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Home My WebLink About223-110CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Joseph Lastufka To:Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Date:Thursday, December 11, 2025 3:15:53 PM Meredith, Thank you for checking, all 3 wells are either planned to be re-permitted or scheduled further out than the expiration date. Please cancel all 3 wells: PBU NK-24 (PTD #223-108) PBU F-40A (PTD #223-110) PBU L-294 (PTD #223-127) Please let me know if you need anything else. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, December 11, 2025 2:34 PM To: Joseph Lastufka <joseph.lastufka@hilcorp.com> Subject: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Hello Joe, The following three approved permits are nearing their expiration dates. Does Hilcorp plan to drill any of these three wells, or should they be marked canceled in the AOGCC database? 1. 223-108 PBU NK-24, expires 2/13/2026 2. 223-110 PBU F-40A, expires 1/3/2026 3. 223-127 PBU L-294, expires 1/2/2026 Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-291 (PTD#213-110) Date:Friday, April 12, 2024 9:58:49 AM Attachments:AnnComm Surveillance TIO for CD4-291.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, April 11, 2024 5:36 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-291 (PTD#213-110) Chris, CRU CD4-291 (PTD#213-110) was reported by operations for high IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CD4-291 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-291 2024-03-01 2400 1000 -1400 IA CD4-291 2024-04-02 2400 1610 -790 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD4-291 haggea Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Reset Inj Valve CD4-291 9/11/2019 boehmbh Notes: General & Safety Annotation End Date Last Mod By Note: Waivered for Water-Only Injection due to surface casing leak 9/20/2017 pproven NOTE: Mandrel Orientation #1) 9:30 10/22/2013 hipshkf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 16 15.06 35.0 114.0 114.0 62.50 H-40 Welded SURFACE 10 3/4 9.95 36.9 2,436.4 2,378.5 45.50 L-80 BTCM INTERMEDIATE 7 6.28 34.5 7,209.7 6,210.2 26.00 L-80 BTCM LINER 3 1/2 2.99 6,703.9 12,585.0 6,244.2 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth … 6,745.4 Set Depth … 6,094.4 String Ma… 3 1/2 Tubing Description TUBING 4.5x3.5"@138' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.4 31.4 0.00 HANGER 10.850 FMC TUBING HANGER FMC 1183180 01 3.958 138.6 138.6 0.13 XO - Reducing 5.220 XO - 4 1/2" IBT (B) x 3 1/2" EUE 8 RD (P) CPAI 1054194 7 2.992 2,009.3 1,974.3 19.41 NIPPLE 4.503 CAMCO BP-6i NIPPLE w/ 2.812" DS profile CAMCO 3404100 1/#08 2.812 6,658.5 6,058.2 63.66 GAS LIFT 5.390 Mandrel 3 1/2" x 1" KBMG w/ DCK-2 SV set @ 2500 psi w/BEK latch CAMCO KBMG 2.920 6,675.7 6,065.7 64.34 NIPPLE 3.960 HES X LANDING NIPPLE CAMCO 1060123 2.813 6,714.5 6,082.0 65.89 LOCATOR 5.000 BAKER LOCATOR (5.00" OD) BAKER 2.990 6,715.7 6,082.5 65.94 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSY BAKER H02672 62-01 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,009.3 1,974.2 19.41 INJ VALVE 2.81" A-1 INJ VLV (S/N: HABS -0223/ 1.5" ORIFICE) ON B-7 LOCK 9/11/2019 1.500 6,671.0 6,063.7 64.16 FISH RHC PLUG BODY PUSHED DOWNHOLE TO NIPPLE AND HELD BY SLIPSTOP 10/12/2013 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,658.5 6,058.2 63.66 1 GAS LIFT DMY BK 1 0.0 2/1/2018 CAMCO KBMG 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,703.9 6,077.7 65.47 PACKER 5.800 BAKER HRD ZXP LINER TOP PACKER BAKER H29645010 9 4.320 6,723.9 6,085.9 66.27 NIPPLE 5.270 BAKER 5'' RS NIPPLE BAKER H29401553 4.250 6,736.1 6,090.7 66.76 XO Threads 5.260 Sub 5'' 15# Hyd 521 box x box BAKER P04517479 583 4.400 6,745.7 6,094.5 67.14 XO THREAD 5.260 crossover 5'' Hyd 521 x 3 1/2'' EUE 8 rd BAKER 13561056 2.960 6,761.4 6,100.5 67.78 NIPPLE 3.960 HES XN LANDING NOGO NIPPLE 10606637 2.813 7,025.0 6,179.9 77.00 XO Threads 3.500 Crossover 3 1/2'' EUE x 3 1/2'' SLHT 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,246.6 7,339.7 6,214.5 6,218.3 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 7,559.6 8,895.7 6,217.3 6,214.4 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 8,990.0 9,230.2 6,215.2 6,219.0 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 9,387.0 10,481.9 6,219.1 6,223.8 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 10,889.6 11,505.2 6,234.0 6,240.7 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 11,693.3 12,270.2 6,240.5 6,243.9 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft 12,364.1 12,454.5 6,245.1 6,246.4 9/29/2013 16.0 SLOTS Slotted 2 1/4" x .125 slots/8 rows/16 slots/ft HORIZONTAL, CD4-291, 6/13/2023 12:20:13 PM Vertical schematic (actual) LINER; 6,703.9-12,585.0 SLOTS; 12,364.1-12,454.5 SLOTS; 11,693.3-12,270.2 SLOTS; 10,889.5-11,505.2 SLOTS; 9,387.0-10,481.9 SLOTS; 8,990.0-9,230.1 SLOTS; 7,559.6-8,895.7 SLOTS; 7,246.6-7,339.7 INTERMEDIATE; 34.5-7,209.7 NIPPLE; 6,675.7 FISH; 6,671.0 GAS LIFT; 6,658.5 SURFACE; 36.9-2,436.4 INJ VALVE; 2,009.3 NIPPLE; 2,009.3 CONDUCTOR Insulated 34"; 35.0-114.0 HANGER; 31.4 WNS INJ KB-Grd (ft) 36.47 RR Date 10/2/2013 Other Elev… CD4-291 ... TD Act Btm (ftKB) 12,595.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032067200 Wellbore Status INJ Max Angle & MD Incl (°) 92.11 MD (ftKB) 12,535.30 WELLNAME WELLBORECD4-291 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP 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 F-40A Hilcorp Alaska, LLC Permit to Drill Number: 223-110 Surface Location: 2273' FSL, 2394' FWL, Sec 02, T11N, R13E, UM, AK Bottomhole Location: 120' FSL, 1069' FEL, Sec 03, T11N, R3E, UM, AK DearMr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. PerStatute 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, -HVVLH&KPLHORZVNL &RPPLVVLRQHU DATED this2 day of January 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 09:24:16 -09'00' 3-1/2"x3-1/4" Drilling Manager 11/20/23 Monty M Myers By Grace Christianson at 3:20 pm, Nov 20, 2023 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement with fully cemented liner on this lateral. SFD 11/27/2023MGR21NOV2023 223-110 DSR-11/20/23 50-029-22215-01-00 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.01.02 09:24:31 -09'00' 01/02/2024 01/02/2024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 20, 2023 Re: PBU F-40A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well F-40 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for F-40A Producer: See F-40 Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2"x5- 1/2" whipstock. E-line or coil will mill the SWN-nipple. Coil will mill window pre-rig. If unable to set the whipstock or mill 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"x5-1/2" 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 Ivishak Zone 2. The lateral will continue in Zone 2 and 1 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 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: Reference F-40 Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and Caliper 2. E-Line : Set Whipstock 3. Fullbore : MIT 4. Coil : Mill SWN nipple and Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in December 2023) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2.Mill 3.80” Window (if not already done pre-rig) 3.Drill build section: 4.25" OH, ~531' (25 deg DLS planned). 4.Drill production lateral: 4.25" OH, ~2,371' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” L-80 solid liner 6.Pump primary cement job: 42 bbls, 15.3 ppg Class G, TOC at TOL*. 7.Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9.Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1.Valve Shop : Valve & tree work 2.Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 3.Service Coil : Post rig perforate (~600’) and RPM. 4.Testing : Portable test separator flowback. PTD 223-110 Sundry 323-630 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 (10,170' MD -8,669' TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,418 psi 4,418 psi 9.8 B Annular friction - ECD (psi/ft)610 psi 0 psi 0.06 C Mud Hydrostatic (ppg)3,877 psi 3,877 psi 8.6 B+C Mud + ECD Combined 4,487 psi 3,877 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 541 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The reservoir pressure is expected to be 3,267 psi at 8,800’ TVD. (7.14 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,387 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. (7.14 ppg equivalent) Liner Program: x 3-1/2", 9.3#, L80/Solid: 9,700' MD – 10,150' MD (450' liner) x 3-1/4", 6.6#, L80/Solid: 10,150' MD – 10,700' MD (550' liner) x 2-7/8", 6.5#, L80/Solid: 10,700' MD – 13,072' MD (2,372' 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” pipe/slip rams (for drilling) to 2-3/8”x3-1/2” 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 93°. Inclination at kick off point is 41°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 14,540 ft x Distance to nearest well within pool – 550 ft Logging: x MWD directional and Gamma Ray will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x 600' perforated post rig – See future perf sundry. 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 Ivishak pool. Anti-Collision Failures: x Anti-Collision Summary – all wells pass (WP02) Hazards: x F is an H2S pad. H2S reading on F-40: 2 ppm (2023). x Max H2S recorded on F-24: 160 ppm (2007). x No fault crossings expected. x Low lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) F is an H2S pad. -4 5 0 0 -4 0 0 0 -3 5 0 0 -3 0 0 0 -2 5 0 0 -2 0 0 0 -1 5 0 0 -1 0 0 0 South(-)/North(+) (1000 usft/in) -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 We s t ( - ) / E a s t ( + ) ( 1 0 0 0 u s f t / i n ) 9014 J-17D 90 1 2 J- 05A 7 6 00 8 0 00 84 0 0 88 0 0 92 009290 F -0 9 88 00 F-09B F -09 A F- 0 9 C 9 0 42 F -1 6A 7 20 0 7 6 0 0 8 0 0 0 8 40 0 8 80 0 F -17 A 5 2 00 5 6 0 0 600 0 64 0 0 68 0 0 7 2 0 0 7600 800 0 8 40 0 88 0 0F-17 520 0 5600 6000 640 0 6800 720 0 7600 8000 8400 8800 9180 F-40 56 00 6000 6400 680 0 7200 760 0 8000 8 400 88 00 90 66 F -08 9 0 5 5F-0 8 A F-0 8 B 6 0 0 0 6 4 00 6 8 0 0 720 0 7600 8 0 00 8400 8 80 0 920 0 9 3 41 F-1 5 90 46 F-1 5 A 8 8 0 0 9 03 5 F-1 5 B F - 0 2 A 8400 88 00 92 0 0 93 18 F -0 2 8000 84 00 8 8 00 9 0 54F-0 2P B 1 88 0 0 9045 F- 4 0 A w p 0 2 To p o f W i n d o w ( 1 0 , 1 7 0 ' M D ) En d 2 5 d l s ( 1 0 , 7 0 1 ' M D ) TD ( 1 3 , 0 7 2 ' M D ) 87 0 0 88 0 0 89 0 0 90 0 0 91 0 0 True Vertical Depth (200 usft/in) -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 Ve r t i c a l S e c t i o n a t 3 2 0 . 0 0 ° ( 4 0 0 u s f t / i n ) F-40 F-40A wp02 Se c MD I n c A z i TV D +N / - S +E / - W D l e g T F a c e VS e c t 1 1 0 1 7 0 . 0 0 4 1 . 1 0 2 1 8 . 8 7 8 6 6 9 . 7 3 - 3 7 4 6 . 6 8 - 1 9 7 9 . 6 6 0 . 0 0 0 . 0 0 - 1 5 9 7 . 6 3 2 1 0 1 9 0 . 0 0 3 9 . 3 0 2 1 8 . 8 7 8 6 8 5 . 0 1 - 3 7 5 6 . 7 3 - 1 9 8 7 . 7 6 9 . 0 0 1 8 0 . 0 0 - 1 6 0 0 . 1 2 3 1 0 2 7 5 . 0 0 1 8 . 0 5 2 1 8 . 8 7 8 7 5 9 . 1 6 - 3 7 8 8 . 3 1 - 2 0 1 3 . 2 0 2 5 . 0 0 1 8 0 . 0 0 - 1 6 0 7 . 9 5 4 1 0 7 0 0 . 8 2 9 0 . 0 0 1 4 . 9 6 9 0 5 0 . 7 3 - 3 5 6 6 . 0 2 - 1 9 9 3 . 6 9 2 5 . 0 0 1 5 5 . 0 0 - 1 4 5 0 . 2 1 5 1 0 8 1 8 . 8 2 9 2 . 9 2 1 . 0 9 9 0 4 7 . 7 1 - 3 4 4 9 . 5 1 - 1 9 7 7 . 2 5 1 2 . 0 0 - 7 8 . 0 0 - 1 3 7 1 . 5 2 6 1 0 9 3 8 . 2 3 9 0 . 0 0 3 4 7 . 0 6 9 0 4 4 . 6 6 - 3 3 3 1 . 0 8 - 1 9 8 9 . 5 5 1 2 . 0 0 - 1 0 1 . 5 0 - 1 2 7 2 . 9 0 7 1 1 0 9 8 . 0 0 9 0 . 0 0 6 . 2 3 9 0 4 4 . 6 6 - 3 1 7 2 . 3 3 - 1 9 9 8 . 8 6 1 2 . 0 0 9 0 . 0 0 - 1 1 4 5 . 3 0 8 1 1 3 7 8 . 0 0 9 0 . 0 0 3 3 2 . 6 3 9 0 4 4 . 6 6 - 2 9 0 1 . 0 1 - 2 0 4 9 . 4 9 1 2 . 0 0 - 9 0 . 0 0 - 9 0 4 . 9 1 9 1 1 5 7 8 . 0 0 9 0 . 0 0 3 0 8 . 6 3 9 0 4 4 . 6 6 - 2 7 4 7 . 5 3 - 2 1 7 5 . 4 4 1 2 . 0 0 - 9 0 . 0 0 - 7 0 6 . 3 8 10 1 1 7 2 8 . 0 0 9 0 . 0 0 3 2 6 . 6 3 9 0 4 4 . 6 6 - 2 6 3 7 . 1 6 - 2 2 7 6 . 1 1 1 2 . 0 0 9 0 . 0 0 - 5 5 7 . 1 3 1 1 1 2 0 8 8 . 0 0 9 0 . 0 0 2 8 3 . 4 3 9 0 4 4 . 6 6 - 2 4 3 5 . 3 8 - 2 5 6 3 . 9 6 1 2 . 0 0 - 9 0 . 0 0 - 2 1 7 . 5 3 1 2 1 2 3 6 8 . 0 0 9 0 . 0 0 3 1 7 . 0 3 9 0 4 4 . 6 6 - 2 2 9 6 . 4 2 - 2 8 0 2 . 4 3 1 2 . 0 0 9 0 . 0 0 4 2 . 2 1 13 1 2 5 0 0 . 0 0 9 0 . 0 0 3 0 1 . 1 9 9 0 4 4 . 6 6 - 2 2 1 3 . 4 2 - 2 9 0 4 . 5 3 1 2 . 0 0 - 9 0 . 0 0 1 7 1 . 4 2 14 1 2 8 6 0 . 0 0 9 0 . 0 0 2 5 7 . 9 9 9 0 4 4 . 6 6 - 2 1 5 4 . 8 6 - 3 2 5 1 . 1 5 1 2 . 0 0 - 9 0 . 0 0 4 3 9 . 0 8 15 1 3 0 7 2 . 0 0 9 0 . 0 0 2 8 3 . 4 3 9 0 4 4 . 6 6 - 2 1 5 2 . 2 5 - 3 4 6 1 . 4 0 1 2 . 0 0 9 0 . 0 0 5 7 6 . 2 2 Pr o j e c t : P r u d h o e B a y Si t e : F We l l : F - 4 0 We l l b o r e : P L A N : F - 4 0 A Pl a n : F - 4 0 A w p 0 2 WE L L B O R E D E T A I L S Pa r e n t W e l l b o r e : F- 4 0 To p o f W i n d o w : 1 0 1 7 0 . 0 0 F- 4 0 A w p 0 2 De p t h F r o m D e p t h T o S u r v e y / P l a n T o o l 92 . 0 0 1 0 1 7 0 . 0 0 1 : S c h l u m b e r g e r G C T m u l t i s h o t ( F - 4 0 ) 3 _ G y r o - C T _ p r e - 1 9 9 8 _ C s g 1 10 1 7 0 . 0 0 1 3 0 7 2 . 0 0 F - 4 0 A w p 0 2 ( P L A N : F - 4 0 A ) 3 _ M W D WE L L D E T A I L S No r t h i n g : 5 9 7 3 7 9 2 . 9 6 Ea s t i n g : 6 5 1 9 5 9 . 2 1 La t t i t u d e : 7 0 . 3 3 5 4 2 5 3 1 4 Lo n g i t u d e : - 1 4 8 . 7 6 7 1 0 2 3 4 1 F- 4 0 A w p 0 2 SE C T I O N D E T A I L S Hi l c o r p A l a s k a , L L C SU R V E Y P R O G R A M NA D 1 9 2 7 ( N A D C O N C O N U S ) US S t a t e P l a n e 1 9 2 7 ( E x a c t s o l u t i o n ) Al a s k a Z o n e 0 4 PR O J E C T D E T A I L S RE F E R E N C E I N F O R M A T I O N Co o r d i n a t e ( N / E ) R e f e r e n c e : W e l l F - 4 0 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : K e l l y B u s h i n g / R o t a r y T a b l e @ 6 7 . 4 3 u s f t ( D O Y O N 1 6 ) Me a s u r e d D e p t h R e f e r e n c e : K e l l y B u s h i n g / R o t a r y T a b l e @ 6 7 . 4 3 u s f t ( D O Y O N 1 6 ) Se c t i o n ( V S ) R e f e r e n c e : S l o t - ( 0 . 0 0 N , 0 . 0 0 E ) Ca l c u l a t i o n M e t h o d : M i n i m u m C u r v a t u r e RE F E R E N C E I N F O R M A T I O N !!" #$ %& ! 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rudhoe Bay Unit Sec. 2 Sec. 10 Sec. 11 Sec. 3 U011N013E FRONTIER PAD F PAD ADL28281 ADL28280 PLAN: F-40A_SHL PLAN: F-40A_TPH PLAN: F-40A_BHL Map Date: 11/20/2023 Prudhoe Bay Unit F-40A Well wp02 E0 540 1,080Feet Legend $)F-40A_BHL ! F-40A_SHL D F-40A_TPH $)Other Bottom Holes (BHL) Other Well Paths Oil and Gas Unit Boundary Pad Footprint Participating Areas CO_341J AIO_3C Do c u m e n t P a t h : O : \ A W S \ G I S \ P r o d u c t s \ A l a s k a \ N S \ W e l l s \ T R S _ D i s t a n c e \ m x d s \ 2 0 2 3 \ N o r t h S l o p e _ P B U _ F - 4 0 A _ w p 0 2 . m x d 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 HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 PBU F-40A PRUDHOE OIL 223-110 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 F - 4 0 A 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 1 0 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 0 2 8 2 8 0 a n d A D L 0 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 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 ) 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 . 18 C o n d u c t o r s t r i n g p r o v i d e d Ye s 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 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 . 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 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 . F u l l i n t e g r i t y a b o v e s i d e t r a c k . 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 3 0 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 Ye s F p a d i s a n H 2 S p a d , m o n i t o r i n g w i l l b e r e q u i r e d . 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 T h i s i s a d e v e l o p m e n t w e l l . 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 a r e r e q u i r e d . M a x r e a d i n g o f 1 6 0 p p m a t F - 2 4 ( 2 0 0 7 ) 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 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 . 1 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 9 / 2 0 2 3 Ap p r MG R Da t e 11 / 2 9 / 2 0 2 3 Ap p r AD D Da t e 12 / 2 9 / 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