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Home My WebLink About224-099Nolan 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: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40300PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -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: 04/03/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU K-12D + PB1 + PB2 + PB3 + PB4 PTD: 224-099 API: 50-029-21759-04-00 (K-12D) 50-029-21759-73-00 (K-12DPB1) 50-029-21759-74-00 (K-12DPB2 50-029-21759-75-00 (K-12DPB3) 50-029-21759-76-00 (K-12DPB4) FINAL LWD FORMATION EVALUATION LOGS (02/07/2025 to 03/07/2025) 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. T40273 T40274 T40275 T40276 T40277 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.03 14:06:19 -08'00' 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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: K-12D 2nd stage of extended perforating PTD 224-099 Request Date:Tuesday, April 1, 2025 3:17:21 PM From: Lau, Jack J (OGC) Sent: Tuesday, April 1, 2025 3:16 PM To: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: K-12D 2nd stage of extended perforating PTD 224-099 Request Good afternoon Finn, You are approved for additional perforations via service coil extended perforating under the existing PTD - 224-099. You are granted a 2 week extension for the 10-407 submittal. Thanks Jack From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Tuesday, April 1, 2025 1:47 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: K-12D 2nd stage of extended perforating PTD 224-099 Request Hi Jack, We would like to add additional perforations to K-12D. This well is a recent CTD sidetrack (rig released 3/10) and service coil perforated 450’ over a 500 interval on 3/20). The initial POP was on 3/22 with DPBGL (No clean gas lift available on K-PAD). The well’s total fluid has declined from 496 bbls to 198 bbls of fluid with WC’s staying consistent in the single digits. It doesn’t appear we’re connecting to any gas to allow the well flow naturally, it still requires DPBGL to flow. We would like to add an additional 385’ of perfs over a 500’ interval next to the initial perfs resulting in 835’ of perfs. In the PTD we planned for ~800’, after drilling the well we thought a single extended perforating run would be sufficient, however after seeing initial production numbers we believe more footage is required. These additional perforations are in the same zone, they are essentially and extension of the initial perforations. Per the attached word program we would like to add additional perforations via service coil extended perforating under the existing PTD - 224-099. Our initial perf date was 3/20, resulting in a due date for the 10-407 on 4/19. We will attempt to execute this second round of perforations by 4/19, however at this time I’d like to request a 2 week extension for the 10-407 submittal. Please let me if you approve and if you have any questions or concerns. Thank you, Finn Finn Oestgaard GBP GC1 & GC3 Operations Engineer A,B,C,D,E,F,G,K,P,X,Y pads 907-564-5026 office 907-350-8420 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT K-12D JBR 04/03/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Both the HCR Kill and Choke initially failed. Greased and functioned and passed retest. N2 Precharge 16@ 1015 psi. 2-7/8" & 3-1/2" test joints used. Test Results TEST DATA Rig Rep:N. Wheeler/ T. JonesOperator:Hilcorp North Slope, LLC Operator Rep:R. Burnett/ E. Gregory Rig Owner/Rig No.:Nabors CDR2AC PTD#:2240990 DATE:3/8/2025 Type Operation:DRILL Annular: 250/3500Type Test:BIWKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopJDH250309095857 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 2415 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2-3/8"P Annular Preventer 1 7-1/16" GK P #1 Rams 1 Blind/Shear P #2 Rams 1 2-3/8" Pipe/Sl P #3 Rams 1 2-3/8"x3-1/2" P #4 Rams 1 2-3/8" Pipe/Sl P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"FP Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P2225 200 PSI Attained P21 Full Pressure Attained P60 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10@ 2015 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P5 #1 Rams P3 #2 Rams P3 #3 Rams P3 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9999 9 9 9Both the HCR Kill and Choke initially failed HCR Valves 2 FP 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Friday, March 7, 2025 3:03 PM To:Finn Oestgaard - (C) Cc:Torin Roschinger Subject:RE: Service Coil Extended Perforating BHA limitation question Hi Finn, Thanks for highlighting this issue. You have approval to run 500’ of perforating guns plus the BHA. Jack From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Friday, March 7, 2025 2:52 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Service Coil Extended Perforating BHA limitation question Hi Jack, Touching base in regards to clarificaƟon on extended perforaƟng with Service Coil. Since this operaƟon has been approved we have historically been perforaƟng with a gun length limitaƟon of 500’. Recent Sundry condiƟons of approval have included: PerforaƟng gun BHA not to exceed 500’. Our perforaƟng BHA’s include a couple items in addiƟon to the guns. If we load 500’ of guns, our BHA will be slightly over 500’ (firing head, swivel, disconnect, etc). Do we have permission to proceed with extended perforaƟng on service coil with a 500’ gun length limitaƟon - overall BHA will be slightly longer than 500’? Thank you, Finn 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. 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. 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Thursday, March 6, 2025 1:58 PM To:Trevor Hyatt Cc:Ryan Ciolkosz; Joseph Lastufka; Alaska NS - CDR2 - DSM Subject:RE: PBU K-12D (PTD #224-099) - BOP Test Extension Request Trevor, Your request for a 24-hour BOP test extension is approved. Thank you for including the previous BOP test reports. Jack From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Thursday, March 6, 2025 12:28 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Alaska NS - CDR2 - DSM <AlaskaNS-CDR2-DSM@hilcorp.com> Subject: PBU K-12D (PTD #224-099) - BOP Test Extension Request Jack, We have now reached TD in K-12D and have multiple shale sections open. Our BOP test is due tonight. We would like to request a 24-hour BOP test extension to allow us to perform our wiper trips and lay in liner running fluid prior to coming out of the hole. This will push us past midnight tonight. Then we will perform a full BOP test in conjunction with changing out to the VBR liner running rams (running liner immediately after). This will save time of performing a full BOP test today, followed by a separate cleanout run and changing to/testing our VBRs before running liner. With the shales open, eƯiciency is important from a wellbore stability and getting liner to TD standpoint. Please see the attached BOP test forms from the two previous tests we have performed while rigged up on this well. Let me know if you need anything else or have any questions. Thank you for your time and consideration! Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 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. 2 From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Wednesday, February 26, 2025 3:56 PM To: jack.lau@alaska.gov Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU K-12D (PTD #224-099) - Plugback and Sidetrack #4 Jack, PBU K-12D (PTD #224-099) Update: While drilling the lateral section we faulted higher into upper Zone 1 sands putting the target sand deeper in section. The team decided to set a billet and sidetrack to maximize footage in the target sand. Please let me know if you have any questions. Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB4 2/26/2025 9,900 – 11,907 MD 1219 Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 From: Ryan Ciolkosz Ryan.Ciolkosz@hilcorp.com Sent: Friday, February 21, 2025 2:26 PM To: Lau, Jack J (OGC) jack.lau@alaska.gov Cc: Joseph Lastufka Joseph.Lastufka@hilcorp.com; Trevor Hyatt Trevor.Hyatt@hilcorp.com; Ryan Ciolkosz Ryan.Ciolkosz@hilcorp.com Subject: PBU K-12D (PTD #224-099) - Plugback and Sidetrack #3 Jack, PBU K-12D (PTD #224-099) Update: While drilling the lateral section we faulted into upper Zone 1 sands putting the target sand deeper in section. The team decided to set a billet and sidetrack to maximize footage in the target sand. Please let me know if you have any questions. Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB3 2/19/2025 9940 – 11,159 MD 1219 3 Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Monday, February 17, 2025 2:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU K-12D (PTD #224-099) - Plugback and Sidetrack #2 Mel /Wade/Jack, PBU K-12D (PTD #224-099) Update: While drilling the lateral section we faulted into the BSAD shale unexpectedly (for a second time) and had wellbore stability issues in the shale. The team decided to set a billet and sidetrack to stay above the problematic shale. Please let me know if you have any questions. Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB2 2/14/2025 9,070 – 9,922 MD 852 Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Wednesday, February 12, 2025 1:58 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU K-12D (PTD #224-099) - Plugback and Sidetrack Mel /Wade/Jack, PBU K-12D (PTD #224-099) Update: While drilling the lateral section we faulted into the BSAD shale unexpectedly and had wellbore stability issues in the shale. The team decided to set a billet and sidetrack to stay above the problematic shale. Please let me know if you have any questions. 4 Sidetrack detail below: Sidetrack Date Depth Interval (ft) Length (ft) PB1 2/11/2025 9,405 – 9,827 MD 422 Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 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. Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.11.21 19:22:27 - 09'00' Sean McLaughlin (4311) By Grace Christianson at 10:30 am, Nov 22, 2024 324-664 DSR-11/22/24 10-407 A.Dewhurst 26NOV24WCB 11-25-2024 * BOPE pressure test to 3500 psi. * All window milling work to be performed under PTD 224-099 * Commencement of CTD drilling under PTD 224-099 to start no later than 60 days after completion of window milling. MGR25NOV24 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.29 11:32:48 -09'00'11/29/24 RBDMS JSB 112924 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 21, 2024 Re:K-12D Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well K-12C with the Nabors CDR2 or CDR3 rig. Proposed plan for K-12D Producer: See K-12C Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to mill the window pre-rig, a single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and lands in Ivishak 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 completion will completely isolate and abandon the parent Sag 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 K-12C Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 8,708’ MD at 180 degrees ROHS 3. Fullbore : MIT-IA to 2500 psi 4. Coil : Mill Window (if window not possible, mill with rig). See attached procedure. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in December 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,415 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not already milled pre-rig) 3. Drill build section: 4.25" OH, ~710' (17 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2379' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test 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. 9. Close in tree, RDMO. 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 (~800’) and RPM. See attached procedure. 4. Testing : Portable test separator flowback. Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (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 (8708' MD -8,462' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,312 psi 4,312 psi 9.8 B -522 psi 0 psi 0.09 C 3,784 psi 3,784 psi 8.6 B+C Mud + ECD Combined 4,307 psi 3,784 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 6 psi 528 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,295 psi at 8,800 TVD. (7.2 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,415 psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4” screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 4.25" hole for the entirety of the production hole section. Liner Program: 3-1/2", 9.3#, 13Cr /Solid: 8,460' MD – 8,690' MD (230' liner) 3-1/4", 6.6#, 13Cr /Solid: 8,690' MD – 9,200' MD (510' liner) 2-7/8", 6.5#, 13Cr /Solid: 9,200' MD – 11,797' MD (2,597' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8” x 3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. 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 96°. Inclination at kick off point is 20°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – 13,635 ft Distance to nearest well within pool – 810 ft Logging: MWD directional, Gamma Ray and Resistivity will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: 800' perforated post rig – See attached extended perforating procedure. 2.0" 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 Prudhoe pool. Formations: Top of Pool at 8,673’ MD in the parent Anti-Collision Failures: Anti-Collision Summary – All wells pass AC for WP03 Hazards: K Pad is not a H2S pad. The last H2S reading on K-12C: 30 ppm on 7/14/2021. Max H2S recorded on DS/Pad: 30 ppm (K-12C in 2021). 1 fault crossings expected. Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Pre-Rig – Service Coil – Window Milling The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire window milling operation. Notes for window milling: The AOGCC will set a 60 day limit from the time the window is milled until CTD begins drilling. Before the 60 day limit is exceeded, an application for either Suspension or Operations Shut-down is required and justification must be sent to the AOGCC and approval granted. Window milling with service CTU operations will fully comply with 20 AAC 25.286(d)(3), including the use of pressure control equipment, all BHAs fully lubricated and at no point will any BHA be open-hole deployed. Window Milling Procedure: 1. Kill well with 1% KCL if necessary. Well may already be killed from previous operations. 2. MU and RIH with window milling assembly – Window mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s window milling BHAs. 3. RIH & TAG whipstock pinch point, calculate distance till string reamer is out of the window, paint coil flag and note in WSR. 4. Mill window per vendor procedure. – Make note of any WHP changes while milling window in the WSR. 5. Make multiple reciprocating passes through the kickoff point to dress liner exit and eliminate all burs. Perform gel sweeps as necessary to keep window clean. Maximum approved distance to reciprocate beyond the window is 15 ft to ensure confidence the window is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire window with coil flag and note bottom of window and total milled depth in WSR. 7. FP well to 2,500’ TVD with 60/40 MeOH while POOH. 8. Once on surface inspect BHA, measure OD of mill and string reamer & document in WSR. 9. RDMO 10. Communicate to Operations to tag wing valve “Do Not POP”. Pre-Rig – Service Coil – Window Milling – BOP Diagram Post-Rig – Service Coil – Perforating Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Prudhoe pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Post Rig – Service Coil – Perforating – BOP Diagram Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip From:AOGCC Permitting (CED sponsored) To:Joseph Lastufka Cc:Torin Roschinger; Finn Oestgaard - (C); Trevor Hyatt; Rixse, Melvin G (OGC); Boman, Wade C (OGC) Subject:RE: [EXTERNAL] RE: PBU K-12D (PTD #224-099) 10-403 Sundry Request Date:Friday, November 22, 2024 2:25:19 PM Hello, This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Friday, November 22, 2024 8:59 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: RE: [EXTERNAL] RE: PBU K-12D (PTD #224-099) 10-403 Sundry Request All, I inadvertently left out the window mill pre-rig BOP Diagram in my hurry to submit last night. Please delete the submittal for PBU K-12D (PTD #224-099) submitted last night and replace with this updated version. I apologize for any inconvenience or confusion, please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Office: (907)777-8400, Cell:(907)227-8496 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Friday, November 22, 2024 7:53 AM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: [EXTERNAL] RE: PBU K-12D (PTD #224-099) 10-403 Sundry Request Hello, This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Thursday, November 21, 2024 7:51 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PBU K-12D (PTD #224-099) 10-403 Sundry Request Hello, Please see attached electronic distribution for PBU K-12D (PTD #224-099). Please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 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. 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Torin Roschinger To:Boman, Wade C (OGC); Rixse, Melvin G (OGC) Cc:Chmielowski, Jessie L C (OGC) Subject:RE: [EXTERNAL] PBU D-21 service coil window milling Date:Tuesday, November 19, 2024 3:02:55 PM Attachments:image001.jpg K-12D - PTD - Including Service Coil Window and Extended Perforating Update -11.19.2024.docx Wade, Please see my comments below in red to the AOGCC’s requests. With the AOGCC’s requests below, I’ve made a few minor updates to the proposed window milling and extended perforating PTD for K-12D. Please let me know if the AOGCC approves of this template and we will begin submitting future CTD PTDs accordingly. To respect the AOGCC’s time, I’m hoping to get a green light on the template before submitting official PTDs in case you would like to see something different. Also, Mel informed me that the AOGCC is reviewing Window Milling and Extended Perforating internally so I fully understand if your response on this isn’t back quickly. I appreciate you and Mel working with us on these. Thank you, Torin From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Friday, November 15, 2024 12:16 PM To: Torin Roschinger <torin.roschinger@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov> Subject: RE: [EXTERNAL] PBU D-21 service coil window milling Torin, AOGCC technical staff are in the process of reviewing Hilcorp’s request to use service coiled tubing units (service CTU) for the window milling operation for coiled tubing drilling (CTD) sidetracks that is currently performed with CTD rigs. A final set of stipulations is still being worked out (that will be very much like the below requirements), but please refer to the below requirements for the CTU PTDs that you are wanting to resubmit. AOGCC will consider service CTU window milling for CTD sidetracks on a case-by-case basis under the following conditions: 1. Approval of the window milling with service CTU operation will be part of the PTD approval and will be on a case-by-case basis. Whether or not window milling with service CTU is approved will be explicitly stated in the conditions of approval section of the PTD Form 10-401. In cases where milling with service coil is not allowed, window milling will be conducted by the coiled tubing drilling rig. Understood. 2. The service CTU window milling operation details must be submitted to the AOGCC as part of the application for a permit to drill (PTD) Form 10-401, via inclusion of Hilcorp’s supplied service coil window milling template. The milling itself will be considered as falling under the PTD, not an associated P&A sundry 10-403. Understood. I’ve provided the window milling and extended perforating templates in the attached K-12D PTD for reference. If the AOGCC would like to see a different format or have suggestions that will make reviewing these better or more efficient from the State’s perspective please let me know. 3. A 60-day limit will be in place following service coil milling a window until CTD drilling commences. If Hilcorp wants to extend this 60-day period, a sundry application must be submitted within 60 days after milling the window, for either Suspension or Operations Shut- down. Understood and agree. 4. Hilcorp must provide a process/method for tracking which wells have an open window milled by service coil and the day count since the milling took place. We have discussed this internally and have determined the best way to communicate that the window has been successfully milled by service coil to both the Drilling and Asset Teams is to document the date on which the window was milled and the date at which CTD must be rigged up on the drill well on the Drilling Schedule that is reviewed by both teams and leadership every Tuesday morning. This will put responsibility on the teams, but accountability on leadership to ensure compliance. These dates will then be reviewed weekly and will allow sufficient time for Hilcorp to communicate to the AOGCC should we need to submit either a Suspension or Operations Shut-down. 5. The window milling with service CTU operation will fully comply with 20 AAC 25.286(d)(3). The entire operation will be completed using pressure control equipment, all BHAs will be fully lubricated, and at no point will any BHA be open-hole deployed. Understood and agree. 6. The service CTU window milling operation is limited to a maximum of 15 feet of open hole. Hilcorp is to provide in the WSR exact details of the correct painting of the coil flag and the total milled depth. Understood and agree. Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Thursday, November 7, 2024 1:51 PM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] PBU D-21 service coil window milling Wade/Mel, I’ve included the window milling template similar to the extended milling template in the form of the 10-401 and 10-403 per your request. We tried to make it seamless within each document so hopefully it reads that way to each of you. Please let me know if you have any suggestions or changes. Thank you, Torin From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Tuesday, November 5, 2024 4:17 PM To: Torin Roschinger <torin.roschinger@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] PBU D-21 service coil window milling Torin, I just conferred with Mel on the service coil window milling. If you would, please write up a formal template, similar to the post-rig service coil extended peforating procedure page, for the milling of CTD windows via service coil. As we discussed on the phone, please make it read such that it would be a seamless addition to both 10-403s and 10-401s. Once you send it our way we’ll peruse it and then get back with you. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov CAUTION: 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. office: 907-793-1238 cell: 907-687-4468 From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Friday, November 1, 2024 1:32 PM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Subject: RE: [EXTERNAL] PBU D-21 service coil window milling Good afternoon Wade, I would like to include what is in the attached email on all CTD PTD and sundrys moving forward. However, I want to make sure that I’ve received Mel’s blessing first prior to making these changes. If approved, we plan to submit all future PTD’s and sundry this way understanding that the AOGCC may not approve all of them. In addition, we would likely want to submit a few changes to existing PTD and sundrys to include them in the service coil milling hopper. Please advise how you would like us to move forward. Thank you, Torin From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Friday, November 1, 2024 11:50 AM To: Trevor Hyatt <trevor.hyatt@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] PBU D-21 service coil window milling Trevor and Torin, I’m looking at the PTD for PBU D-21, and the fourth line of the pre-rig work section has service coil milling possibly milling the window: Are you wanting to officially include the template in the PTD as you did for PBU K-12C? I realize this process is a topic of current conversation and want to be clear on the plan for this sidetrack. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 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. 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. 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Joseph Lastufka To:Rixse, Melvin G (OGC) Cc:Boman, Wade C (OGC) Subject:RE: [EXTERNAL] RE: PBU K-12C (PTD #215-176) and K-12D (PTD #224-099) questions on completion of sundry work / abandonment Date:Sunday, November 3, 2024 10:46:11 AM Attachments:image001.png image002.png Thanks Mel! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, November 1, 2024 6:50 PM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: [EXTERNAL] RE: PBU K-12C (PTD #215-176) and K-12D (PTD #224-099) questions on completion of sundry work / abandonment Joe, My bad. I think you can do reporting as usual. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Wade From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Friday, November 1, 2024 12:19 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PBU K-12C (PTD #215-176) and K-12D (PTD #224-099) questions on completion of sundry work / abandonment Mel / Wade, Just happened to notice that the sundry lines for K-12C (PTD #215-176) 10-403 and K-12D (PTD #224-099) 10-401cutoff differ from the sundry / PTD: K-12C Sundry: K-12D Permit to Drill: I’m not sure if I should proceed as normal with the Abandon 10-407 submitted within 30 days of window mill (sundry) or after drilling to TD (PTD), or if there was just an error of where the line was placed. Happy to provide whatever is preferred, just confused me on a Friday. Please also note that the PTD # for K-12D (#224-099) is labeled as 224-009 in the PTD Rig Work section. Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 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. 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. 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-12D Hilcorp Alaska, LLC Permit to Drill Number: 224-099 Surface Location: 1695' FNL, 1110' FWL, Sec. 04, T11N, R14E, UM, AK Bottomhole Location: 2183' FSL, 1925' FEL, Sec. 04, 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, Jessie L. Chmielowski Commissioner DATED this 31st day of October 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.31 07:48:12 -06'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3.Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 11797' TVD: 8757' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 13635' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 57.46' 15.Distance to Nearest Well Open Surface: x-671372 y- 5975524 Zone- 4 23.76' to Same Pool:810' 16. Deviated wells: Kickoff depth: 8708 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 4-1/4"3-1/2"x3-1/4"9.3#/6.6# 13Cr80 STL/TCII 3337' 8460' 8213' 11797' 8757' x2-7/8" /6.5# /Hyd 511 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 36 - 116 35 - 2696 33 - 7895 7732 - 8417 8251 - 8549 8523 - 9011 Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email:trevor.hyatt@hilcorp.com Contact Phone:907-777-8396 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng PRUDHOE BAY, PRUDHOE OIL Monty Myers Drilling Manager Trevor Hyatt 2390' FSL, 735' FWL, Sec. 04, T11N, R14E, UM, AK December 1, 2024 Liner 315 4-1/2"348 cu ft Class G 8500 - 8815 8788 - 11456 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2661 8 cu yds Concrete 36 - 116 35 - 269613-3/8"1860 cu ft AS III, Top Job: 267 cu ft AS I Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 3-1/2" x 3-1/4" x 2-7/8" 33 - 8125 162 cu ft Class G 151 sx Class G Liner Liner 8092 724 2668 Intermediate Authorized Name: 8699 - 11438 Conductor/Structural 20"80 11456 9011 LengthCasing 8750, 10640 Cement Volume MDSize Plugs (measured): (including stage data) 181 sx Class G 8750 8487 2560 18. Casing Program: Top - Setting Depth - BottomSpecifications 3295 Total Depth MD (ft): Total Depth TVD (ft): 107205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2415 2183' FSL, 1925' FEL, Sec. 04, T11N, R14E, UM, AK 95-001 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 1695' FNL, 1110' FWL, Sec. 04, T11N, R14E, UM, AK ADL 028303 PBU K-12D Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 8439 - 9009 1154 cu ft Class G, 300 cu ft AS I 7952 - 86767" 9-5/8" Noo Noo Noo shales: Noooo Noooo Nooo Nooooo Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Drilling Manager 07/15/24 Monty M Myers By Grace Christianson at 11:42 am, Jul 15, 2024 MGR15AUG2024 * Pipe rams required to fit pipe body OD for jointed pipe work strings if utilized. * Post rig perforating BHAs not to exceed 500' in length. WCB 8-1-2024 DSR-7/15/24 224-099 50-029-21759-04-00 96 Variance to 20 AAC 25.112(I). Approved for alternate plug placement with fully cemented production liner. A.Dewhurst 25OCT24 *BOPE test to 3500 psi. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.31 07:48:22 -06'00' *&:03 10/31/24 10/31/24 RBDMS JSB 110124 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: July 15, 2024 Re:K-12D Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well K-12C with the Nabors CDR2 or CDR3 rig. Proposed plan for K-12D Producer: See K-12C Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to mill the window pre-rig, a single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and lands in Ivishak 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 completion will completely isolate and abandon the parent Sag 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 K-12C Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 8,708’ MD at 180 degrees ROHS 3. Fullbore : MIT-IA to 2500 psi 4. Coil : Mill Window (if window not possible, mill with rig). Give AOGCC 24hr notice prior to BOPE test. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,415 psi. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in December 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,415 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not already milled pre-rig) 3. Drill build section: 4.25" OH, ~710' (17 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2379' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test 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. 9. Close in tree, RDMO. 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 (~800’) and RPM. 4. Testing : Portable test separator flowback. Sundry 324-404 PTD 224-009 Nabors CDR2 orpp CDR3 rig. 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 (8708' MD -8,462' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,312 psi 4,312 psi 9.8 B - ECD 522 psi 0 psi 0.09 C 3,784 psi 3,784 psi 8.6 B+C Mud + ECD Combined 4,307 psi 3,784 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 6 psi 528 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,295 psi at 8,800 TVD. (7.2 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,415 psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4” screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 4.25" hole for the entirety of the production hole section. Liner Program: 3-1/2", 9.3#, 13Cr /Solid: 8,460' MD – 8,690' MD (230' liner) 3-1/4", 6.6#, 13Cr /Solid: 8,690' MD – 9,200' MD (510' liner) 2-7/8", 6.5#, 13Cr /Solid: 9,200' MD – 11,797' MD (2,597' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8” x 3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. 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 96°. Inclination at kick off point is 20°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – 13,635 ft Distance to nearest well within pool – 810 ft Logging: MWD directional, Gamma Ray and Resistivity will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: 800' perforated post rig – See attached extended perforating procedure. 2.0" 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. Formations: Top of pool at 8,673’ MD in the parent Anti-Collision Failures: Anti-Collision Summary – All wells pass AC for WP03 Hazards: K Pad is not a H2S pad. The last H2S reading on K-12C: 30 ppm on 7/14/2021. Max H2S recorded on DS/Pad: 30 ppm (K-12C in 2021). 1 fault crossings expected. Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram 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 Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip 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 OIL 224-099 PBU K-12D PRUDHOE BAY WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT K-12DInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240990PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesADL0283032Lease number appropriateYes3Unique well name and numberYesPRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NAThis well is a CTD sidetrack from an existing wellbore with pressure integrity.18Conductor string providedNAAll drilling on this sidetrack will be below the existing SC shoe.19Surface casing protects all known USDWsNAThis well is a CTD sidetrack from an existing wellbore with pressure integrity.20CMT vol adequate to circulate on conductor & surf csgNAThis well is a CTD sidetrack from an existing wellbore with pressure integrity.21CMT vol adequate to tie-in long string to surf csgYesFully cemented production liner. Parent well isolates the reservoir.22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesCDR2 and CDR3 have adequate tankage and good trucking support.24Adequate tankage or reserve pitYesSundry 324-40425If a re-drill, has a 10-403 for abandonment been approvedYesNo separation factors less than 1.26Adequate wellbore separation proposedNAAll drilling will be below the SC shoe.27If diverter required, does it meet regulationsYesMPD but reservoir press of 7.2 ppg equivalent is below water gradient of 8.33 ppg.28Drilling fluid program schematic & equip list adequateYesCT packoff, flow cross, annular, blind/shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29BOPEs, do they meet regulationYes7-1/16" 5000 psi stack pressure tested to 3500 psi.30BOPE press rating appropriate; test to (put psig in comments)YesFlanged choke and kill lines between dual combis w/remote choke.31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNoPrudhoe's K-Pad is not an "H2S pad."33Is presence of H2S gas probableNAThis is a development well.34Mechanical condition of wells within AOR verified (For service well only)NoK-Pad wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYesExpected reservoir pressure is 7.2 ppg EMW. MPD will be utilized.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate10/25/2024ApprWCBDate9/9/2024ApprADDDate10/25/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/31/2024