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Home My WebLink About223-122Nolan 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: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -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: 06/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU N-07B + PB1 PTD: 223-122 API: 50-029-20137-02-00 (N-07B) 50-029-20137-70-00 (N-07BPB1) FINAL LWD FORMATION EVALUATION LOGS (05/12/2025 to 05/27/2025) 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. T40547 T40548 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.13 11:56:07 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU N-07B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 223-122 50-029-20137-02-00 341J ADL 0028282 ~12940 Surface Intermediate Liner Liner Liner ~9032 2572 7579 9974 1006 3180 ~12880 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" ~9032 34 - 2606 2045 - 9624 30 - 10004 9826 - ~10180 ~9760 - ~12940 2537 34 - 2606 2045 - 8185 30 - 8512 8358 - ~8680 ~8301 - ~9032 None 2670 4760 7020 7500 10530 None 4930 6870 8160 8430 10160 None 4-1/2" 12.6# 13cr80 28 - 9824None Conductor 80 20" 34 - 114 34 - 114 4-1/2" Baker S3 Packer No SSSV Installed 9767, 8307 Date: Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com (907) 564-4763 Prudhoe Bay 12/1/2024 Current Pools: Prudhoe Oil Proposed Pools: Prudhoe Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:01 pm, Oct 04, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.04 15:40:07 - 08'00' Torin Roschinger (4662) 324-580 10-404 , ADL 0028281 SFD Perforate SFD 10/27/2024MGR15OCT24 DSR-10/10/24JLC 10/28/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.29 03:29:29 -08'00'10/29/24 RBDMS JSB 102924 Perf Procedure N-07B PTD: 223-122 Well Name:N-07B Initial Perfs API Number:50-029-20137-02-00 Current Status:New CTD Sidetrack Rig:CTU, SL Estimated Start Date:12/1/2024 Estimated Duration:2.5 days Regulatory Contact:Abbie Barker Permit to Drill Number:223-122 First Call Engineer:Aras Worthington (907) 440-7692 (c)(907) 564-4763 Second Call Engineer:Tyson Shriver (406) 690-6385 (c) Current Bottom Hole Pressure:3,420 psi @ 8,830’ TVD 7.5 PPGE (Estimated) Max. Anticipated Surface Pressure:2537 psi (Based on 0.1 psi/ft. gas gradient) Min ID:2.377” ID – crossover @ ~10,380’ MD Max Angle: TBD Tie-in Log: RPM To be run as part of the post-rig work Brief Well Summary: 2024 CST targeting IvishakZone 2A-1B sands. Objective: RPM log, possible CBL of CTD liner, and initial extended perforating within Zone 2A-1B with service coiled tubing. 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 2.3” nozzle drift BHA and drift well to TD. a. Displace well with 1% KCl while RIH b. Flag pipe off bottom to avoid damaging logging tools on subsequent logging run. 3. MU RPM logging tools. 4. RIH to above tag depth. 5. Log RPM in gas view mode. 6. POOH and download data. Once good data is confirmed MU memory CBL logging tools and RIH. a. Perform CR pipe management as needed so that CBLrun can serve as flag run for perfs b. Send RPM data to RE as soon as available. 7. Log memory CBL from TD to TOL (RE discretion depending on how CT Liner cement job goes). a. Flag pipe for perf run while logging OOH. Consult with RE on potential perf intervals. b. Perform repeat pass from 10,500’ – 9600’ MD. 8. POOH with memory CBL and download data. a. Send results to RE with field pick of TOC. 9. 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. Perf Procedure N-07B PTD: 223-122 10. There will be no perforations to bullhead kill the well. Well will already be loaded w/ 8.4 ppg fluid per previous steps. Re-load well with 8.4 ppg (or heavier) at WSS discretion. a.Wellbore volume to top of proposed perfs = ~170 bbls b. 4-1/2” Tubing – 9760’ x .0152bpf = 148 bbls c. 3-1/2” Liner - 220’ x .0087bpf = 4 bbls d. 3-1/4” Liner – 210’ x .0079 = 2 bbls e. 2-7/8” Liner – ~2560’ x .0058bpf = 15 bbls 11. At surface, prepare for deployment of TCP guns. 12. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. 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. 13.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. 14. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per sundry is 500ft.Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Iperf Schedule *HES 1.75” Geo Razor guns were used to estimate for this job. 1.91” gun swell 15. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 16. 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. 17. Pump pipe displacement while POOH. Stop at surface to reconfirm well dead and hole full. 18. 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. 19. FP well to 2000’ MD. 20. RDMO CTU. Slickline 21. Install LTP (pending results of cement job). 22. Install GLVs. 23. POP. Perf Interval Perf Length Gun Length Weight of Gun (lbs) TBD, between 10,180’ MD and 12,940’ MD (Zone 2A- 1B) ч500’ч500’ч2300lbs (4.6ppf) TBD, between 10,180’ MD and 12,940’ MD (Zone 2A- 1B) ч500’ч500’ч2300lbs (4.6ppf) Perf Procedure N-07B PTD: 223-122 Attachments: x Wellbore Schematic (as-planned to be drilled) x Proposed Schematic (as-planned to be drilled and perforated) x Coil Tubing BOPE Schematic x Equipment Layout Diagram x Standing Orders for Open Hole Well Control during Perf Gun Deployment x Sundry Change Form Perf Procedure N-07B PTD: 223-122 As-planned to-be-drilled Wellbore Schematic Perf Procedure N-07B PTD: 223-122 Proposed Schematic (perforated) Perf Procedure N-07B PTD: 223-122 Coiled Tubing BOPs Perf Procedure N-07B PTD: 223-122 Standing Orders for Open Hole Well Control during Perf Gun Deployment Perf Procedure N-07B PTD: 223-122 Equipment Layout Diagram Perf Procedure N-07B PTD: 223-122 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU N-07B Hilcorp Alaska, LLC Permit to Drill Number: 223-122 Surface Location: 3061' FNL, 4709' FEL, Sec 08, T11N, R13E UM, AK Bottomhole Location: 1712' FNL, 890' FEL, Sec 09, T11N, R13E, 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 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 Chmielowski Commissioner DATED this 2 day of January 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 09:58:36 -09'00' Drilling Manager 12/27/23 Monty M Myers By Grace Christianson at 7:34 am, Dec 28, 2023 50-029-20137-02-00 A.Dewhurst 28DEC23 223-122 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented production liner. MGR29DEC23*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 09:58:50 -09'00' 01/02/24 01/02/24 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 13, 2023 Re:N-07B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well N-07A with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for N-07B Producer: 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 then 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 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 + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 4 and land in Zone 2. The lateral will continue in Zone 2/1 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 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 Dec 29th, 2023) Reference N-07A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift. Caliper. DGLVs. 2. E-Line : Set Whipstock @ 10,180' 30 deg ROHS 3. Coil : Mill XN nipple and Window (if window not possible, mill with rig) 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in January 19, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2500 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~174' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2586' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner 6. Pump primary cement job: 37 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. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 2. Service Coil : Post rig RPM log and perforate (200’- 400'). 3. Tie In : Disconnect Injection lines, convert to production line and twin with N-30 w/ SSV eqpt. Sundry 323-669 PTD 223-122 Change 3" rams to VBRs. - mgr 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 (10180' MD -8679' TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4423 psi 4423 psi 9.8 B Annular friction - ECD (psi/ft)611 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3881 psi 3881 psi 8.6 B+C Mud + ECD Combined 4492 psi 3881 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain -69 psi 542 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The reservoir pressure is expected to be 3381 psi at 8800 TVD. (7.4 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2500 psi. A min EMW of 8.4 ppg for this well will be 411 psi Overbalanced to the reservoir. 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: 4.25" hole for the entirety of the production hole section. Liner Program: 3-1/2", 9.3#, 13Cr Solid: 9760' MD – 10170' MD (410' liner) 3-1/4", 6.6#, 13Cr Solid: 10170' MD – 10380' MD (210' liner) 2-7/8", 6.5#, 13Cr Solid: 10380' MD – 12940' MD (2560' 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. A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. 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: Directional plan attached. Maximum planned hole angle is 90°. Inclination at kick off point is 8°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – 21,013 ft Distance to nearest well within pool – 1110 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: 200' - 400' perforated post rig – See future perf sundry. 2" 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: The J-09A Wellbore fails anti-collision with the N-07B WP06 wellpath. The J-09A wellbore was abandoned in 2013 with a CTD cemented liner. Hazards: N pad is not an H2S pad. H2S reading on N-07A: 16 ppm on 10/1/2013. Max H2S recorded on N pad: 96 ppm.. 1 fault crossings expected. Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka Change 3" rams to 2-7/8 x 3-1/2" VBRs - mgr 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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" 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 3.0" Pipe / Slip 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. X PRUDHOE OIL 223-122 PBU N-07B PRUDHOE BAY W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p N o r t h S l o p e , L L C We l l N a m e : PR U D H O E B A Y U N I T N - 0 7 B In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 6 5 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 1 2 2 0 PR U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 NA 1 P e r m i t f e e a t t a c h e d Ye s AD L 0 2 8 2 8 2 a n d A D L 0 2 8 2 8 1 2 L e a s e n u m b e r a p p r o p r i a t e Ye s 3 U n i q u e w e l l n a m e a n d n u m b e r Ye s P R U D H O E B A Y , P R U D H O E O I L - 6 4 0 1 5 0 - g o v e r n e d b y 3 4 1 J 4 W e l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r s NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) NA T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 18 C o n d u c t o r s t r i n g p r o v i d e d NA A l l d r i l l i n g o n t h i s s i d e t r a c k w i l l b e l o w e x i s t i n g s u r f a c e c a s i n g s h o e . 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s NA T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s T h i s w e l l i s a i n z o n e C T D s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s F u l l y c e m e n t e d p r o d u c t i o n l i n e r . P a r e n t w e l l i s o l a t e s t h e r e s e r v o i r . 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s C D R 2 h a s a d e q u a t e t a n k a g e a n d g o o d t r u c k i n g s u p p o r t . 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t Ye s S u n d r y 3 2 3 - 6 6 9 25 I f a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s H a l l i b u r t o n c o l l i s i o n s c a n s h o w s m a n a g e a b l e c o l l i s i o n r i s k . 26 A d e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d NA A l l d r i l l i n g b e l o w t h e s u r f a c e c a s i n g s h o e . N o d i v e r t e r r e q u i r e d . 27 I f d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s M P D b u t r e s e r v o i r p r e s s u r e b e l o w w a t e r g r a d i e n t . 28 D r i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s C T P a c k o f f , f l o w c r o s s , a n n u l a r , b l i n d s h e a r , C T p i p e s l i p s , f l o w c r o s s , B H A p i p e s l i p s , C T p i p e s l i p s 29 B O P E s , d o t h e y m e e t r e g u l a t i o n Ye s 7 - 1 / 1 6 " 5 0 0 0 p s i s t a c k p r e s s u r e t e s t e d t o 3 5 0 0 p s i . 30 B O P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s F l a n g e d c h o k e a n d k i l l l i n e s b e t w e e n d u a l c o m b i ' s w r e m o t e c h o k e 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n No 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No H 2 S m e a s u r e s r e q u i r e d . M a x r e a d i n g o n N - p a d 9 6 p p m . 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s T a r g e t r e s e r v o i r p o r e p r e s s u r e a n t i c i p a t e d t o b e 7 . 4 p p g E M W 36 D a t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 S e i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 S e a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 C o n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 12 / 2 8 / 2 0 2 3 Ap p r MG R Da t e 12 / 2 8 / 2 0 2 3 Ap p r AD D Da t e 12 / 2 8 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& : JL C 1 / 2 / 2 0 2 4