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Home My WebLink About223-093CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Joseph Lastufka To:AOGCC Permitting (CED sponsored) Cc:Rixse, Melvin G (OGC); Guhl, Meredith D (OGC); Dewhurst, Andrew D (OGC); Ryan Lewis; Boman, Wade C (OGC); Roby, David S (OGC); Taylor Wellman Subject:RE: [EXTERNAL] RE: MPU F-17 Suspension Sundry (325-462): Question Date:Thursday, December 11, 2025 11:21:50 AM Hello, Per request of AOGCC, please cancel MPU F-17L1 Permit to Drill (PTD #223-093) approved 11/3/2023. 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 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Tuesday, August 19, 2025 11:39 AM To: Ryan Lewis <ryan.lewis@hilcorp.com>; Joseph Lastufka <joseph.lastufka@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL] RE: MPU F-17 Suspension Sundry (325-462): Question Ryan, Understood. It appears that you only made ~2’ of new hole. Then to keep the record simple and clear, I suggest that we not create a separate record for the attempted L1 lateral: cancel the L1 PTD (223-093 ) with our permitting email address record the activity of the kickoff attempt, stuck BHA, and future reservoir abandonment activity (this sundry) on the suspension 10-407 for this F-17 (197- 196) wellbore; no need to create a separate 10-407 for the L1 We will proceed with this sundry If you have any questions, let me know. Thanks, 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. Andy From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Tuesday, 19 August, 2025 09:37 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU F-17 Suspension Sundry (325-462): Question The plan is to Reservoir abandon F-17L1. We are not planning to make another attempt. Thanks, RL From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Friday, August 15, 2025 11:22 AM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] MPU F-17 Suspension Sundry (325-462): Question Ryan, I’m reviewing the MPU F-17 sundry for a reservoir plug and suspension and have a question for you. What are your intentions for the F-17L1 well? Are you planning on making another attempt in the near future (I couldn’t tell as there is no estimated date on this sundry)? I ask because the PTD 223-093 was classified as a L1 “lateral” because the parent wellbore hadn’t been plugged. After the proposed work in this sundry, that will change. If you drill the L1 well, it won’t actually be a lateral anymore, it would be a normal “redrill”. That would necessitate a different API number and likely name change (to F-17A or such). If this is the plan, then we will need to do a series of changes which I can explain later. If you want to suspend the well only and do not plan on redrilling it soon, then we can proceed with the sundry. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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 theonward 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 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 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 01/17/24 Monty M Myers Hilcorp Alaska, LLC By Grace Christianson at 12:55 pm, Jan 17, 2024 RBDMS JSB 012324 DSR-1/26/24WCB 7-2-2024 _____________________________________________________________________________________ Created By: JNL 1/16/2024 Operations Shutdown Milne Point Unit Well: MPU F-17 / F-17L1 Last Completed: 12/30/2023 PTD: 197-196 / 223-093 OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset (Approx.) 12-1/4" 2650 sx PF E, 110 sx Class G, 160 sx PF E 7-5/8” 170 sx Class G, 185 sx Class G CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 7" Production 26 / L-80 / BTC-Mod 6.151 Surface 21,749’ TUBING DETAIL 4-1/2” Killstring 12.6 / L-80 / IBT Surface 9,119’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status F-17: Kuparuk 20,950’ 21,020’ 7,668’ 7,678’ 70’ 3-3/8” Closed F-17: Kuparuk 21,080’ 21,540’ 7,685’ 7,717’ 460’ 3-3/8” Closed TD =21,781’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.6/ GL Elev.: 12.7’ 7” 5 4 1 9-5/8” 2 3 4-1/2” Killstring PBTD =20,884’(MD) / PBTD = 7,657’(TVD) L1PBTD =20,919’(MD) /L1 PBTD =7,663’(TVD) L1 TD = 20,919’ (MD) / L1TD = 7,663’ (TVD) TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tbg hgr, 4.5” NSCT top & btm CIW 4” H BPV profile JEWELRY DETAIL No Depth Item 1 20,528’ Fish: Tricone Bit, Motor, MWD, GR, 4” Drillpipe 2 20,884’ Whipstock 3 20,906’ CIBP 4 20,911’ Whipstock 5 20,925’ CIBP WELL INCLINATION DETAIL KOP @ 744’ / L1 KOP @ 20,884’ Max Hole Angle = 80 deg @ 7900’, +70 deg 4,000 – 20,000, +80 from 20,000 to TD GENERAL WELL INFO API: 50-029-22823-00-00 / L1: 50-029-22823-60-00 Drilled, Cased & Completed: 8/1/2000 L1: Doyon 14 Operations Shutdown 12/28/2023 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:Doug Yessak - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Nathan Sperry; Alaska NS - Doyon 14 - DSMs Subject:Doyon 14 BOP 12-29-2023 Date:Friday, December 29, 2023 10:37:00 AM Attachments:Doyon 14 BOP_ MPU F-17_12-29-23.xlsx Doug Yessak Hilcorp DSM Doyon 14 907-670-3090 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. 0LOQH3RLQW8QLW)/ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:14 DATE: 12/29/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2230930 Sundry # Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Other: Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1900 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.P Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 N/A NA Trip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2-7/8"X5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 3-1/8" X 5000 P Time/Pressure Test Result HCR Valves 2 3-1/8" X 5000 P System Pressure (psi)3000 P Kill Line Valves 2 3-1/8" X 5000 P Pressure After Closure (psi)1650 P Check Valve 0NA200 psi Attained (sec)47 P BOP Misc 0NAFull Pressure Attained (sec)193 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1983psi P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 16 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:6.0 HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/25/23 17:45 Waived By Test Start Date/Time:12/28/2023 22:30 (date) (time)Witness Test Finish Date/Time:12/29/2023 4:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Doyon Test Annular with 4" test joint to 250/2500 psi. All other tests performed to 250/4000 psi. Test lower & upper rams w/ 4" & 4-1/2" test joints. Test H2S and LEL gas alarms. Test PVT- gain/ loss and flow paddle. All test performed against test plug. O. Williams / N. Hamilton Hilcorp D. Yessak / I. Toomey MPU F-17L1 Test Pressure (psi): rig14@doyondrilling.com skaNS-Doyon14-DSMs@hilcorp.c Form 10-424 (Revised 08/2022)2023-1229_BOP_Doyon14_MPU_F-17L1 9 9 999 9 9 9 9 9 9 -5HJJ Drilling Manager 12/28/23 Monty M Myers 323-686 By Grace Christianson at 1:31 pm, Dec 28, 2023 A.Dewhurst 29DEC23 MGR18DEC23 * Approved for temporary shutdown of up to 1 year. Operations must continue within 12 months from approved 10-403 or initiate abandonment. 10-404 *&:JLC 12/29/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.29 09:50:22 -09'00' RBDMS JSB 010324 To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry Drilling Engineer Date: December 28, 2023 Re: MPU F-17L1 Operations Shutdown Sundry Request Sundry approval is requested for Operations Shutdown Doyon 14 milled a window in the Kuparuk B with the top of the window at 20,884’ MD. A motor BHA got stuck in the window on December 17th, 2023. Despite multiple days of fishing and jarring, the BHA remains stuck in the window. The fish consists of a tricone bit, motor, MWD, GR, 4” HWDP, and 4” DP. The top of the fish is at 20,528’ MD. The proposed plan forward is to perform a BOP test, trip in with drillpipe to swap the well over to seawater, pull out laying down drillpipe, run a killstring to 4,500’ TVD, freeze protect across the permafrost, and RDMO to MPU F-34L1. Hilcorp will evaluate additional fishing opportunities to develop a plan forward to fish the BHA out of the window. The tentative return date is 3Q 2024. Nate Sperry Drilling Engineer Hilcorp Alaska, LLC _____________________________________________________________________________________ Created By: JNL 12/28/2023 Operations Shutdown Milne Point Unit Well: MPU F-17 / F-17L1 Last Completed: 8/1/2000 PTD: 197-196 / 223-093 OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset (Approx.) 12-1/4" 2650 sx PF E, 110 sx Class G, 160 sx PF E 7-5/8” 170 sx Class G, 185 sx Class G CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 9,544’ 7" Production 26 / L-80 / BTC-Mod 6.151 Surface 21,749’ TUBING DETAIL 4-1/2” Killstring Surface ~9,100’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status F-17: Kuparuk 20,950’ 21,020’ 7,668’ 7,678’ 70’ 3-3/8” Closed F-17: Kuparuk 21,080’ 21,540’ 7,685’ 7,717’ 460’ 3-3/8” Closed TD =21,780’ (MD) / TD = 7,734’(TVD) 20” Orig. KB Elev.: 45.6/ GL Elev.: 12.7’ 7” 5 4 1 9-5/8” 2 3 4-1/2” Killstring PBTD =20,884’(MD) / PBTD = 7,657’(TVD) L1PBTD =20,919’(MD) /L1 PBTD =7,663’(TVD) L1 TD = 20,919’ (MD) / L1TD = 7,663’ (TVD) TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” x 4-1/16” 5M FMC Gen 5 FMC Tbg hgr, 4.5” NSCT top & btm CIW 4” H BPV profile JEWELRY DETAIL No Depth Item 1 20,528’ Fish: Tricone Bit, Motor, MWD, GR, 4” Drillpipe 2 20,884’ Whipstock 3 20,906’ CIBP 4 20,911’ Whipstock 5 20,925’ CIBP WELL INCLINATION DETAIL KOP @ 744’ / L1 KOP @ 20,884’ Max Hole Angle = 80 deg @ 7900’, +70 deg 4,000 – 20,000, +80 from 20,000 to TD GENERAL WELL INFO API: 50-029-22823-00-00 / L1: 50-029-22823-60-00 Drilled, Cased & Completed: 8/1/2000 L1: Doyon 14 Operations Shutdown 12/28/2023 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: Milne Point Unit, Undefined Oil, MPU F-17L1 Hilcorp Alaska, LLC Permit to Drill Number: 223-093 Surface Location: 1808' FSL, 2731' FEL, Sec. 06, T13N, R10E, UM, AK Bottomhole Location: 2570' FNL, 1562' FEL, Sec. 08, T14N, R10E, 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 ___ day of November 2023. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.03 12:46:05 -08'00' 03 Drilling Manager 10/05/23 Monty M Myers By Grace Christianson at 4:09 pm, Oct 05, 2023 223-093 * Injection not authorized until the Area Injection Order (future AIO 10C) has been issued with expanded affected area. -A.Dewhurst 03 NOV 23 A.Dewhurst 03NOV23 DSR-10/5/23MGR11OCT2023 and MILNE POINT, UNDEFINED OIL (until the MP, Kuparuk River Oil Pool is expanded) 50-029-22823-60-00 * BOPE test to 4000 psi. Annular to 2500 psi. * MIT-IA to 2500 psi. State to witness. * State witnessed MIT-IA to 2500 psi within 10 days of stabilized injection. *&: Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.03 12:46:29 -08'00' 11/03/23 11/03/23 Notes on map Area within purple cylinder is within ¼ mile of planned F-17A sidetrack Kick off point in Kuparuk reservoir PT D A P I W E L L S T A T U S To p o f K u p A ( M D ) To p o f K u p A ( T V D ) CB L T o p o f Ce m e n t (M D ) CB L T o p o f Ce m e n t (T V D ) K u p a r u k A s t a t u s Zo n a l I s o l a t i o n 19 7 - 1 9 6 5 0 - 0 2 9 - 2 2 8 2 3 - 0 0 - 0 0 M P U F - 1 7 K u p a r u k A I n j e c t o r 20 7 5 1 ' 7 6 3 4 ' < 1 8 , 6 2 5 ' < 7 , 1 3 1 ' O p e n TO C f r o m U S I T d a t e d 2 7 - J a n - 1 9 9 8 . T o p o f l o g g i n g i n t e r v a l 1 8 , 6 2 5 ' MD / 7 , 1 3 1 ' T V D . C I B P t o b e s e t i n m o t h e r b o r e . F - 1 7 A s i d e t r a c k t o b e co m p l e t e d i n s a m e K u p a r u k P o o l . Ar e a o f R e v i e w M P U F - 1 7 A Milne Point Unit (MPU) F-17L1 Application for Permit to Drill Version 2 October 5, 2023 Table of Contents 1.0 Well Summary ........................................................................................................................... 2 2.0 Management of Change Information ........................................................................................ 3 3.0 Tubular Program ....................................................................................................................... 4 4.0 Drill Pipe Information ............................................................................................................... 4 5.0 Internal Reporting Requirements ............................................................................................. 5 6.0 Wellbore Schematics .................................................................................................................. 6 7.0 Drilling / Completion Summary ................................................................................................ 9 8.0 Mandatory Regulatory Compliance / Notifications ................................................................ 10 9.0 R/U and Test BOPE ................................................................................................................. 12 10.0 Pull 4-1/2” Tubing, Mill Packer............................................................................................... 14 11.0 Mill 6-1/8” Window and Kick Off ........................................................................................... 15 12.0 Drill 6-1/8” Production Hole Section ....................................................................................... 18 13.0 Run 4-1/2” Liner ...................................................................................................................... 21 14.0 Run Upper Completion............................................................................................................ 24 15.0 RDMO ...................................................................................................................................... 28 16.0 Post-Rig Work ......................................................................................................................... 29 17.0 Doyon 14 BOP Schematic ........................................................................................................ 30 18.0 Wellhead Schematic ................................................................................................................. 31 19.0 Days Vs Depth .......................................................................................................................... 32 20.0 Formation Tops & Information............................................................................................... 33 21.0 Anticipated Drilling Hazards .................................................................................................. 34 22.0 Doyon 14 Layout ...................................................................................................................... 36 23.0 FIT Procedure .......................................................................................................................... 37 24.0 Doyon 14 Choke Manifold Schematic ..................................................................................... 38 25.0 Casing Design Information ...................................................................................................... 39 26.0 6-1/8” Hole Section MASP ....................................................................................................... 40 27.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 41 28.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 42 Page 2 Milne Point Unit F-17L1 Drilling Procedure 1.0 Well Summary Well MPU F-17L1 Pad Milne Point “F” Pad Planned Completion Type 4-1/2” Pre-Drilled Liner Target Reservoir(s) Kuparuk A Planned Well TD, MD / TVD 31,272’ MD / 8,139’ TVD PBTD, MD / TVD 31,272 MD / 8,139’ TVD Surface Location (Governmental) 1808' FSL, 2429' FWL, Sec 6, T13N, R10E, UM, AK Surface Location (NAD 27 – Zone 4) X=541,834 Y=6,035,260 Top of Productive Horizon (Governmental) 2236' FNL, 1317' FWL, Sec 20, T14N, R10E, UM, AK TPH Location (NAD 27) X=545,718, Y=6,052,356 BHL (Governmental) 2570' FNL, 1562' FEL, Sec 8, T14N, R10E, UM, AK BHL (NAD 27) X=548,021, Y=6,062,596 AFE Drilling Days 26 Days AFE Completion Days 5 Days Maximum Anticipated Pressure (Surface) 1,900 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2,666 psi (6.7ppg EMW) Work String 4” 14# S-135 XT-39 KB Elevation above MSL: 33.7 ft + 12.7 ft = 46.4 ft GL Elevation above MSL: 12.7 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit F-17L1 Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit F-17L1 Drilling Procedure 3.0 Tubular Program Hole Section OD (in) ID (in)Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) 6-1/8” 4-1/2” 3.92 3.795 4.714 13.5 L-80 H625 9,020 8,540 279 4.0 Drill Pipe Information Hole Section OD (in) ID (in)TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension** (k-lbs) Production 4” 3.34” 2.563”4.875”14 S-135 XT39 18,500 22,200* 446 **Assumes 1.0 friction factor pipe dope *Tension Rating Based on Premium Pipe All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit F-17L1 Drilling Procedure 5.0 Internal Reporting Requirements Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. Afternoon Updates x Submit a short operations update each work day to mmyers@hilcorp.com, nathan.sperry@hilcorp.com,jengel@hilcorp.com and joseph.lastufka@hilcorp.com Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. EHS Incident Reporting x Health and safety: Notify EHS field coordinator. x Environmental: Drilling Environmental coordinator x Notify Drlg Manager & Drlg Engineer x Submit Hilcorp Incident report to contacts above within 24 hrs Casing Tally x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com Casing and Cement report x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and joseph.lastufka@hilcorp.com Hilcorp Milne Point Contact List: Title Name Work Phone Email Drilling Manager Monty Myers 907.777.8431 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 jengel@hilcorp.com Drilling Engineer Nathan Sperry 907.777.8450 nathan.sperry@hilcorp.com Operations Engineer Taylor Wellman 907.777.8449 twellman@hilcorp.com Geologist Graham Emerson 907.564.5242 Graham.emerson@hilcorp.com Reservoir Engineer Alan Abel 907.564.5032 Alan.abel@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 kfleming@hilcorp.com Safety Manager Laura Green 907.777.8314 lagreen@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 Joseph.Lastufka@hilcorp.com Page 6 Milne Point Unit F-17L1 Drilling Procedure 6.0 Wellbore Schematics Page 7 Milne Point Unit F-17L1 Drilling Procedure Page 8 Milne Point Unit F-17L1 Drilling Procedure Page 9 Milne Point Unit F-17L1 Drilling Procedure 7.0 Drilling / Completion Summary MPU F-17L1 is a sidetrack injection well targeting the Kuparuk River Pool, located on Milne Point ‘F-pad’. The directional plan is a single string horizontal well with the kick off point at 20,907’ MD. Maximum hole angle is ~91 degrees. Drilling operations are expected to commence approximately November 15th, 2023, pending rig schedule. Production liner will be 4-1/2” 12.6# L-80 pre-drilled liner run to 31,246’ MD / 8,139’ TVD. There are no plans to pre-produce the well. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on “B” pad. General sequence of operations: 1. MIRU Doyon 14 2. N/U 13-5/8” x 5M BOPE and test 3. Pull tubing from cut 4. Mill Baker S3 packer and push to bottom 5. Run 7” CIBP and set same. 6. Set 7” WS and mill 6-1/8” window 7. Drill with kickoff (motor) assembly until sufficient separation achieved 8. Drill 6-1/8” hole with RSS to TD 9. Run 4-1/2” production liner 10. Run 4-1/2” production tubing 11. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Production Hole: No mud logging. LWD: GR/Res Page 10 Milne Point Unit F-17L1 Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that all drilling and completion operations comply with all applicable AOGCC regulations. Operations stated in this PTD application may be altered based on sound engineering judgement as wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of approval are captured in shift handover notes until they are executed and complied with. x BOPs shall be tested at (1) week intervals prior to initiating window milling and (2) week intervals during the drilling and completion of MPU F-17L1. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/4,000 psi & subsequent tests of the BOP equipment will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial and subsequent tests).Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The results of this test and any subsequent tests of the casing must be recorded as required by 20 AAC 25.070(1)”. AOGCC Regulation Variance Requests: x None Page 11 Milne Point Unit F-17L1 Drilling Procedure Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 6-1/8” x 13-5/8” x 5M Hydril “GK” Annular BOP x 13-5/8” x 5M Hydril MPL Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Hydril MPL Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/4000 Subsequent Tests: 250/4000 Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 12 Milne Point Unit F-17L1 Drilling Procedure 9.0 R/U and Test BOPE This is an in-reservoir sidetrack. The existing perforations will be isolated via a CIBP. 9.1 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Ensure rig mats cover entire footprint of rig. 9.4 MIRU Doyon 14, Ensure rig is centered over the wellhead to prevent any wear to BOPE or wellhead. x Mud loggers will not be used on F-17L1. x A CMIT-TxIA to 2500 psi passed on 7/6/2023. 9.5 RU to pump down the tubing and take returns from the IA to a tank. Pump at least 1 truck of seawater followed by at least one soap sweep surface to surface per MI. x Estimated Kuparuk pore pressure is 6.7ppg. x The whipstock will be set at ~20,907’ MD. x Note that it is recommended to circ another BU after pulling the hanger to the floor to clear the annulus of any scale/debris. x Tubing volume to the cut depth is ~297 bbls x IA volume to the cut depth is ~450 bbls. 9.6 Install BPV. N/D the tree. Install test dart in the BPV. 9.7 N/U 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5” VBRs x N/U bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 9.8 Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Test 2-7/8” x 5” VBR’s with 4” and 4-1/2” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug Page 13 Milne Point Unit F-17L1 Drilling Procedure x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 9.9 R/D BOP test equipment. 9.10 Pull test dart and BPV. 9.11 Order out 8.6ppg fluid for production hole. 9.12 Ensure 5-1/2” or 5-3/4” liners in mud pumps (maximize available pump pressure). Page 14 Milne Point Unit F-17L1 Drilling Procedure 10.0 Pull 4-1/2” Tubing, Mill Packer x The tubing was cut at 19,517’ CT MD in July 2023. 10.1 PU landing joint or spear and recover the tubing hanger. x The hanger was installed in 1998. The hanger is an FMC 11” x 4-1/2” w/ a 19.5” pup below. 10.2 Back out lock down screws. 10.3 Pull tubing hanger with landing joint/XO to the floor. 10.4 The tubing is expected to be in good condition. 10.5 Note and record PU weight required to pull the tubing from cut. 10.6 The expected weight of the string in a vertical hole filled with seawater is 198 klbs (assumes 19,517’ cut depth). PU weight will be significantly less due to the deviation. 10.7 Recommend that at least 1X BU is circulated after pulling the hanger to the floor. If desired, circulate another soap sweep surface-to-surface to clean the tubing. 10.8 Pull and lay down the tubing from the cut. x Note: CT saw positive indication of a good cut. If the tubing cut was incomplete, an e-line conveyed cutter will need to be tractored into the well to make a second cut. 10.9 Run wear ring. 10.10 PU 4” drill pipe and RIH with packer milling assembly per Baker rep. x The primary plan is to burn over the packer and push it to bottom. 10.11 Mill packer following Baker Hughes procedure. 10.12 Chase packer down below 21,000’ MD. 10.13 When on bottom circulate at max rate a minimum of 1X BU or until returns are clean. Pump high vis sweep if necessary. 10.14 POOH with milling assembly. 10.15 PU 7” CIBP per Baker rep. RIH and set in the middle of joint below KOP and above top perf. Perform 10 min assurance test to 1,000 psi. POOH. Page 15 Milne Point Unit F-17L1 Drilling Procedure 11.0 Mill 6-1/8” Window and Kick Off x A USIT was run on January 27, 1998. The top of the logging interval was 18,600’ and the log shows cement from 18,600’ to TD with good bond across the planned KOP. 11.1 Whipstock Set Depth Information: x Planned TOW: ~20,907’ MD i. Collars are located at 20,944’ and 20,902’ and 20,860’ and 20,822’ (parent RKB reference) x WS will be set to avoid a collar based on the F-17 7” tally (Nabors 22E RKB of 33.05’). Note that the original paperwork reports a 12.7’ ground level and the 33.05’ RKB is from the rig floor to the base flange. x Doyon 14’s RKB on F-17L1 is 33.7’ (RKB to base flange) plus 12.7’ ground level for 46.4’. There is almost no shift required from the parent tally (33.05’ vs. 33.7’). x Drilling foreman, whipstock service hand, and drilling engineer to review parent tally and agree on the set depth. 11.2 MU 6-1/8” mill/whipstock assembly as per Baker Hughes tally x Make up HWDP, string magnets, and float sub x Ensure magnets are in trough, under shakers and flow area to capture metal shavings circulated 11.3 Install MWD and orient. Rack back mill assembly. x Ensure a dedicated MWD is available for orientation of the whipstock 11.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD and milling rep. Document and record offset in well file. 11.5 Slowly run in the hole as per fishing Rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bolt. 11.6 Run in hole at 1 ½ to 2 minutes per stand, or per Fishing Rep. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 11.7 Shallow test MWD 11.8 Stop at least 30-45’ above planned set depth and obtain survey with MWD. 11.9 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient whipstock face. Page 16 Milne Point Unit F-17L1 Drilling Procedure 11.10 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 0q ROHS. 11.11 Whipstock Orientation Diagram: Desired orientation of the whipstock face is 15L to 15R, target is 0 ROHS Hole Angle at window interval (20,900’ MD) is ~81°, Azimuth 10°. 11.12 Once whipstock is in desired orientation, set WS per fishing rep. 11.13 Pressure up per rep to set hydraulic set whipstock, (verify highlighted values with Baker rep) P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the whipstock shear bolt. (35klbs shear value, verify with Baker rep). 11.14 P/U 5-10’ above top of whipstock. 11.15 Displace to window milling fluid. CBU and confirm 8.6 ppg MW in/out x Ensure mud properties are sufficient for transporting metal cuttings x Milling fluid will be 8.6 ppg solids free mud 11.16 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high visc sweeps as necessary. 11.17 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 11.18 Clean catch trays and ditch magnets frequently while milling window. 11.19 Mill window until the uppermost mill has passed across the entire tray and 20’ of new hole has been milled. Dress and polish window as needed. 15R15L Page 17 Milne Point Unit F-17L1 Drilling Procedure 11.20 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 11.21 Circulate bottoms up until even MW in/out and hole is clean of metal shavings. 11.22 Pull back into 7” casing and perform FIT to 11.5 ppg EMW. Chart Test. x Note: A 9.0ppg FIT with 8.6ppg fluid density provides 115 bbl kick tolerance assuming 6.7ppg pore pressure (swabbed kick at 8.6ppg). 11.23 POOH & LD milling BHA. Gauge mills for wear. 11.24 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. Page 18 Milne Point Unit F-17L1 Drilling Procedure 12.0 Drill 6-1/8” Production Hole Section 12.1 PU 6-1/8” kickoff assembly. x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4” 14# S-135 XT 39 x Run x2 Solid Plunger Floats for MPD 12.2 6-1/8” hole mud program summary: x Density:The Kuparuk reservoir pressure is expected to be 6.7ppg. 8.6ppg MW will be used. x Solids Concentration:It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Inhibition:3% KCl will be used for inhibition. Watch MBT levels, dilute as necessary to maintain. Increase KCl % as needed x Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. x PVT will be used throughout the drilling phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type:8.6 - 9.8ppg FlowPro SF 3% KCl Inhibited Properties: Section Density Plastic Viscosity Yield Point Total Solids MBT pH 6-1/8” 8.6 - 9.8 ALAP 12-20 <5%< 7 9.0 - 9.5 12.3 TIH w/ 6-1/8” directional assembly on 4” DP to above window. Shallow test MWD and LWD on trip in. 12.4 Ensure even 8.6ppg MW in and out. Note: MPD is NOT needed for drilling with the motor assembly. 12.5 Drill 6-1/8” hole section with kickoff assembly at least until we have confirmed we have separation from the old wellbore. TOOH. Page 19 Milne Point Unit F-17L1 Drilling Procedure 12.6 P/U 6-1/8” RSS Directional BHA x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4” 14# S-135 XT 39 x Run x2 Solid Plunger Floats for MPD 12.7 Install MPD Element x Ensure rig crew is familiar with MPD connection operations 12.8 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 150-250 gpm (Target 200 ft/min AV) x RPM: 120 – 180 x WOB as needed x Target ECD and CBHP: As low as reasonably possible to minimize lost circulation x Take MWD surveys every stand drilled. x Kuparuk PP estimate is 6.7 ppg. Good drilling and tripping practices are vital for avoidance of differential sticking. x Watch for fluid losses while drilling through Kuparuk. 12.9 At TD, circulate a minimum of 2X BU x Circulate at full drill rate (150-250 gpm) while rotating at 120 rpm’s x We can slowly rack back a couple of stands while performing the BU circulations. 12.10 Backream to the window: x Circulate at max rate while minimizing drilling ECD’s x Perform CBHP connections x Rotate at maximum rpm that can be sustained. x Limit pulling speed to 5 – 10 min/std (slip to slip time, not including connections). x Continue backreaming to the window and circ at least 1X BU at the window. x Rack back DP while TOOH. Do not lay down drill pipe. This is to minimize open hole time before liner is on bottom. x Once inside casing, drop rabbit on remaining drillpipe on TOOH that will be used to run the 4.5” liner. Confirm diameter drift with Baker for setting liner hanger. 12.11 Circulate a minimum of 2X BU at 7” window and clean casing with high vis sweeps. 12.12 Monitor well for flow. Increase mud weight if necessary x Wellbore breathing has been seen on past MPU Kuparuk wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise x If necessary, increase MW at shoe for any higher than expected pressure seen Page 20 Milne Point Unit F-17L1 Drilling Procedure 12.13 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Page 21 Milne Point Unit F-17L1 Drilling Procedure 13.0 Run 4-1/2” Liner Plan to alternate 1 solid joint and 1 pre-drilled joint. 13.1 Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2” injection liner with pre-drilled liner, the following well control response procedure will be followed: x With a pre-drilled joint across the BOP: P/U & M/U the 4” safety joint (with 4-1/2” crossover installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2” liner. x With 4-1/2” solid joint across BOP: Slack off and position the 4-1/2” solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2” solid joint. Close TIW valve. 13.2 Set the test plug and flush the stack with the wash tool. Pull test plug. 13.3 Ensure rams have been tested on 4” and 4-1/2” test joints prior to running liner. 13.4 Ensure wear bushing is installed in wellhead. 13.5 R/U 4-1/2” casing running equipment. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 13.6 Run 4-1/2” liner per completion tally. x Dope pin end only w/ paint brush. x Utilize a collar clamp until weight is sufficient to keep slips set properly. 4-1/2” Tenaris Hydril 625 Make-Up Torques Casing OD Minimum Optimum Maximum 4.5”8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs 4-1/2” Tenaris Hydril 625 Operating Limit Torques Casing OD Operating Yield 4.5”12,800 ft-lbs 15,000 ft-lbs Page 22 Milne Point Unit F-17L1 Drilling Procedure Page 23 Milne Point Unit F-17L1 Drilling Procedure 13.7 Ensure to run enough liner to provide for approximately 150’ overlap inside 7” casing. Ensure hanger/pkr will not be set in a 7” connection. 13.8 Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 13.9 M/U Baker SLZXP liner top packer. 13.10 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 13.11 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 13.12 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the string to bottom. 13.13 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 13.14 RIH to TD. Monitor run for losses. 13.15 Follow Baker procedure to set SLZXP. 13.16 Unsting and CBU X2. 13.17 Swap well to KCl completion brine. Ensure the density matches the final mud weight used during the liner run. 13.18 Perform flowcheck. POOH LDDP. Page 24 Milne Point Unit F-17L1 Drilling Procedure 14.0 Run Upper Completion 14.1 Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). 14.2 M/U injection assembly and RIH to setting depth. TIH no faster than 90 ft/min. x Ensure wear bushing is pulled. x Ensure 4-½” JFE Bear x XT39 crossover is on rig floor and M/U to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. x Monitor displacement from wellbore while RIH. 4-1/2” JFE Bear Make-Up Torques Tbg OD Minimum Optimum Maximum 4.5”4,860 ft-lbs 5,400 ft-lbs 5,940 ft-lbs 4-1/2” JFE Bear Operating Limit Torques Tbg OD Operating 4.5”8,100 ft-lbs Page 25 Milne Point Unit F-17L1 Drilling Procedure 4-½” Upper Completion Running Order x 4-½” WLEG (spaced out inside the SLZXP) x 2 joints (minimum, more as needed) 4-½” 12.6#/ft, L-80 JFE Bear tubing x 4-1/2” Arsenal Glass Floatation Sub (Baseplan set to rupture at 4,000psi. Confirm w/ OE prior to make up) Page 26 Milne Point Unit F-17L1 Drilling Procedure x 1 joint 4-½” 12.6#/ft, L-80 JFE Bear tubing x 4-½” “XN” nipple (ID=3.705” No-Go) x 1 joint 4-½” 12.6#/ft, L-80 JFE Bear tubing x 7” x 4-1/2” Packer (Set at ±20,540’ MD) x 4-½” 12.6#/ft, L-80 JFE Bear tubing x 4-½” SGM-FS XDPG Gauge at TBD x 4-½” 12.6#/ft, L-80 JFE Bear tubing x 4-1/2” X Nipple (ID = 3.813”) @ ±2,200’ MD x 4-½” 12.6#/ft, L-80 JFE Bear tubing x 4-½” 12.6#/ft, L-80 JFE Bear space out pups x 1 joint 4-½” 12.6#/ft, L-80 JFE Bear tubing x Tubing hanger with 4-1/2” JFE Bear pin down 14.3 While running the upper completion, loading the tubing will be required as it will not auto fill due to the Arsenal Glass Floatation Sub. Fill w/ same weight completion fluid to avoid differential pressure. i. Contingency: Based on losses, it may be required to partially load tubing with diesel to avoid pre-mature rupture of the Floatation Sub. Contact OE to confirm calculations. 14.4 Locate and no-go out the seal assembly. Space out the completion (+/- 1’ to 2’ above No-Go). Place all space out pups below the first full joint of the completion. 14.5 Makeup the tubing hanger and landing joint. 14.6 Bullhead down the 4-1/2”x7” annulus to the formation with brine and 1% corrosion inhibitor. 14.7 Freeze protect the IA to ~2,500’ MD with ±96 bbl of diesel. 14.8 Land hanger. RILDs and test hanger. 14.9 Pressure up on the tubing to initiate setting the packer as per the Packer Rep. Perform MIT-T to 3,000 psi (charted for 30 mintues). 14.10 Bleed tubing down to 1,000 psi and perform an MIT-IA to 2,500 psi and test for 30 charted minutes. i. Note this test must be witnessed by the AOGCC representative. 14.11 Bleed down IA and pressure up the tubing to burst the Glass Floatation Sub at 4,000psi. Once burst, confirm by pumping ±5bbls down to the formation. Page 27 Milne Point Unit F-17L1 Drilling Procedure 14.12 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and tree. 14.13 Pull BPV. Set TWC. Test tree to 5000 psi. 14.14 Pull TWC. Set BPV. Bullhead tubing freeze protect. 14.15 Secure the tree and cellar. Page 28 Milne Point Unit F-17L1 Drilling Procedure 15.0 RDMO 15.1 RDMO Doyon 14. Page 29 Milne Point Unit F-17L1 Drilling Procedure 16.0 Post-Rig Work 16.1 Pull BPV. Bullhead tubing freeze protect if/as needed. 16.2 RU SL and set MCX valve @ ±2,200’ MD. 16.3 RD SL unit. Page 30 Milne Point Unit F-17L1 Drilling Procedure 17.0 Doyon 14 BOP Schematic Typical Ram Configuration Page 31 Milne Point Unit F-17L1 Drilling Procedure 18.0 Wellhead Schematic FMC Gen 5 Typical 2-7/8” Page 32 Milne Point Unit F-17L1 Drilling Procedure 19.0 Days Vs Depth Page 33 Milne Point Unit F-17L1 Drilling Procedure 20.0 Formation Tops & Information Formation TVD TVDss MD EMW (PPG) Top A3 7662.2 -7615.8 20911.5 6.7 Top A2 7685.9 -7639.5 21109.2 6.7 Top A1 7713.2 -7666.8 21397.6 6.7 MPU F-Pad Data Sheet Page 34 Milne Point Unit F-17L1 Drilling Procedure 21.0 Anticipated Drilling Hazards Window Exit: Tracking Casing The KOP is cemented. The motor run will help us ensure departure from the parent bore prior to drilling ahead with a rotary steerable system. Production Hole Sections: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of 200 ft/min. Lost Circulation: Monitor ECD’s during production section to ensure ECD’s stay below 12.5ppg (target as low as possible). Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. The Kuparuk FG is predicted to be ~12.6ppg. Wellbore Stability: This is an in-zone sidetrack. Wellbore instability is viewed as a low risk. Maintain sufficient MW for stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles. Use MPD to offset swab effect while TOOH. Anti-Collision: This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic interference while drilling ahead. Faulting: There are no mapped faults in the production interval. H2S: Treat every hole section as though it has the potential for H2S. H2S events have typically been minor from F-pad Kuparuk wells. The vast majority of sample data is less than 10 ppm. F-69 recorded a sample with 47 ppm. F-53 had one sample test come back with 32 ppm. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Page 35 Milne Point Unit F-17L1 Drilling Procedure 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 36 Milne Point Unit F-17L1 Drilling Procedure 22.0 Doyon 14 Layout Page 37 Milne Point Unit F-17L1 Drilling Procedure 23.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 38 Milne Point Unit F-17L1 Drilling Procedure 24.0 Doyon 14 Choke Manifold Schematic Page 39 Milne Point Unit F-17L1 Drilling Procedure 25.0 Casing Design Information Page 40 Milne Point Unit F-17L1 Drilling Procedure 26.0 6-1/8” Hole Section MASP Page 41 Milne Point Unit F-17L1 Drilling Procedure 27.0 Spider Plot (NAD 27) (Governmental Sections) Page 42 Milne Point Unit F-17L1 Drilling Procedure 28.0 Surface Plat (As Built) (NAD 27) 6WDQGDUG3URSRVDO5HSRUW 2FWREHU 3ODQ038)/ZS +LOFRUS$ODVND//& 0LOQH3RLQW 03W)3DG 3ODQ03) 3ODQ038)/ 56 0 0 64 0 0 72 0 0 80 0 0 88 0 0 True Vertical Depth (1200 usft/in) 17 6 0 0 1 8 4 0 0 1 9 2 0 0 2 0 0 0 0 2 0 8 0 0 2 1 6 0 0 2 2 4 0 0 2 3 2 0 0 2 4 0 0 0 2 4 8 0 0 25 6 0 0 26 4 0 0 2 7 2 0 0 2 8 0 0 0 2 8 8 0 0 Ve r t i c a l S e c t i o n a t 1 3 . 8 0 ° ( 1 2 0 0 u s f t / i n ) MP F - 1 7 A w p 0 4 c p 1 MP F - 1 7 A w p 0 4 c p 2 MP F - 1 7 A w p 0 4 c p 3 MP F - 1 7 A w p 0 4 c p 4 MP F - 1 7 A w p 0 5 c p 5 MP F - 1 7 A w p 0 5 c p 6 MP F - 1 7 A w p 0 5 c p 7 MP F - 1 7 A w p 0 5 c p 8 MP F - 1 7 A w p 0 5 c p 9 MP F - 1 7 A w p 0 5 t o e MP U F - 1 7 A w p 1 0 t g t 1 MP U F - 1 7 A w p 1 0 t g t 2 20500 21000 21500 21780 MP F - 1 7 7" T O W 4 1 / 2 " x 6 " 21000 21500 22000 22500 23000 23500 24000 24500 25000 25500 26000 26500 27000 27500 28000 28500 29000 29500 30000 30500 31000 31272 MP U F - 1 7 L 1 w p 1 1 St a r t D i r 1 2 º / 1 0 0 ' : 2 0 9 0 0 ' M D , 7 6 6 0 . 4 8 ' T V D : 0 ° R T T F En d D i r : 2 0 9 1 7 ' M D , 7 6 6 2 . 9 5 ' T V D St a r t D i r 4 . 7 5 º / 1 0 0 ' : 2 0 9 4 7 ' M D , 7 6 6 6 . 7 8 ' T V D En d D i r : 2 1 2 4 7 . 5 8 ' M D , 7 6 9 9 . 7 1 ' T V D St a r t D i r 4 . 7 5 º / 1 0 0 ' : 2 1 5 1 9 . 0 8 ' M D , 7 7 2 4 . 2 2 ' T V D En d D i r : 2 1 7 8 8 . 3 2 ' M D , 7 7 4 3 . 5 7 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 2 0 8 8 . 3 2 ' M D , 7 7 5 9 . 4 3 ' T V D En d D i r : 2 2 1 6 0 . 0 2 ' M D , 7 7 6 1 . 4 3 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 2 9 4 5 . 9 ' M D , 7 7 6 3 . 6 5 ' T V D En d D i r : 2 3 0 2 9 . 7 1 ' M D , 7 7 6 6 . 3 3 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 3 1 2 9 . 7 1 ' M D , 7 7 7 2 . 4 3 ' T V D En d D i r : 2 3 2 5 4 . 6 1 ' M D , 7 7 8 5 . 4 7 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 3 4 0 0 . 6 2 ' M D , 7 8 0 7 . 0 4 ' T V D En d D i r : 2 3 5 9 5 . 9 3 ' M D , 7 8 2 5 . 7 5 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 3 9 1 0 . 9 2 ' M D , 7 8 3 9 . 4 9 ' T V D En d D i r : 2 4 0 1 9 . 3 4 ' M D , 7 8 4 0 . 1 4 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 4 3 5 0 . 1 6 ' M D , 7 8 2 9 . 6 7 ' T V D En d D i r : 2 4 4 6 9 . 2 4 ' M D , 7 8 3 0 . 3 8 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 4 5 6 9 . 2 4 ' M D , 7 8 3 4 . 7 4 ' T V D En d D i r : 2 4 6 9 6 . 5 3 ' M D , 7 8 4 2 . 9 9 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 5 3 0 3 . 5 9 ' M D , 7 8 9 5 . 1 2 ' T V D En d D i r : 2 5 4 2 7 . 1 3 ' M D , 7 9 0 0 . 4 3 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 5 6 7 7 . 1 3 ' M D , 7 9 0 0 . 4 3 ' T V D En d D i r : 2 5 8 4 0 . 3 ' M D , 7 9 0 6 . 9 ' T V D St a r t D i r 4 º / 1 0 0 ' : 2 6 0 8 9 . 7 3 ' M D , 7 9 2 6 . 6 7 ' T V D En d D i r : 2 6 1 2 6 . 3 8 ' M D , 7 9 3 0 . 0 4 ' T V D St a r t D i r 1 º / 1 0 0 ' : 2 6 4 2 6 . 3 8 ' M D , 7 9 6 1 . 4 ' T V D En d D i r : 2 6 8 8 7 . 0 1 ' M D , 7 9 9 2 . 5 2 ' T V D St a r t D i r 1 º / 1 0 0 ' : 2 8 3 2 5 . 1 2 ' M D , 8 0 3 6 . 4 3 ' T V D En d D i r : 2 8 6 9 5 . 9 8 ' M D , 8 0 5 0 . 3 7 ' T V D St a r t D i r 1 º / 1 0 0 ' : 2 9 3 2 4 . 5 3 ' M D , 8 0 7 8 . 4 3 ' T V D En d D i r : 2 9 4 2 9 . 0 3 ' M D , 8 0 8 2 . 3 8 ' T V D WE L L D E T A I L S : P l a n : M P F - 1 7 N A D 1 9 2 7 ( N A D C O N C O N U S ) A l a s k a Z o n e 0 4 Gr o u n d L e v e l : 12 . 7 0 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0 . 0 0 6 0 3 5 2 6 0 . 3 8 5 4 1 8 3 3 . 6 1 70 ° 3 0 ' 2 6 . 0 9 7 1 N 14 9 ° 3 9 ' 2 7 . 8 5 1 5 W CA S I N G D E T A I L S TV D TV D S S MD S i z e Na m e 76 6 0 . 6 4 7 6 1 4 . 2 4 2 0 9 0 1 . 0 0 7 7 " T O W 81 3 9 . 4 3 8 0 9 3 . 0 3 3 1 2 7 2 . 2 5 4- 1 / 2 4 1 / 2 " x 6 " Pr o j e c t : M i l n e P o i n t Si t e : M P t F P a d We l l : P l a n : M P F - 1 7 We l l b o r e : P l a n : M P U F - 1 7 L 1 De s i g n : M P U F - 1 7 L 1 w p 1 1 SE C T I O N D E T A I L S 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 T a r g e t A n n o t a t i o n 1 2 0 9 0 0 . 0 0 8 0 . 6 3 9 . 8 6 7 6 6 0 . 4 8 1 7 2 5 6 . 6 6 4 0 1 2 . 3 4 0 . 0 0 0 . 0 0 1 7 7 1 5 . 6 2 S t a r t D i r 1 2 º / 1 0 0 ' : 2 0 9 0 0 ' M D , 7 6 6 0 . 4 8 ' T V D : 0 ° R T T F 2 2 0 9 1 7 . 0 0 8 2 . 6 7 9 . 8 6 7 6 6 2 . 9 5 1 7 2 7 3 . 2 3 4 0 1 5 . 2 2 1 2 . 0 0 0 . 0 0 1 7 7 3 2 . 3 9 E n d D i r : 2 0 9 1 7 ' M D , 7 6 6 2 . 9 5 ' T V D 3 2 0 9 4 7 . 0 0 8 2 . 6 7 9 . 8 6 7 6 6 6 . 7 8 1 7 3 0 2 . 5 5 4 0 2 0 . 3 2 0 . 0 0 0 . 0 0 1 7 7 6 2 . 0 8 S t a r t D i r 4 . 7 5 º / 1 0 0 ' : 2 0 9 4 7 ' M D , 7 6 6 6 . 7 8 ' T V D 4 2 1 2 4 7 . 5 8 8 4 . 8 2 3 5 5 . 6 6 7 6 9 9 . 7 1 1 7 6 0 0 . 1 9 4 0 3 4 . 5 9 4 . 7 5 - 8 2 . 1 4 1 8 0 5 4 . 5 4 E n d D i r : 2 1 2 4 7 . 5 8 ' M D , 7 6 9 9 . 7 1 ' T V D 5 2 1 5 1 9 . 0 8 8 4 . 8 2 3 5 5 . 6 6 7 7 2 4 . 2 2 1 7 8 6 9 . 8 2 4 0 1 4 . 1 3 0 . 0 0 0 . 0 0 1 8 3 1 1 . 4 9 S t a r t D i r 4 . 7 5 º / 1 0 0 ' : 2 1 5 1 9 . 0 8 ' M D , 7 7 2 4 . 2 2 ' T V D 6 2 1 7 8 8 . 3 2 8 6 . 9 7 8 . 3 0 7 7 4 3 . 5 7 1 8 1 3 7 . 6 3 4 0 2 3 . 4 3 4 . 7 5 8 0 . 8 1 1 8 5 7 3 . 8 0 E n d D i r : 2 1 7 8 8 . 3 2 ' M D , 7 7 4 3 . 5 7 ' T V D 7 2 2 0 8 8 . 3 2 8 6 . 9 7 8 . 3 0 7 7 5 9 . 4 3 1 8 4 3 4 . 0 8 4 0 6 6 . 6 7 0 . 0 0 0 . 0 0 1 8 8 7 2 . 0 0 M P F - 1 7 A w p 0 4 c p 1 S t a r t D i r 4 º / 1 0 0 ' : 2 2 0 8 8 . 3 2 ' M D , 7 7 5 9 . 4 3 ' T V D 8 2 2 1 6 0 . 0 2 8 9 . 8 4 8 . 2 9 7 7 6 1 . 4 3 1 8 5 0 4 . 9 9 4 0 7 7 . 0 1 4 . 0 0 - 0 . 2 0 1 8 9 4 3 . 3 4 E n d D i r : 2 2 1 6 0 . 0 2 ' M D , 7 7 6 1 . 4 3 ' T V D 9 2 2 9 4 5 . 9 0 8 9 . 8 4 8 . 2 9 7 7 6 3 . 6 5 1 9 2 8 2 . 6 6 4 1 9 0 . 3 3 0 . 0 0 0 . 0 0 1 9 7 2 5 . 5 8 S t a r t D i r 4 º / 1 0 0 ' : 2 2 9 4 5 . 9 ' M D , 7 7 6 3 . 6 5 ' T V D 10 2 3 0 2 9 . 7 1 8 6 . 5 0 8 . 6 0 7 7 6 6 . 3 3 1 9 3 6 5 . 5 0 4 2 0 2 . 6 3 4 . 0 0 1 7 4 . 7 1 1 9 8 0 8 . 9 7 E n d D i r : 2 3 0 2 9 . 7 1 ' M D , 7 7 6 6 . 3 3 ' T V D 11 2 3 1 2 9 . 7 1 8 6 . 5 0 8 . 6 0 7 7 7 2 . 4 3 1 9 4 6 4 . 1 9 4 2 1 7 . 5 5 0 . 0 0 0 . 0 0 1 9 9 0 8 . 3 7 M P F - 1 7 A w p 0 4 c p 2 S t a r t D i r 4 º / 1 0 0 ' : 2 3 1 2 9 . 7 1 ' M D , 7 77 2 . 4 3 ' T V D 12 2 3 2 5 4 . 6 1 8 1 . 5 1 8 . 7 9 7 7 8 5 . 4 7 1 9 5 8 6 . 9 5 4 2 3 6 . 3 3 4 . 0 0 1 7 7 . 8 2 2 0 0 3 2 . 0 6 E n d D i r : 2 3 2 5 4 . 6 1 ' M D , 7 7 8 5 . 4 7 ' T V D 13 2 3 4 0 0 . 6 2 8 1 . 5 1 8 . 7 9 7 8 0 7 . 0 4 1 9 7 2 9 . 6 5 4 2 5 8 . 4 0 0 . 0 0 0 . 0 0 2 0 1 7 5 . 9 2 S t a r t D i r 4 º / 1 0 0 ' : 2 3 4 0 0 . 6 2 ' M D , 7 8 0 7 . 0 4 ' T V D 14 2 3 5 9 5 . 9 3 8 7 . 5 0 1 3 . 8 3 7 8 2 5 . 7 5 1 9 9 2 0 . 1 3 4 2 9 6 . 5 4 4 . 0 0 4 0 . 2 0 2 0 3 6 9 . 9 9 E n d D i r : 2 3 5 9 5 . 9 3 ' M D , 7 8 2 5 . 7 5 ' T V D 15 2 3 6 1 0 . 9 3 8 7 . 5 0 1 3 . 8 3 7 8 2 6 . 4 0 1 9 9 3 4 . 6 8 4 3 0 0 . 1 3 0 . 0 0 0 . 0 0 2 0 3 8 4 . 9 8 M P U F - 1 7 A w p 1 0 t g t 1 16 2 3 9 1 0 . 9 2 8 7 . 5 0 1 3 . 8 3 7 8 3 9 . 4 9 2 0 2 2 5 . 7 1 4 3 7 1 . 7 7 0 . 0 0 0 . 0 0 2 0 6 8 4 . 6 9 S t a r t D i r 4 º / 1 0 0 ' : 2 3 9 1 0 . 9 2 ' M D , 7 8 3 9 . 4 9 ' T V D 17 2 4 0 1 9 . 3 4 9 1 . 8 1 1 3 . 3 8 7 8 4 0 . 1 4 2 0 3 3 1 . 0 6 4 3 9 7 . 2 6 4 . 0 0 - 5 . 9 9 2 0 7 9 3 . 0 8 E n d D i r : 2 4 0 1 9 . 3 4 ' M D , 7 8 4 0 . 1 4 ' T V D 18 2 4 3 5 0 . 1 6 9 1 . 8 1 1 3 . 3 8 7 8 2 9 . 6 7 2 0 6 5 2 . 7 3 4 4 7 3 . 7 7 0 . 0 0 0 . 0 0 2 1 1 2 3 . 7 2 S t a r t D i r 4 º / 1 0 0 ' : 2 4 3 5 0 . 1 6 ' M D , 7 8 2 9 . 6 7 ' T V D 19 2 4 4 6 9 . 2 4 8 7 . 5 0 1 5 . 4 0 7 8 3 0 . 3 8 2 0 7 6 8 . 0 5 4 5 0 3 . 3 5 4 . 0 0 1 5 4 . 8 8 2 1 2 4 2 . 7 6 E n d D i r : 2 44 6 9 . 2 4 ' M D , 7 8 3 0 . 3 8 ' T V D 20 2 4 5 6 9 . 2 4 8 7 . 5 0 1 5 . 4 0 7 8 3 4 . 7 4 2 0 8 6 4 . 3 6 4 5 2 9 . 8 8 0 . 0 0 0 . 0 0 2 1 3 4 2 . 6 3 S t a r t D i r 4 º / 1 0 0 ' : 2 4 5 6 9 . 2 4 ' M D , 7 8 3 4 . 7 4 ' T V D 2 1 2 4 6 9 6 . 5 3 8 5 . 0 7 1 9 . 8 9 7 8 4 2 . 9 9 2 0 9 8 5 . 3 7 4 5 6 8 . 3 6 4 . 0 0 1 1 8 . 5 9 2 1 4 6 9 . 3 2 E n d D i r : 2 4 6 9 6 . 5 3 ' M D , 7 8 4 2 . 9 9 ' T V D 22 2 5 3 0 3 . 5 9 8 5 . 0 7 1 9 . 8 9 7 8 9 5 . 1 2 2 1 5 5 4 . 1 3 4 7 7 4 . 0 9 0 . 0 0 0 . 0 0 2 2 0 7 0 . 7 3 S t a r t D i r 4 º / 1 0 0 ' : 2 5 3 0 3 . 5 9 ' M D , 7 8 9 5 . 1 2 ' T V D 23 2 5 4 2 7 . 1 3 9 0 . 0 0 1 9 . 5 0 7 9 0 0 . 4 3 2 1 6 7 0 . 2 9 4 8 1 5 . 6 7 4 . 0 0 - 4 . 4 9 2 2 1 9 3 . 4 6 E n d D i r : 2 5 4 2 7 . 1 3 ' M D , 7 9 0 0 . 4 3 ' T V D 24 2 5 6 7 7 . 1 3 9 0 . 0 0 1 9 . 5 0 7 9 0 0 . 4 3 2 1 9 0 5 . 9 5 4 8 9 9 . 1 2 0 . 0 0 0 . 0 0 2 2 4 4 2 . 2 3 M P F - 1 7 A w p 0 5 c p 5 S t a r t D i r 4 º / 1 0 0 ' : 2 5 6 7 7 . 1 3 ' M D , 7 9 0 0 . 4 3 ' T V D 25 2 5 8 4 0 . 3 0 8 5 . 4 5 1 4 . 8 1 7 9 0 6 . 9 0 2 2 0 6 1 . 6 5 4 9 4 7 . 1 9 4 . 0 0 - 1 3 4 . 2 1 2 2 6 0 4 . 9 0 E n d D i r : 2 5 8 4 0 . 3 ' M D , 7 9 0 6 . 9 ' T V D 26 2 6 0 8 9 . 7 3 8 5 . 4 5 1 4 . 8 1 7 9 2 6 . 6 7 2 2 3 0 2 . 0 4 5 0 1 0 . 7 6 0 . 0 0 0 . 0 0 2 2 8 5 3 . 5 1 S t a r t D i r 4 º / 1 0 0 ' : 2 6 0 8 9 . 7 3 ' M D , 7 9 2 6 . 6 7 ' T V D 27 2 6 1 2 6 . 3 8 8 4 . 0 0 1 5 . 0 0 7 9 3 0 . 0 4 2 2 3 3 7 . 3 1 5 0 2 0 . 1 5 4 . 0 0 1 7 2 . 6 6 2 2 8 9 0 . 0 0 E n d D i r : 2 61 2 6 . 3 8 ' M D , 7 9 3 0 . 0 4 ' T V D 28 2 6 4 2 6 . 3 8 8 4 . 0 0 1 5 . 0 0 7 9 6 1 . 4 0 2 2 6 2 5 . 5 0 5 0 9 7 . 3 7 0 . 0 0 0 . 0 0 2 3 1 8 8 . 2 9 M P U F - 1 7 A w p 1 0 t g t 2 S t a r t D i r 1 º / 1 0 0 ' : 2 6 4 2 6 . 3 8 ' M D , 7 9 6 1 . 4 ' T V D 29 2 6 8 8 7 . 0 1 8 8 . 2 5 1 6 . 7 8 7 9 9 2 . 5 2 2 3 0 6 7 . 3 9 5 2 2 3 . 1 8 1 . 0 0 2 2 . 7 4 2 3 6 4 7 . 4 3 E n d D i r : 26 8 8 7 . 0 1 ' M D , 7 9 9 2 . 5 2 ' T V D 30 2 8 3 2 5 . 1 2 8 8 . 2 5 1 6 . 7 8 8 0 3 6 . 4 3 2 4 4 4 3 . 6 2 5 6 3 8 . 1 6 0 . 0 0 0 . 0 0 2 5 0 8 2 . 9 3 M P F - 1 7 A w p 0 5 c p 8 S t a r t D i r 1 º / 1 0 0 ' : 2 8 3 2 5 . 1 2 ' M D , 8 0 3 6 . 4 3 ' T V D 3 1 2 8 6 9 5 . 9 8 8 7 . 4 4 1 3 . 1 6 8 0 5 0 . 3 7 2 4 8 0 1 . 5 8 5 7 3 3 . 8 7 1 . 0 0 - 1 0 2 . 6 6 2 5 4 5 3 . 3 9 E n d D i r : 2 8 6 9 5 . 9 8 ' M D , 8 0 5 0 . 3 7 ' T V D 32 2 9 3 2 4 . 5 3 8 7 . 4 4 1 3 . 1 6 8 0 7 8 . 4 3 2 5 4 1 3 . 0 2 5 8 7 6 . 8 0 0 . 0 0 0 . 0 0 2 6 0 8 1 . 2 7 M P F - 1 7 A w p 0 5 c p 9 S t a r t D i r 1 º / 1 0 0 ' : 2 9 3 2 4 . 5 3 ' M D , 8 0 7 8 . 4 3 ' T V D 33 2 9 4 2 9 . 0 3 8 8 . 2 3 1 3 . 8 5 8 0 8 2 . 3 8 2 5 5 1 4 . 5 6 5 9 0 1 . 1 9 1 . 0 0 4 1 . 3 5 2 6 1 8 5 . 6 9 E n d D i r : 2 9 4 2 9 . 0 3 ' M D , 8 0 8 2 . 3 8 ' T V D 34 3 1 2 7 2 . 2 5 8 8 . 2 3 1 3 . 8 5 8 1 3 9 . 4 3 2 7 3 0 3 . 3 4 6 3 4 2 . 1 6 0 . 0 0 0 . 0 0 2 8 0 2 8 . 0 3 M P F - 1 7 A w p 0 5 t o e T o t a l D e p t h : 3 1 2 7 2 . 2 5 ' M D , 8 1 3 9 . 4 3 ' T V D SU R V E Y P R O G R A M Da t e : 2 0 2 3 - 0 5 - 2 4 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : De p t h F r o m D e p t h T o Su r v e y / P l a n T o o l 10 0 . 7 0 1 1 7 0 0 . 7 0 4 : G y r o d a t a c o n t . d r i l l p i p e m / ( M P F - 1 7 ) 3 _ G y r o - C T _ D r i l l p i p e 11 7 2 8 . 0 7 2 0 9 0 0 . 0 0 5 : M W D - S t a n d a r d ( M P F - 1 7 ) 3 _ M W D 20 9 0 0 . 0 0 2 1 3 0 0 . 0 0 M P U F - 1 7 L 1 w p 1 1 ( P l a n : M P U F - 1 7 L 1 ) 3 _ M W D _ I n t e r p A z i + S a g 21 3 0 0 . 0 0 3 1 2 7 2 . 0 0 M P U F - 1 7 L 1 w p 1 1 ( P l a n : M P U F - 1 7 L 1 ) 3 _ M W D + I F R 2 + M S + S a g 16800 17400 18000 18600 19200 19800 20400 21000 21600 22200 22800 23400 24000 24600 25200 25800 26400 27000 27600 28200 So u t h ( - ) / N o r t h ( + ) ( 1 2 0 0 u s f t / i n ) 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 West(-)/East(+) (1200 usft/in) MPU F-17A wp10 tgt2 MPU F-17A wp10 tgt1 MPF-17A wp05 toe MPF-17A wp05 cp9 MPF-17A wp05 cp8 MPF-17A wp05 cp7 MPF-17A wp05 cp6 MPF-17A wp05 cp5 MPF-17A wp04 cp4 MPF-17A wp04 cp3 MPF-17A wp04 cp2 MPF-17A wp04 cp1 7735 MPF-17 7" TOW 4 1/2" x 6" 7750 8000 8139 MPU F-17L1 wp11 Start Dir 12º/100' : 20900' MD, 7660.48'TVD : 0° RT TF End Dir : 20917' MD, 7662.95' TVD Start Dir 4.75º/100' : 20947' MD, 7666.78'TVD End Dir : 21247.58' MD, 7699.71' TVD Start Dir 4.75º/100' : 21519.08' MD, 7724.22'TVD End Dir : 21788.32' MD, 7743.57' TVD Start Dir 4º/100' : 22088.32' MD, 7759.43'TVD End Dir : 22160.02' MD, 7761.43' TVD Start Dir 4º/100' : 22945.9' MD, 7763.65'TVD End Dir : 23029.71' MD, 7766.33' TVD Start Dir 4º/100' : 23129.71' MD, 7772.43'TVD End Dir : 23254.61' MD, 7785.47' TVD Start Dir 4º/100' : 23400.62' MD, 7807.04'TVD End Dir : 23595.93' MD, 7825.75' TVD Start Dir 4º/100' : 23910.92' MD, 7839.49'TVD End Dir : 24019.34' MD, 7840.14' TVD Start Dir 4º/100' : 24350.16' MD, 7829.67'TVD End Dir : 24469.24' MD, 7830.38' TVD Start Dir 4º/100' : 24569.24' MD, 7834.74'TVD End Dir : 24696.53' MD, 7842.99' TVD Start Dir 4º/100' : 25303.59' MD, 7895.12'TVD End Dir : 25427.13' MD, 7900.43' TVD Start Dir 4º/100' : 25677.13' MD, 7900.43'TVD End Dir : 25840.3' MD, 7906.9' TVD Start Dir 4º/100' : 26089.73' MD, 7926.67'TVD End Dir : 26126.38' MD, 7930.04' TVD Start Dir 1º/100' : 26426.38' MD, 7961.4'TVD End Dir : 26887.01' MD, 7992.52' TVD Start Dir 1º/100' : 28325.12' MD, 8036.43'TVD End Dir : 28695.98' MD, 8050.37' TVD Start Dir 1º/100' : 29324.53' MD, 8078.43'TVD End Dir : 29429.03' MD, 8082.38' TVD CASING DETAILS TVD TVDSS MD Size Name 7660.64 7614.24 20901.00 7 7" TOW 8139.43 8093.03 31272.25 4-1/2 4 1/2" x 6" Project: Milne Point Site: M Pt F Pad Well: Plan: MPF-17 Wellbore: Plan: MPU F-17L1 Plan: MPU F-17L1 wp11 WELL DETAILS: Plan: MPF-17 Ground Level: 12.70 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 6035260.38 541833.61 70° 30' 26.0971 N 149° 39' 27.8515 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPF-17, True North Vertical (TVD) Reference:MPF-17A Plan @ 46.40usft Measured Depth Reference:MPF-17A Plan @ 46.40usft Calculation Method:Minimum Curvature 3URMHFW &RPSDQ\ /RFDO&RRUGLQDWH5HIHUHQFH 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WE L L D E T A I L S : P l a n : M P F - 1 7 N A D 1 9 2 7 ( N A D C O N C O N U S ) Al a s k a Z o n e 0 4 Gr o u n d L e v e l : 1 2 . 7 0 +N / - S + E / - W N o r t h i n g E a s t i n g La t i t u d e Lo n g i t u d e 0. 0 0 0. 0 0 60 3 5 2 6 0 . 3 8 54 1 8 3 3 . 6 1 7 0 ° 3 0 ' 2 6 . 0 9 7 1 N 14 9 ° 3 9 ' 2 7 . 8 5 1 5 W 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 : We l l P l a n : M P F - 1 7 , T r u e N o r t h Ve r t i c a l ( T V D ) R e f e r e n c e : M P F - 1 7 A P l a n @ 4 6 . 4 0 u s f t Me a s u r e d D e p t h R e f e r e n c e : MP F - 1 7 A P l a n @ 4 6 . 4 0 u s f t Ca l c u l a t i o n M e t h o d : Mi n i m u m C u r v a t u r e SU R V E Y P R O G R A M Da t e : 2 0 2 3 - 0 5 - 2 4 T 0 0 : 0 0 : 0 0 V a l i d a t e d : Y e s V e r s i o n : 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 To o l 10 0 . 7 0 1 1 7 0 0 . 7 0 4 : G y r o d a t a c o n t . d r i l l p i p e m / ( M P F - 1 7 ) 3 _ G y r o - C T _ D r il l p i p e 11 7 2 8 . 0 7 2 0 9 0 0 . 0 0 5 : M W D - S t an d a r d ( M P F - 1 7 ) 3 _ M W D 20 9 0 0 . 0 0 2 1 3 0 0 . 0 0 M P U F - 1 7 L 1 w p 1 1 ( P l a n : M P U F - 1 7 L 1 ) 3 _ M W D _ I n t e r p A z i + S a g 21 3 0 0 . 0 0 3 1 2 7 2 . 0 0 M P U F - 1 7 L 1 w p 1 1 ( P l a n : M P U F - 1 7 L 1 ) 3 _ M W D + I F R 2 + M S + S a g 0. 0 0 30 . 0 0 60 . 0 0 90 . 0 0 12 0 . 0 0 15 0 . 0 0 18 0 . 0 0 Centre to Centre Separation (60.00 usft/in) 20 9 0 0 2 1 4 5 0 2 2 0 0 0 2 2 5 5 0 2 3 1 0 0 2 3 6 5 0 2 4 2 0 0 2 4 7 5 0 2 5 3 0 0 2 5 8 5 0 2 6 4 0 0 2 6 9 5 0 2 7 5 0 0 2 8 0 5 0 2 8 6 0 0 2 9 1 5 0 2 9 7 0 0 3 0 2 5 0 3 0 8 0 0 3 1 3 5 0 Me a s u r e d D e p t h ( 1 1 0 0 u s f t / i n ) GL O B A L F I L T E R A P P L I E D : A l l w e l l p a t h s w i t h i n 2 0 0 ' + 1 0 0 / 1 0 0 0 o f r e f e r e n c e 20 9 0 0 . 0 0 T o 3 1 2 7 2 . 2 5 Pr o j e c t : M i l n e P o i n t Si t e : M P t F P a d We l l : P l a n : M P F - 1 7 We l l b o r e : P l a n : M P U F - 1 7 L 1 Pl a n : M P U F - 1 7 L 1 w p 1 1 CA S I N G D E T A I L S TV D T V D S S M D S i z e N a m e 76 6 0 . 6 4 7 6 1 4 . 2 4 2 0 9 0 1 . 0 0 7 7 " T O W 81 3 9 . 4 3 8 0 9 3 . 0 3 3 1 2 7 2 . 2 5 4 - 1 / 2 4 1 / 2 " x 6 " 1 Dewhurst, Andrew D (OGC) From:Nathan Sperry <Nathan.Sperry@hilcorp.com> Sent:Friday, November 3, 2023 09:24 To:Dewhurst, Andrew D (OGC) Cc:Rixse, Melvin G (OGC); Roby, David S (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] MPU F-17L1 (PTD 223-093) - Question Doyon14. Thankyou, NateSperry DrillingEngineer HilcorpAlaska,LLC From:Dewhurst,AndrewD(OGC)[mailto:andrew.dewhurst@alaska.gov] Sent:Friday,November3,20239:23AM To:NathanSperry<Nathan.Sperry@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,StephenF (OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]MPUFͲ17L1(PTD223Ͳ093)ͲQuestion Nathan, Soundsgood. Whichrigwillyoubeusingforthiswell? Andy From:NathanSperry<Nathan.Sperry@hilcorp.com> Sent:Thursday,November2,202307:52 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,StephenF (OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]MPUFͲ17L1(PTD223Ͳ093)ͲQuestion GoodmorningAndy, WepreferopƟon#1(proceedunderstaterules)anddelayinjecƟonunƟltheAIOisupdated. Thankyou, NateSperry DrillingEngineer 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. 2 HilcorpAlaska,LLC From:Dewhurst,AndrewD(OGC)[mailto:andrew.dewhurst@alaska.gov] Sent:Wednesday,November1,20234:27PM To:NathanSperry<Nathan.Sperry@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,StephenF (OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:[EXTERNAL]MPUFͲ17L1(PTD223Ͳ093)ͲQuestion Nathan, TheMPUFͲ17L1wellistargeƟngreservoiroutsideofthecurrentKuparukRiverOilPoolboundary.Meanwhile,Hilcorp hasappliedfortheexpansionofthispool. ItisunlikelythattheexpansionwillbeissuedbeforetheanƟcipatedspuddateofNovember15th.Youcoulddrillthis wellunderstatewideregulaƟons(vspoolrules)fortheporƟonofthewelloutsidethepool.Fromthedrillingaspect,I don’tseeanychangethiswouldmake.However,HilcorpwouldnotbeabletobegininjecƟonunƟltheAreaInjecƟon Oderwasupdatedwiththeexpandedaīectedarea. QuesƟon: doyouwishto(1)drillassoonaspossibleandproceedwiththepermitunderstateruleswithacondiƟon restricƟnginjecƟon,or(2)waitunƟltheoilpoolandassociatedinjecƟonorderhasbeenupdated? 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. 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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. 223-093 MPU F-17L1 MILNE POINT X KUPARUK RIVER OIL POOL and MILNE POINT, UNDEFINED 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 A l a s k a , L L C We l l N a m e : MI L N E P T U N I T F - 1 7 L 1 In i t i a l C l a s s / T y p e SE R / P E N D Ge o A r e a 89 0 Un i t 11 3 2 8 On / O f f S h o r e On Pr o g r a m SE R Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 0 9 3 0 MI L N E P O I N T , K U P A R U K R I V E R O I L - 5 2 5 1 0 0 M I L N E P O I N T , U N D E F I N E D O I L 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 5 5 0 9 , A D L 3 5 5 0 1 8 , A D L 3 5 5 0 1 7 , A D L 3 5 5 0 1 6 , a n d A D L 3 9 4 1 6 7 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 S e e c o m m e n t s b e l o w . M I L N E P O I N T , K U P A R U K R I V E R O I L - 5 2 5 1 0 0 - g o v e r n e d b y 4 3 2 E a n d M I L N E P O I N T , U N D E 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 T D e x t e n d s o u t s i d e o f M i l n e P o i n t U n i t b u t s t a y s w i t h i n 5 0 0 ' o f H i l c o r p l e a s e b o u n d a r i e 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 P e n d i n g e x p a n s i o n o f K u p a r u k O i l P o o l ( C O - 2 3 - 0 1 4 ) . U n d e r s t a t e r u l e s f o r p o r t i o n o u t s i d e p o o l 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 No S e e c o m m e n t s b e l o w . P e n d i n g e x p a n s i o n o f A r e a I n j e c t i o n O r d e r N o . 1 0 B - M i l n e P o i n t U n i t 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r s e r v Ye s 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 ) No 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 r o t a r y 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 T h i s w e l l i s a i n z o n e r o t a r y 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 . 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s T h i s w e l l i s a i n z o n e r o t a r y s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 20 C M T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g Ye s T h i s w e l l i s a i n z o n e r o t a r y s i d e t r a c k f r o m a n e x i s t i n g w e l l b o r e w i t h p r e s s u r e i n t e g r i t y . 21 C M T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s P a r e n t w e l l h a s a d e q u a t e c e m e n t a t s u r f a c e c a s i n g a n d t o t h e t o p o f p r o d u c t i o n z o n e . 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 r o t a r y 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 D o y o n 1 4 h a s a d e q u a t e t a n k a g e a n d g o o d t r u c k i n g s u p p o r t . 24 A d e q u a t e t a n k a g e o r r e s e r v e p i t Ye s S u n d r y 3 2 3 - 5 5 4 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 i d e n t i f i e s n o c l o s e a p p r o a c h e s . 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 N o d i v e r t e r . T h i s w e l l i s a i n z o n e r o t a r y 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 . 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 A l l f l u i d s w i l l b e o v e r b a l a n c e d t o 6 . 7 P P G E p o r e p r e s s u r e e x p e c t e d 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 1 a n n u l a r 3 r a m , 1 f l o w c r o s 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 5 0 0 0 p s i s t a c k t e s t e d t o 4 0 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 31 C h o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 W o r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n No M a x i m u m H 2 S r e a d i n g o n M P U F p a d i s 4 7 p p m 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 Ye s 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No H 2 S m e a s u r e s r e q u i r e d . F - 6 9 r e c o r d e d s a m p l e w i t h 4 7 p p m . 35 P e r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s P o t e n t i a l o v e r p r e s s u r e i n K u p a r u k D - S h a l e . E x p e c t e d p o r e p r e s s u r e o f K u p a r u k A r e s e r v o i r i s 6 . 7 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 03 - N o v - 2 3 Ap p r MG R Da t e 16 - O c t - 2 3 Ap p r AD D Da t e 09 - O c t - 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e TD e x t e n d s o u t s i d e o f M P U , K u p a r u k R i v e r O i l P o o l , a n d A I O 1 0 B b o u n d a r i e s . H i l c o r p w i l l b e d r i l l i n g t h i s p o r t i o n o f t h e w e l l t o s t a t e ru l e s . I n j e c t i o n n o t a u t h o r i z e d u n t i l t h e A r e a I n j e c t i o n O r d e r ( f u t u r e A I O 1 0 C ) h a s b e e n i s s u e d w i t h e x p a n d e d a f f e c t e d a r e a . *& :