++: !1 !A; ; = =;; !!=: !+9: + +=! :! !;9 :: = 1+ 35 D ., !1:+ A; !1:+ A; ! 9! ! 35 D ., - !=!9 !=!= :: =: A 1:+ % ! % !4 " , A A A 4 " , ; ; ;4 " , ; ; ;4 " , ; ; ; 4 " , : : :4 " , : : :4 " , : : : 4 " , : : : 4 " , ! ! !4 " , ! ! !4 " , ! ! ! 4 " , ) & *, " - " ' ( ( ! " #$)*+' (% &' , ( ! " #$+' (' ( ( - ' ( " .( ) * / (' 0( 1 + , 0.( " ' 02 + 2(-.)/) (- " . ' + 3 ( 01 1'' )*+' ( 1'' 0"02"+ 3 ' + 5' 6 1'' + 5' 6 % 5' 6 % . 5' 6 ! 0 3 - + ! ! ! 4 " , ! ! % ! ! % !4 " , !! !! !!4 " , !! !! !!4 " , !! !! !! 4 " , !+ !+ !+4 " , !1 !1 !1 4 " , !1 !1 !14 " , - !1 !1 !1 !1: :; !1: ; !!+! ; 9 9+= !1 !1 !1 !=!9 :; !1;1 9: !!1+ ; 9 9!= !1 !1 % ! !1 % !4 " , !1 !1 !1 !+;: !!A+= ;+ ;! :! =;1 1= + 9!A - !1 !1 !1 !+:!9 !!A= !: A: A+ =; 9+ + 9+ !1 !1 !1 !+:;! ! !!A +A A: A: =; +! + 9: != != != !9=9 +9 :=1! != !==+ 1 ;; !! + 9!+ - != != != !99 :==9 ;+ !==1 1; ; 9 + 9+ != != != !!9 :=A; =; !=99 !! ;A! + =:= 35 D ., - !: !: !: !1: !+=:1 : = !+ !1 =! :; *& E & !: !: !: !9:; !9 !+9A= A +: :+ 91 ;= ! +++ + + +4 " , +! +! +! !!9: !;A 99 :91 =; ;= A1 ; :1+ - +! +! +! !!= !;: A: :9 9A ;== !! ; 9 +! +! +! !+= !+=1 ; !11= ;= :A1 A1 1 : +! +!% ! +!% ! !:A 1; !!1! := !:+ == :1= : ;:: - +! +!% ! +!% ! !!!!9 !!++ A9 !!+1 ;1 :; =! 9 +!A +! +!% ! +!% ! !!9 :::A + !==; ;: !: :; = !!A +! % 6 +! +! 0! !!9: !;A 99 :91 =; ;= A1 ; :1+ - +! % 6 +! +! 0! !!= !;: A: :9 9A ;== !! ; 9 +! % 6 +! +! 0! !+= !+=1 ; !11= ;= :A1 A1 1 : ++ ++ ++ !1: !1= !+!! ! ::1 9 9 99 - ++ ++ ++ !=!9 !1= !+9 ;+ ::! : 9 1! ++ ++ ++ !==9 ;1 !1= !+1 += ::= + 9 A9 ++ ++ ++ !99! !1 !;!+ 9; :A !1 9 !: + 9; - ++ ++ ++ !9: !: 1 :A= : 9;9 ; + 9! +: +: +:4 " , +: +: +:4 " , +: +: +: 4 " , +: +: % ! +: % !4 " , 1! 1! 1!4 " , 1! 1! 1!4 " , 1! 1!% ! 1!% !4 " , *& E & 1+ 1+ 1+ !+!: !1== A1 AA ; !9 A ! !9: *& E & - 1+ 1+ 1+ !+1!9 !1;+ 9: 1 =9 : =+ ! !A 1+ 1+ 1+ !+;: 9; !=+ + 1; 11 +++ 1+ + =A 1= 1= 1=4 " , 1= 1= 1=4 " , 1= 1=% ! 1=% !4 " , 1= 1= 1= 4 " , 1= 1= 1= 4 " , ) & *, " - " ' ( ( ! " #$)*+' (% &' , ( ! " #$+' (' ( ( - ' ( " .( ) * / (' 0( 1 + , 0.( " ' 02 + 2(-.)/) (- " . ' + 3 ( 01 1'' )*+' ( 1'' 0"02"+ 3 ' + 5' 6 1'' + 5' 6 % 5' 6 % . 5' 6 ! 0 3 - + 1 1 14 " , 1 1! 1!4 " , 1 1+ 1+4 " , 1 11 11 4 " , 1A 1A 1A !+!9 :A: !; !!A1 ; :1A ! = :A! - 1A 1A 1A !+:;9 !!!A ;! 9 19 91A 9! 9 +9 1A 1A 1A4 " , 1A 1A! 1A!4 " , 1A 1A% ! 1A% !4 " , 1A 1A% + 1A% +4 " , 1; 1; 1;4 " , 1; 1; 1;4 " , 1; 1; 1; 0+4 " , = = =4 " , = %36 = = 0+4 " , - =! =! =! !+:;9 !!+= : !!=; =+ ;; ;: = !; - =! =! =! !+:;9 !!+= : !!=; =+ ;; :! = !: - =! =!% ! =!% ! !+:;9 !1 :1 !!=: 9+ ;;A == = 1; =+ =+ =+ !!:1 ;; !+:A ; 9+: =: 1: ++ 1 :A1 - =+ =+ =+ !+!9 !99; ;1 9A A 1!; 9 + +A: =+ =+ =+ !++9 !+: ;: !! 1 11+ +9 + !: =+ =+ =+ 01 !!:1 ;; !+:A ; 9+: =: 1:A ;! = +! - =+ =+ =+ 01 !+!9 !99; ;1 9A A 1++ =A + 1!9 =+ =+ =+ 01 !+!9 !;= A1 9= 1A; 1! + 9 =1 =1 =1 4 " , =1 =1! =1!4 " , ) & *, " - " ' ( ( ! " #$)*+' (% &' , ( ! " #$+' (' ( ( - ' ( " .( ) * / (' 0( 1 + , 0.( " ' 02 + 2(-.)/) (- " . ' + 3 ( 01 1'' )*+' ( = ; !+ ! +9 9 A9 ! !+9 !9 ) & .' && % >! >+ !1 !1 !1 > !1 !1 !1 > != != != >! !: !: !: > +! +! +! >! +! +!% ! +!% ! >! +! % 6 +! +! 0! > ++ ++ ++ >! ++ ++ ++ > 1+ 1+ 1+ >! 1A 1A 1A >! =! =! =! > =! =! =! > =! =!% ! =!% ! > =+ =+ =+ >= =+ =+ =+ 01 > - 5 - 3 . & * 6 & 7 % !:+A #-< $ D = 5& *, " 6 ! !F )& !9F G 4"" .' * 4"" . " .' * ! " #$ ) & *, " - " ' ( ( ! " #$)*+' (% &' , ( ! " #$+' (' ( ( - ' ( " .( ) * / (' 0( 1 + , 0.( " ' 02 + 2(-.)/) (- " . ' + 3 ( 01 1'' )*+' ( 1 : +9 9 A9 ! !+9 ) & .' 35 D ., *& E & %& E 34-4 % >! >+ !1 !1 !1 > !1 !1 !1 > != != != >! !: !: !: > +! +! +! >! +! +!% ! +!% ! >! +! % 6 +! +! 0! > ++ ++ ++ >! ++ ++ ++ > 1+ 1+ 1+ >! 1A 1A 1A >! =! =! =! > =! =! =! > =! =!% ! =!% ! > =+ =+ =+ >= =+ =+ =+ 01 > - 5 - 3 . & * 6 & 7 % !:+A #-< $ D = 5& *, " 6 ! !F )& !9F G 4"" .' * 4"" . " .' * ! " #$ ) & *, " - 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"or 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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 225-054 PBU F-06B PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT F-06BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250540Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL028280, ADL028277, and ADL0282782 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 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 approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For 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 providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes Contigent on fully cemented liner25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes Variance granted for no CS Hydril rams29 BOPEs, do they meet regulationYes 5000 psi30 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 shutdownYes The last H2S reading on F-06A: 16 ppm in 2024.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No F-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure gradient is 7.1 ppg EMW. MPD to maintain an ECD of 9.8 ppg EMW.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate6/6/2025ApprJJLDate6/9/2025ApprADDDate6/5/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate JLC 6/9/2025
