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Home My WebLink About224-004Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/29/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250529 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 5/10/2025 AK E-LINE GPT/CIBP/Perf HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL IRU 241-01 50283201840000 221076 5/7/2025 AK E-LINE Plug/Perf KBU 22-06Y 50133206500000 215044 5/6/2025 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 5/7/2025 AK E-LINE Perf KBU 24-06RD 50133204990100 206013 4/8/2025 YELLOWJACKET GPT-PLUG MPI 1-61 50029225200000 194142 5/10/2025 AK E-LINE Perf MPU E-42 50029236350000 219082 5/3/2025 AK E-LINE Patch MPU S-55 50029238130000 225006 5/13/2025 AK E-LINE CBL OP16-03 50029234420000 211017 4/25/2025 READ LeakDetect PAXTON 13 50133207330000 225021 4/29/2025 YELLOWJACKET SCBL PBU 01-12B 50029202690200 223090 4/8/2025 HALLIBURTON RBT PBU D-08B 50029203720200 225007 3/22/2025 BAKER MRPM PBU H-17B (REVISION)50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU J-25B 50029217410200 224134 3/10/2025 BAKER MRPM PBU K-19C (REVISION)50029225310300 224004 3/27/2025 BAKER MRPM PBU K-19C 50029225310300 224004 3/27/2025 HALLIBURTON RBT SRU 241-33B 50133206960000 221053 3/12/2025 YELLOWJACKET PERF Revision Explanation: Both wells had wrong side stack well name and API#/PTD on previous upload H-17b was marked as H-17A and K-19C was marked as K-19B. Well name now reflets correct sidetrack and has correct SPI# and PTD. T40489 T40490 T40491 T40492 T40492 T40493 T40494 T40495 T40496 T40497 T40498 T40499 T40500 T40501 T40502 T40503 T40503 T40504 (REVISION)50029225310300 224004 3/27/2025 BAKER MRPM PBU K-19C 50029225310300 224004 3/27/2025 HALLIBURTON RBT PBU K-19C Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.29 14:33:01 -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: 04/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU K-19C PTD: 224-004 API: 50-029-22531-03-00 FINAL LWD FORMATION EVALUATION LOGS (03/13/2025 to 03/20/2025) 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. 224-004 T40280 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.04 15:27:21 -08'00' PBU K-19C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-004 50-029-22531-03-00 341J ADL 028303 ~14130'~8707 80 3471 9676 ~1546 ~3130' ~14100 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" ~8707 47 - 127 47 - 3518 45 - 9721 9566 - ~11112 ~11000- ~14130 2524 47 - 127 47 - 3517 45 - 8172 8044 -~8635 ~8628 - ~8707 NoneNone 1490 6870 7240 8430 10160 None 4-1/2" 12.6# 13Cr85 42 - 9571None 4-1/2" HES TNT Perm Packer No SSSV Installed 9451, 7950 Torin Roschinger Operations Manager Brodie Wages david.wages@hilcorp.com 907-777-8396 PRUDHOE BAY 3/5/2025 PRUDHOE OIL PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.02.17 11:32:55 - 09'00' Torin Roschinger (4662) 325-082 By Gavin Gluyas at 8:54 am, Feb 18, 2025 SFD 3/3/2025 10-404 JJL 2/25/25 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill for each shift using attached standing orders. Ensure well is dead prior to breaking containment DSR-2/18/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.03 08:55:34 -09'00' RBDMS JSB 030425 Post Rig ExtADP K-19C PTD: 224-004 Well Name:K-19C API Number: 50-029-22531-03-00 Current Status:Operable Producer Rig:Slickline / Coil Estimated Start Date:March 2025 Estimated Duration:3days Regulatory Contact:Abbie Barker / Joe Lastufka Permit to Drill Number:224-004 First Call Engineer:David Wages 713.380.9836 Second Call Engineer:Finn Oestgaard 907.350.8420 Current Bottom Hole Pressure:3379 psi @ 8554’ TVD 7.6 ppg (1/2016 SBHPS) Max. Anticipated Surface Pressure:2524 psi with 0.1 psi/ft gas in wellbore Min ID:2.441” 3-3/16”x2-7/8” XO @ 11,312’ MD Max Angle: ~90 Deg @ 2-7/8” Liner Tie In Log: CTD Drilling OH Log Brief Well Summary: New CTD Lateral Objective: The objective of this program is to perform post rig operations to POP the well. Sundry Procedure: Coil –Extended Perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. 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. 1. 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. 2. Drift for RPM 3. Displace well to 1% KCl in prep for RPM 4. Perform Liner Lap test to 1200 psi 5. Pull 2 RPM w/ GR/CCL in GasView mode from PBTD to top of liner a. Rush analysis, RPM to be used as tie in 6. Bullhead 1.2x wellbore volume ~225 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a.Wellbore volume to PBTD (~14,120’) =187 bbls b. 4-1/2” Tubing/ 4-1/2” Liner to top of CTD Liner – 11,000’ X .0152 bpf = 168 bbl c. CTD liner to planned PBTD = 19 bbls 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, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Post Rig ExtADP K-19C PTD: 224-004 *Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders 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. a. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 9.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” MaxForce 070 charges 6 SPF Perf Interval Perf Length Gun Length Weight of Gun (lbs) TBD Max 500’Max 500’2790lbs (5.58ppf) 10. RIH with perf gun and lightly tag CIBP for depth control (as needed). Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 11. After perforating, PUH to top of liner or into tubing 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. 12. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 13. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 14. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. RDMO CTU. 16. Turn well over to Operations POP. Slickline 17. Contingent on Liner Lap Test: Set chrome 4.5" LTP with PTSA in 3.00" polish bore. Test LTP to 1500 psi. OE to provide spaceout based on final TOL depth. 18. Install generic kick off design per GLE. a. Expected rates: 740 bopd, 56 bwpd, 18.8 mmscfd. Testers: 19. MIRU Well Test Unit a. Work with pad op to determine flowline to use if the tie in is not complete 20. POP well per SLBU program below 21. Once well is on stable production, obtain a 12 hour piggyback well test a. Retest as needed to confirm pad separator rates Attachments: Current Wellbore Schematic - K-19B Pre CTD Proposed Schematic - K-19C Post CTD Coil Tubing BOPE Schematic Equipment Layout Diagram Standing Orders for Open Hole Well Control during Perf Gun Deployment Tie-In Log Sundry Change Form KOP for redrilled well lies within the Ivishak Formation. SFD Post Rig ExtADP K-19C PTD: 224-004 Current Wellbore Schematic Post Rig ExtADP K-19C PTD: 224-004 Proposed Schematic Post Rig ExtADP K-19C PTD: 224-004 Coiled Tubing BOPs Post Rig ExtADP K-19C PTD: 224-004 Equipment Layout Diagram Post Rig ExtADP K-19C PTD: 224-004 Standing Orders for Open Hole Well Control during Perf Gun Deployment Post Rig ExtADP K-19C PTD: 224-004 Tie-In Log (CTD OH Log) Post Rig ExtADP K-19C PTD: 224-004 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 K-19C Hilcorp Alaska, LLC Permit to Drill Number: 224-004 Surface Location: 3100' FSL, 4766' FEL, Sec 04, T11N, R14E, UM, AK Bottomhole Location: 1506' FSL, 2471' FEL, Sec 03, T11N, R14E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this 22 day of January 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.22 12:48:00 -09'00' 3-1/2"x3-1/4" 11480, 11725, 12050, 12520, 14045 Drilling Manager 01/11/24 Monty M Myers By Grace Christianson at 8:19 am, Jan 12, 2024 50-029-22531-03-00 MGR17JAN24 A.Dewhurst 17JAN24 DSR-1/19/24 224-004 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112 (i) Approved for alternate plug placement with fully cemented production liner. April *&:JLC 1/22/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.22 12:48:17 -09'00' 01/22/24 01/22/24 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 11, 2024 Re:K-19C Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well K-19B with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for K-19C Producer: See K-19B 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. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set a 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation out of the 4- 1/2" liner. The well will kick off drilling in the Ivishak Zone 2 and lands in Zone 1. The lateral will continue in Zone 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 whipstock and 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: x Reference K-19B Sundry submitted in concert with this request for full details. 1. Coil : Drift whipstock, mill XN nipple 2. SL : Dummy GLV 3. FB : Load IA, MIT-IA to 2500 psi 4. V : Pre-CTD tree prep Rig Work: (Estimated to start in January) 1.MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,552 psi). Give AOGCC 24hr notice prior to BOPE test. 2.Set 4-1/2" packer whipstock 3. Mill 3.80” Window. 4.Drill production lateral: 4.25" OH, ~3,018' (12 deg DLS planned). 5.Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (Swap to VBRs prior to running liner) 6. Pump primary cement job: 40 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. 8.Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1.Valve Shop : Valve & tree work 2.Slickline : Set LTP* (if necessary). Set live GLVs. 3.Service Coil : Post rig perforate (~800’) and RPM. 4. Testing : Portable test separator flowback. 40 bbls, 15.3 ppg Class G, PTD 224-004 Sundry 324-013 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 (11112' MD -8635' TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4400 psi 4400 psi 9.8 B Annular friction - ECD (psi/ft)667 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3862 psi 3862 psi 8.6 B+C Mud + ECD Combined 4528 psi 3862 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 539 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The reservoir pressure is expected to be 3,343 psi at 8,800 TVD. (7.49 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,552 psi. x A min EMW of 8.4 ppg for this well will be 412 psi Underbalanced to the reservoir. 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. See emails for details. -A.Dewhurst 17JAN24 reservoir pressure is expected to be 3,343 psi at 8,800 TVD. (7.49 ppg equivalent). overbalanced Liner Program: x 3-1/2", 9.3#, 13Cr /Solid: 11,000' MD – 11,100' MD (100' liner) x 3-1/4", 6.6#, 13Cr /Solid: 11,100' MD – 11,312' MD (212' liner) x 2-7/8", 6.5#, 13Cr /Solid: 11,312' MD – 14,130' MD (2,818' 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 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 90°. Inclination at kick off point is 85°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 14,580 ft x Distance to nearest well within pool – 900 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 800'' 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 All wells pass for WP02 Hazards: x K pad is not an H2S pad. The last H2S reading on K-19B: 20 ppm in 2023. x Max H2S recorded on K pad: 30 ppm on K-10C in 2013. x 1 fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) H2S measures required. -A.Dewhurst 16JAN24 - 3" pipe rams to be replaced by VBRs for liner running. $) $) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $ $) $) $) $) $) $ $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) ! ! !!!!! !!!!!! !!!!!!!!!!!!!!!!! !!!!!! !!!!!!!!!!! !!! !!!!!! !!!!!!!!!! !! !!!!!!! ! !! !!!! !!!!!! !!!!! !!!!!! ! ! !D $) 15-21A 15-27A 15-27B 15-29 15-29A 15-29B E-09A E-09B K-02 K-03 K-03A K-03B K-04 K-04A K-04B K-04C K-06 K-06A K-07 K-07A K-07B K-07D K-07E K-07F K-10C K-10D K-12 K-12B K-16 K-16A K-17 K-17A K-20 K-20A K-20B K-20C K-317B Prudhoe Bay Unit Sec. 33 Sec. 10 Sec. 34 Sec. 9 Sec. 3Sec. 4 U012N014E U011N014E K PAD ADL28303 ADL28300 ADL28304 PLAN: K-19C_SHL PLAN: K-19C_TPH PLAN: K-19C_BHL Map Date: 12/14/2023 Prudhoe Bay Unit K-19C Well wp02 E0 1,000 2,000Feet Legend $)PLAN: K-19C_BHL !PLAN: K-19C_SHL D PLAN: K-19C_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 _ K - 1 9 C _ w p 0 2 . m x d -2 5 0 0 -2 0 0 0 -1 5 0 0 -1 0 0 0 -5 0 0 0 50 0 South(-)/North(+) (1000 usft/in) 5000 5500 6000 6500 7000 7500 8000 8500 We s t ( - ) / E a s t ( + ) ( 1 0 0 0 u s f t / i n ) 8 958 L1-23 K-10 C 8786 K-19BPB1 K-19B 88 0 08801K-1 7A P B1K-17APB 2 8707K-19C wp02 To p o f W i n d o w - 1 1 1 1 2 ' M D TD - 1 4 1 3 0 ' M D 85 5 0 86 0 0 86 5 0 87 0 0 87 5 0 True Vertical Depth (100 usft/in) 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 Ve r t i c a l S e c t i o n a t 1 2 0 . 0 0 ° ( 4 0 0 u s f t / i n ) K- 1 9 B P B 1 K- 1 9 C w p 0 2 To p o f W i n d o w - 1 1 1 1 2 ' M D TD - 1 4 1 3 0 ' M D Se c M D I n c A z i T V D + N / - S + E / - W D l e g T F a c e V S e c t 1 1 1 1 1 2 . 0 0 8 4 . 2 4 8 9 . 0 4 8 6 3 4 . 6 6 - 2 6 3 . 2 7 5 1 7 1 . 8 4 0 . 0 0 0 . 0 0 4 6 1 0 . 5 8 2 1 1 1 3 2 . 0 0 8 4 . 2 5 9 0 . 8 5 8 6 3 6 . 6 6 - 2 6 3 . 2 5 5 1 9 1 . 7 4 9 . 0 0 9 0 . 0 0 4 6 2 7 . 8 0 3 1 1 2 0 2 . 0 0 8 4 . 3 1 9 9 . 2 9 8 6 4 3 . 6 6 - 2 6 9 . 4 0 5 2 6 1 . 0 5 1 2 . 0 0 9 0 . 0 0 4 6 9 0 . 9 0 4 1 1 3 7 2 . 0 0 7 8 . 4 5 1 1 9 . 0 7 8 6 6 9 . 3 7 - 3 2 4 . 1 0 5 4 1 8 . 9 9 1 2 . 0 0 1 0 8 . 0 0 4 8 5 5 . 0 3 5 1 1 4 9 4 . 0 0 8 1 . 3 4 1 3 3 . 6 5 8 6 9 0 . 8 9 - 3 9 5 . 1 5 5 5 1 5 . 3 8 1 2 . 0 0 8 0 . 0 0 4 9 7 4 . 0 3 6 1 1 7 0 3 . 0 2 9 0 . 0 0 1 5 7 . 2 8 8 7 0 6 . 8 9 - 5 6 5 . 6 0 5 6 3 2 . 3 7 1 2 . 0 0 7 1 . 0 0 5 1 6 0 . 5 8 7 1 1 9 0 3 . 0 0 9 0 . 0 0 1 3 3 . 2 8 8 7 0 6 . 8 9 - 7 2 8 . 7 8 5 7 4 5 . 4 4 1 2 . 0 0 - 9 0 . 0 0 5 3 4 0 . 0 8 8 1 2 2 0 7 . 0 0 9 0 . 0 0 1 6 9 . 7 6 8 7 0 6 . 8 9 - 9 9 1 . 5 1 5 8 8 7 . 9 4 1 2 . 0 0 9 0 . 0 0 5 5 9 4 . 8 6 9 1 2 5 5 7 . 0 0 9 0 . 0 0 1 2 7 . 7 6 8 7 0 6 . 8 9 - 1 2 8 4 . 1 2 6 0 6 5 . 4 0 1 2 . 0 0 - 9 0 . 0 0 5 8 9 4 . 8 5 10 1 2 7 5 7 . 0 0 9 0 . 0 0 1 0 3 . 7 6 8 7 0 6 . 8 9 - 1 3 7 0 . 4 2 6 2 4 4 . 2 1 1 2 . 0 0 - 9 0 . 0 0 6 0 9 2 . 8 5 1 1 1 2 8 7 9 . 0 0 9 0 . 0 0 1 1 8 . 4 0 8 7 0 6 . 8 9 - 1 4 1 4 . 1 9 6 3 5 7 . 7 3 1 2 . 0 0 9 0 . 0 0 6 2 1 3 . 0 5 12 1 3 1 7 9 . 0 0 9 0 . 0 0 8 2 . 4 0 8 7 0 6 . 8 9 - 1 4 6 7 . 4 8 6 6 4 7 . 9 7 1 2 . 0 0 - 9 0 . 0 0 6 4 9 1 . 0 5 13 1 3 4 5 9 . 0 0 9 0 . 0 0 1 1 6 . 0 0 8 7 0 6 . 8 9 - 1 5 1 1 . 6 2 6 9 2 0 . 4 2 1 2 . 0 0 9 0 . 0 0 6 7 4 9 . 0 7 14 1 3 7 3 9 . 0 0 9 0 . 0 0 8 2 . 4 0 8 7 0 6 . 8 9 - 1 5 5 5 . 7 7 7 1 9 2 . 8 7 1 2 . 0 0 - 9 0 . 0 0 7 0 0 7 . 1 0 15 1 3 9 4 1 . 0 0 9 0 . 0 0 1 0 6 . 6 4 8 7 0 6 . 8 9 - 1 5 7 1 . 5 9 7 3 9 2 . 7 4 1 2 . 0 0 9 0 . 0 0 7 1 8 8 . 1 0 16 1 4 1 3 0 . 0 0 9 0 . 0 0 8 3 . 9 6 8 7 0 6 . 8 9 - 1 5 8 8 . 9 5 7 5 7 9 . 7 1 1 2 . 0 0 - 9 0 . 0 0 7 3 5 8 . 6 9 Pr o j e c t : P r u d h o e B a y Si t e : K We l l : K - 1 9 We l l b o r e : P L A N : K - 1 9 C Pl a n : K - 1 9 C 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 : K- 1 9 B P B 1 To p o f W i n d o w : 1 1 1 1 2 . 0 0 K- 1 9 C 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 22 3 . 0 6 3 5 0 8 . 8 5 K - 1 9 S r v y 1 M W D ( K - 1 9 ) 3 _ M W D 35 1 8 . 0 0 3 6 2 5 . 0 0 G y r o S S ( K - 1 9 B P B 1 ) 3 _ U n k n o w n G y r o 2 36 6 2 . 0 9 3 7 5 7 . 6 3 O T K M W D I N C 8 - 1 / 2 " ( K - 1 9 B P B 1 ) 3 _ M W D _ I n t e r p A z i ( B P I N C + T r e n d ) 37 8 8 . 4 7 3 9 1 4 . 6 5 O T K M W D I I F R 8 - 1 / 2 " ( K - 1 9 B P B 1 ) 3 _ M W D ( B P M W D + I F R ) 39 9 7 . 2 4 9 6 9 3 . 5 5 A T K M W D 8 - 1 / 2 " ( K - 1 9 B P B 1 ) 3 _ M W D ( B P M W D + I F R + M S - W O C A ) 97 3 6 . 0 5 1 1 1 1 2 . 0 0 O T K M W D I I F R 6 - 1 / 8 ( K - 1 9 B P B 1 ) 3 _ M W D ( B P M W D + I F R + M S - W O C A ) 11 1 1 2 . 0 0 1 4 1 3 0 . 0 0 K - 1 9 C w p 0 2 ( P L A N : K - 1 9 C ) 3 _ M W D WE L L D E T A I L S No r t h i n g : 5 9 7 5 0 2 5 . 2 5 Ea s t i n g : 6 7 0 7 8 7 . 9 0 La t t i t u d e : 7 0 ° 2 0 ' 1 5 . 6 6 3 5 N Lo n g i t u d e : 1 4 8 ° 3 6 ' 5 0 . 9 9 0 7 W K- 1 9 C 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 K - 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"# $ %&' , ) -. 8 # 1 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 nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1 Dewhurst, Andrew D (OGC) From:Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent:Wednesday, January 17, 2024 09:30 To:Dewhurst, Andrew D (OGC) Cc:Rixse, Melvin G (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL] PBU K-19C (PTD 224-004) - Question Thatisanincorrect“underbalanced”statement.Itshouldsay“overbalanced”. Sorryfortheconfusionandthanksforcheckinginonit. TrevorHyatt HilcorpAlaska,LLC DrillingEngineer Trevor.Hyatt@hilcorp.com Cell:907Ͳ223Ͳ3087 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Wednesday,January17,20248:42AM To:TrevorHyatt<Trevor.Hyatt@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov> Subject:[EXTERNAL]PBUKͲ19C(PTD224Ͳ004)ͲQuestion Trevor, WearecompleƟngthereviewofthePBUKͲ19CPTDandIhaveaquesƟon: Wouldyoupleaseclarifywhatyoumeanwiththepredictedunderbalanced8.4ppgŇuidvs.apredicted7.5ppgEMW reservoir? Youdon'toftengetemailfromtrevor.hyatt@hilcorp.com.Learnwhythisisimportant CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 Thanks, Andy AndrewDewhurst SeniorPetroleumGeologist AlaskaOilandGasConservaƟonCommission 333W.7thAve,Anchorage,AK99501 andrew.dewhurst@alaska.gov Direct:(907)793Ͳ1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. PRUDHOE BAY X 224-004 PBU K-19C PRUDHOE OIL POOL 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 K - 1 9 C 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 4 0 0 4 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 A D L 0 2 8 3 0 3 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 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 . 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 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 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 . 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 4 - 0 1 3 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 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 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 K - P a d w e l l s a r e H 2 S - b e a r i n g . H 2 S m e a s u r e s a r e r e q u i r e d . 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 h e r e s e r v o i r p r e s s u r e i s e x p e c t e d t o b e 3 , 3 4 3 p s i a t 8 , 8 0 0 T V D . ( 7 . 4 9 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 1/ 1 6 / 2 0 2 4 Ap p r MG R Da t e 1/ 1 7 / 2 0 2 4 Ap p r AD D Da t e 1/ 1 6 / 2 0 2 4 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 / 2 0 2 4