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Home My WebLink About223-108CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Joseph Lastufka To:Guhl, Meredith D (OGC) Subject:RE: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Date:Thursday, December 11, 2025 3:15:53 PM Meredith, Thank you for checking, all 3 wells are either planned to be re-permitted or scheduled further out than the expiration date. Please cancel all 3 wells: PBU NK-24 (PTD #223-108) PBU F-40A (PTD #223-110) PBU L-294 (PTD #223-127) Please let me know if you need anything else. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, December 11, 2025 2:34 PM To: Joseph Lastufka <joseph.lastufka@hilcorp.com> Subject: [EXTERNAL] 223-108 PBU NK-24, 223-110 PBU F-40A, 223-127 PBU L-294 Hello Joe, The following three approved permits are nearing their expiration dates. Does Hilcorp plan to drill any of these three wells, or should they be marked canceled in the AOGCC database? 1. 223-108 PBU NK-24, expires 2/13/2026 2. 223-110 PBU F-40A, expires 1/3/2026 3. 223-127 PBU L-294, expires 1/2/2026 Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Originated: Delivered to:7-Nov-24 Alaska Oil & Gas Conservation Commiss 07Nov24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL IBC-CBL FINAL FIELD 10-Oct-24 2K-19A 50-103-20118-01-00 211-034 Kuparuk River WL Cutter FINAL FIELD 11-Oct-24 MT7-83 50-103-20891-01-00 224-102 Greater Mooses Tooth WL TTiX-USIT-CBL FINAL FIELD 19-Oct-24 1C-157 50-029-23754-00-00 223-038 Kuparuk River WL IBC-CBL FINAL FIELD 23-Oct-24 CD1-33A 50-103-20357-01-00 222-105 Colville River WL PERF FINAL FIELD 30-Oct-24 MT7-09 50-103-20837-00-00 222-011 Greater Mooses Tooth WL TTiX-Plug&Perf FINAL FIELD 1-Nov-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39755 T39756 T39757 T39758 T39759 T39760 1C-157 50-029-23754-00-00 223-038 Kuparuk River WL IBC-CBL FINAL FIELD 23-Oct-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.08 08:38:26 -09'00' 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, Sag River Undefined Oil Pool, PBU NK-24 Hilcorp Alaska, LLC Permit to Drill Number: 223-108 Surface Location: 1384' FSL, 664' FEL, Sec 36, T12N, R15E, UM, AK Bottomhole Location: 1733' FSL, 1806' FEL, Sec 22, T12N, R16E, 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 February 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.13 17:10:35 -06'00' 13 Stg 1 L-955 sx T-595 sx, Stg 2 L-1002 sx / T-539 sx Drilling Manager 11/17/23 Monty M Myers By Grace Christianson at 11:35 am, Nov 17, 2023 * Weekly diverter function test required if surface hole lasts more than 7 days. * BOPE test to 4000 psi. Annular to 3500 psi. * FIT and Casing tests digital data to AOGCC upon completion. 1140 9.875" DSR-11/20/23 PRUDHOE BAY, SAG RIVER UNDEFINED OIL POOL 223-108 St 50-029-23773-00-00 MGR18JAN2024 A.Dewhurst 12FEB24 *&:JLC 2/13/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.13 17:11:02 -06'00' 02/13/24 02/13/24 Prudhoe Bay East (PBU) NK-24 Drilling Program Version 0 11/01/2023 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 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 R/U and Preparatory Work ..................................................................................................... 11 10.0 N/U 21-1/4” 2M Diverter System ............................................................................................. 12 11.0 Drill 16” Hole Section .............................................................................................................. 14 12.0 Run 13-3/8” Surface Casing .................................................................................................... 17 13.0 Cement 13-3/8” Surface Casing ............................................................................................... 22 14.0 ND Diverter, NU BOPE, & Test .............................................................................................. 27 15.0 Drill 12-1/4” Intermediate 1 Hole Section ............................................................................... 28 16.0 Run 9-5/8” Intermediate 1 Casing ........................................................................................... 33 17.0 Cement 9-5/8” Intermediate 1 Casing ..................................................................................... 36 18.0 Drill 8-1/2” x 9-7/8” Intermediate 2 Hole Section ................................................................... 39 19.0 Run 7” Intermediate 2 Liner ................................................................................................... 44 20.0 Cement 7” Intermediate 2 Liner ............................................................................................. 47 21.0 Drill 6-1/8” Production Hole Section ....................................................................................... 50 22.0 Run 4-1/2” Production Liner ................................................................................................... 54 23.0 Cement 4-1/2” Production Liner ............................................................................................. 57 24.0 Perforate 4-1/2” Liner ............................................................................................................. 60 25.0 Run Upper Completion/ Post Rig Work ................................................................................. 61 26.0 Parker 273 Rig Diverter Schematic ......................................................................................... 65 27.0 Parker 273 Rig BOP Schematic ............................................................................................... 66 28.0 Wellhead Schematic ................................................................................................................. 67 29.0 Days Vs Depth .......................................................................................................................... 68 30.0 Formation Tops & Information............................................................................................... 69 31.0 Anticipated Drilling Hazards .................................................................................................. 73 32.0 Parker 273 Rig Layout............................................................................................................. 81 33.0 FIT Procedure .......................................................................................................................... 82 34.0 Parker 273 Rig Choke Manifold Schematic ............................................................................ 83 35.0 Casing Design ........................................................................................................................... 84 36.0 12-1/4” Hole Section MASP ..................................................................................................... 85 37.0 8-1/2” x 9-7/8” Hole Section MASP ......................................................................................... 86 Page 2 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 38.0 6-1/8” Hole Section MASP ....................................................................................................... 87 39.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 88 40.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 89 1.0 Well Summary Well PBU NK-24 Pad Prudhoe Bay NK Pad Planned Completion Type 4-1/2”production Tubing Target Reservoir(s) Sag River Sands Planned Well TD, MD / TVD 26,335’ MD / 9,926’ TVD PBTD, MD / TVD 26,255’ MD / 9,929’ TVD Surface Location (Governmental) 1,384' FSL, 664' FEL, Sec 36, T12N, R15E, UM, AK Surface Location (NAD 27) X= 721,897.30, Y= 5,979,929.04 Top of Productive Horizon (Governmental)746' FNL, 2,458' FEL, Sec 28, T12N, R16E, UM, AK TPH Location (NAD 27) X= 735,247.93, Y= 5,988,769.69 BHL (Governmental) 1,733' FSL, 1,806' FEL, Sec 22, T12N, R16E, UM, AK BHL (NAD 27) X= 741,093.00, Y= 5,991,436.00 AFE Number 231-00061 AFE Drilling Days 50 AFE Completion Days 8 Maximum Anticipated Pressure (Surface) 3,906 psig Maximum Anticipated Pressure (Downhole/Reservoir) 4,912 psig Work String 5” 19.5# S-135 XT-50 4” 14# S-139 XT-39 Parker 273 KB Elevation above MSL: 19.5 ft + 46.95 ft = 66.45 ft GL Elevation above MSL: 19.5 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 2.0 Management of Change Information Page 4 Prudhoe Bay East NK-24 Sag Producer 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) Cond 20” 19.25 - - - X-52 Weld 16” 13-3/8” 12.415 12.259 14.375 68 L-80 BTC 5,020 2,270 1,556 12-1/4” 9-5/8” 8.681 8.525 10.625 47 L-80 DWC-C 6,870 4,760 1,086 8-1/2” 7” 6.276 6.151 7.656 26 L-80 VamTop 7,240 5,410 604 6-1/8” 4-1/2” 3.958 3.833 4.937 12.6 13Cr-80 VamTop 8,430 7,500 288 Tubing 4-1/2” 3.958 3.833 4.937 12.6 13Cr-80 VamTop 8,430 7,500 288 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) Surf, Int, & Prod 5”4.276”3.500”6.500”19.5 S-135 XT50 44,000 52,800 712klb 4”3.340”2.688” 4.875”14.0 S-135 XT39 17,700 21,200 513klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 5.0 Internal Reporting Requirements 5.1 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. 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. 5.2 Afternoon Updates x Submit a short operations update each work day to mmyers@hilcorp.com, frank.roach@hilcorp.com, nathan.sperry@hilcorp.com, jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.3 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. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp,com, frank.roach@hilcorp.com, jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com, frank.roach@hilcorp.com, jengel@hilcorp.com and joseph.lastufka@hilcorp.com 5.7 Hilcorp Contact List: Title Name Work Phone Email Drilling Manager Monty Myers 907.777.8431 mmyers@hilcorp.com Drilling Engineer Frank Roach 907.777.8413 frank.roach@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 jengel@hilcorp.com Drilling Engineer Nate Sperry 907.777.8450 nathan.sperry@hilcorp.com Completion Engineer David Bjork 907.564.4672 david.bjork@hilcorp.com Geologist Christopher Clinkscales 907.777.8316 christopher.clinkscales@hilcorp.com Reservoir Engineer Tanner Gansert 907.564.5234 tanner.gansert@hilcorp.com Drilling Env. Coordinator Chris Keil 303.681.8844 chris.keil@hilcorp.com EHS Manager Laura Green 907.777.8314 lagreen@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 Joseph.Lastufka@hilcorp.com _____________________________________________________________________________________ Created By: FVR 10/20/2023 PROPOSED SCHEMATIC Niakuk Unit Well: NK 24 Last Completed: TBD PTD: TBD GENERAL WELL INFO API: TBD Completed: TBD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 129.5 / X56 / Weld N/A Surface 110’ N/A 13-3/8” Surface 68 / L-80 / BTC 12.415” Surface 6,868’ 0.1497 9-5/8” Intermediate 47 / L-80 / DWC/C 8.681” Surface 18,188’ 0.0732 7” Liner 26 / L-80 / VT 6.276” 18,038’ 19,701’ 0.0383 4-1/2” Liner 12.6 / 13Cr-80 / VT 3.958” 19,551’ 26,335’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr-80 / VT 3.958” Surface 19,551’ 0.0152 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status TD =26,335’(MD) / TD =9,926’(TVD) 13-3/8” KB Elev: = 65.85’ / GL Elev: = 19.5’ 4-1/2” 5 3 4 6 7 9-5/8” 2 PBTD =26,255’(MD) / PBTD =9,929’(TVD) 7” 4-1/2” 1 OPEN HOLE / CEMENT DETAIL Driven 16” Stg 1 L – 955 sx / T – 595 sx, Stg 2 L – 1002 sx / T – 539 sx 12-1/4” L – 522 sx / T – 383 sx 8-1/2” 564 sx Class G 6-1/8” 795 sx Class G JEWELRY DETAIL No Depth ID Item 1 ~2,300’ 12.415” 13-3/8” ES Cementer 2 ~18,038’ 6.190 9-5/8” x 7” Liner Hanger/LTP 3 ~19,551’ 3.910 7” x 4-1/2” Liner Hanger/LTP 4 ~19,555’ 3.958 WLEG 5 ~19,455’ 3.856” Packer 6 TBD 3.813” GLM (Number and depth TBD) 7 ~2,100’ 3.812” Nipple profile for SSSV WELL INCLINATION DETAIL TREE & WELLHEAD Tree Wellhead 6.0 Page 7 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 7.0 Drilling / Completion Summary NK-24 is a 4-string, grassroots producer planned to target the Sag River sands. The directional plan is 16” surface hole and 13-3/8” surface casing set in the base of the SV5. A 12-1/4” section will be drilled and 9-5/8” intermediate 1 casing set at base of the CM3. An 8-1/2”x9-7/8” underreamed section will be drilled and 7” intermediate 2 liner set at TSGR. A 6-1/8” horizontal section will be drilled with the sump in the Ivishak and TD in the Sag River formation. A 4-1/2” production liner will be run and cemented in place. Perforating will be performed on the rig, and the well will be completed with 4- 1/2” production tubing. Parker 273 will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately December 13, 2023, pending rig schedule. Surface casing will be run to 6,868’ MD / ~4,083’ TVD and cemented to surface via a 2-stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to one of two locations: Primary: Prudhoe G&I on Pad 4 Secondary: the Milne Point “B” pad G&I facility General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U & Test 21-1/4” Diverter and 16” diverter line 3. Drill 16” hole to TD of surface hole section. Run and cement 13-3/8” surface casing 4. N/D diverter, N/U wellhead, NU 13-5/8” 5M BOP & Test 5. Drill 12-1/4” to TD of intermediate 1 hole section. Run and cement 9-5/8” intermediate 1 casing 6. Drill 8-1/2”x9-7/8” to TD of intermediate 2 hole section. Run and cement 7” intermediate 2 liner 7. Drill 6-1/8” hole to TD 8. Run and cement 4-1/2” production liner 9. TCP 4-1/2” production liner 10. Run Upper Completion 11. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface Hole: Remote Ops geologist. LWD: GR + Res 2. Intermediate 1 Hole: Field Ops geologist for casing pick. LWD: GR + Res 3. Intermediate 2 Hole: Field Ops geologist for casing pick. Triple Combo 4. Production Hole: Field Ops geologist. LWD: Triple-Combo (For geo-steering) March 4th, 2024 from email correspondence -A.Dewhurst Page 8 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with all applicable AOGCC regulations, specific regulations are listed below. 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 BOPs shall be tested at (2) week intervals during the drilling and completion of PBU NK-24. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial and subsequent tests of BOP equipment will be to 250/4,000 psi for 5/5 min (annular to 70% rated WP, 3,500 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)”. Page 9 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure AOGCC Regulation Variance Requests: x No variances are requested at this time. Summary of Parker 273 BOP Equipment & Test Requirements Hole Section Equipment Test Pressure (psi) 16”x 21-1/4” 2M Annular BOP w/ 16” diverter line Function Test Only 12-1/4” x 13-5/8” x 5M Annular BOP x 13-5/8” x Double Gate o Blind ram in btm cavity x Mud cross w/ 3-1/8” x 5M side outlets x 13-5/8” x Single ram x 3” x 5M Choke Line x 2” x 5M Kill line x 3” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/4,000 Annular: 250/3,500 Subsequent Tests: 250/4,000 Annular: 250/3,500 8-1/2” x 13-5/8” x 5M Annular BOP x 13-5/8” x Double Gate o Blind ram in btm cavity x Mud cross w/ 3-1/8” x 5M side outlets x 13-5/8” x Single ram x 3” x 5M Choke Line x 2” x 5M Kill line x 3” x 5M Choke manifold x Standpipe, floor valves, etc 6-1/8” x 13-5/8” x 5M Annular BOP x 13-5/8” x Double Gate o Blind ram in btm cavity x Mud cross w/ 3-1/8” x 5M side outlets x 13-5/8” x Single ram x 3” x 5M Choke Line x 2” x 5M Kill line x 3” x 5M Choke manifold x Standpipe, floor valves, etc Primary closing unit: Sara Koomey Control Unit, 3,000 psi, 316 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an air-driven pump and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. x 9-7/8" Page 10 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 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 Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@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 11 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 9.0 R/U and Preparatory Work 9.1 NK-24 will utilize an existing set 20” conductor on Niakuk Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 Ensure any necessary wellhead equipment is staged prior to MIRU. A slip-loc starting head should also be staged in the cellar in the event that surface casing must be set using emergency slips. 9.8 MIRU Parker 273 Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.9 Mix spud mud for 16” surface hole section. Ensure mud temperatures are cool (<80qF). 9.10 Ensure 5-3/4” liners in mud pumps. x NOV 12-P-160 1,600 HP mud pumps are rated at 5,085 psi, 471 gpm @ 120 spm @ 97% volumetric efficiency. Page 12 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 10.0 N/U 21-1/4” 2M Diverter System 10.1 N/U 21-1/4” diverter (Diverter Schematic attached to program). x N/U 20”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x N/U 20” riser to BOP Deck x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source 10.2 Notify AOGCC. Function test diverter. x Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. x Ensure that the annular closes in less than 45 seconds (API Standard 64 3rd edition March 2018 section 12.6.2 for packing element ID greater than 20”) 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 13 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 10.4 Rig & Diverter Orientation: x May change on location Page 14 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 11.0 Drill 16” Hole Section 11.1 P/U 16” directional drilling 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 Consider running a UBHO sub for wireline gyro.GWD will be the primary gyro tool. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135. x Run a solid float in the surface hole section. 11.2 Begin drilling out from conductor at reduced flow rates to avoid broaching the conductor. x Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 16” hole section to section TD in the SV5. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well, targeting the shale package in the base of the SV5. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 450-550 gpm while drilling through permafrost. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Once past base permafrost, slowly increase flow rate to a maximum of 650 gpm over several stands. x Avoid sliding when drilling across the prognosed base of permafrost, top SV6, and the EOCU to prevent high dogleg severity. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability. x Perform gyro surveys until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 15 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x In PBE hydrates are not present. However, continue to drill using hydrate mitigation measures: x Keep mud temperature as cool as possible, Target 60-70°F x Dump and dilute as necessary to maintain temp, utilize cold water on the rig as well as cold premade mud on trucks ready x Drill through hydrate sands and quickly as possible, do not backream. x While not expected to be present, monitor returns for hydrates, checking pressurized & non-pressurized scales x Take MWD and GWD surveys every stand until magnetic interference cleans up. After MWD surveys show clean magnetics, only take MWD surveys. x Surface Hole AC: x There are no wells with a clearance factor of <1.0 11.4 16” hole mud program summary: System Type:8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density PV YP API FL HPHT Drill Solids MBT Hardness Surface –BPRF 8.8 –9.0 10-20 20-45 NC NA <9 <35 <200 BPRF - TD 9.0 –9.5 10-30 20-45 <10 NA <9 <35 <200 System Formulation: Gel + FW spud mud Product Quantity Water 0.967 Bbls Soda Ash 0.125 ppb M-I GEL 35.0 ppb Primary Products Weight Material M-I WATE Viscosifiers M-I GEL Fluid Loss Additives M-I Pac UL (only if needed for fluid loss near TD) Alkalinity Control Soda Ash Bit & BHA Balling SCREENKLEEN (only if needed for balling in surface) Contingency Products Thinner CF Desco II, TANNATHIN & SAPP Cement Contamination Sodium Bicarbonate & SAPP Screen Blinding SCREENKLEEN Lost Circulation Material NUT PLUG FINE & MEDIUM, M-I-X II FINE & Medium Foaming/Aeration SCREENKLEEN / DEFOAM EXTRA x PVT System: PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. Page 16 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Casing Running:Reduce system YP as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). 11.5 At TD; PU 2-3 stands off bottom to avoid washing out the hole at TD, CBU, pump tandem sweeps and drop viscosity. Drop mud temp as low as possible as well. 11.6 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (550-650 gpm) and maximize rotation. x Pull slowly, 5 – 10 ft / minute, adjust as dictated by hole conditions x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. Page 17 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 12.0 Run 13-3/8” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 13-3/8” casing running equipment (CRT & Tongs) x Ensure 13-3/8” BTC x XT50, and TXP x XT50 XO on rig floor and M/U to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x R/U of CRT if hole conditions require. x R/U a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 12.25” on the location prior to running. x Be sure to count the total # of joints on the location 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. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120’ shoe track assembly consisting of: 13-3/8” Float Shoe 1 joint – 13-3/8”, 2 Centralizers 10’ from each end w/ stop rings 1 joint –13-3/8”, 1 Centralizer mid joint w/ stop ring 13-3/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint –13-3/8”, 1 Centralizer mid joint with stop ring 13-3/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record S/N’s of all float equipment and stage tool components. 12.5 Float equipment and Stage tool equipment drawings: This end up. Bypass Baffle Page 18 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 19 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 12.6 Continue running 13-3/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: x 1 centralizer every joint to ~ 1000’ MD from shoe x 1 centralizer every 2 joints from ~1,000’ above shoe to ~100’ TVD below base permafrost (~2,280’ MD) x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~1,935’ MD prognosed). x Install centralizers over couplings on 5 joints below and 5 joints above stage tool. x Do not place tongs on ES cementer, this can cause damage to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 2800 psi. 13-3/8” 68/# L-80 BTC MUT – Make up to Mark 10 jts Take Average Casing OD Minimum Optimum Maximum 13-3/8” 27,540 ft-lbs Mark 33,660 ft-lbs Page 20 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 21 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 12.8 Continue running 13-3/8” surface casing x Centralizers: 1 centralizer every 3rd joint to 200’ from surface x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 22 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 13.0 Cement 13-3/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 120 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 40% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: Page 23 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: = (6,868-120)*.1497 =1,010 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mix Water 13.92 gal/sk 4.97 gal/sk Page 24 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 25 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2 nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre-job safety meeting. x Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 120 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2 nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. Lead Slurry Tail Slurry System Arctic Cem G Density 11.0 lb/gal 15.8 lb/gal Yield 2.54 ft3/sk 1.17 ft3/sk Mixed Water 12.2 gal/sk 5.08 gal/sk 516 2793 18.3 1140 102 2895 497 110' Page 26 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 13.26 Displacement calculation: 2055’ x 0.1497 bpf = 308 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1,000 – 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips. 13.30 Make initial cut on 13-3/8” final joint. L/D cut joint. Make final cut on 13-3/8”. Dress off stump. Install 13-3/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to frank.roach@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 14.0 ND Diverter, NU BOPE, & Test 14.1 ND the diverter T, knife gate, diverter line & NU 13-5/8” 5M casing spool. 14.2 NU 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 5-1/2” VBRs or 5” solid body rams in top cavity,blind ram in bottom cavity. x Single ram can be dressed with 2-7/8” x 5-1/2” VBRs or 5” solid body rams x NU 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 14.3 RU MPD RCD and related equipment 14.4 Run 5” BOP test plug 14.5 Test BOP to 250/4,000 psi for 5/5 min. Test annular to 250/3,500 psi for 5/5 min. x Test with 5” test joint and test VBR’s with 2-7/8” and 5” test joints x Smallest and largest pipes to be ran 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 x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 RD BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix LSND fluid for production hole. Starting mud weight at either 9.0 ppg or matching mud weight used to TD surface hole, whichever is heavier. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 5-3/4” liners in mud pumps. Page 28 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 15.0 Drill 12-1/4” Intermediate 1 Hole Section 15.1 MU 12-1/4” cleanout BHA x Milltooth bit and Motor 15.2 TIH w/ 12-1/4” BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 3,000 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on LOT/FIT graph. AOGCC reg is 50% of burst = 5,020 / 2 = ~2,510 psi. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoetrack and 20’ of new formation. 15.6 CBU and condition mud for LOT. 15.7 Conduct LOT. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. Submit casing test and LOT digital data to AOGCC. x 11.8 ppg EMW provides >>25bbls based on 11.0 ppg MW, 10.0 ppg PP (swabbed kick at 11.0 ppg EMW BHP) 15.8 POOH and LD cleanout BHA 15.9 MU 12-1/4” directional BHA x RSS and Gr/Res x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Drill string will be 5” 19.5# S-135 XT50. x Run a solid float in this hole section. x 12-1/4” ghost reamer along 5” DP to split openhole section (~5,650’ behind bit). 0.5 ppg kick intensity above 11.0 ppg mud wt would require 12.4 ppge shoe integrity for ~25 bbl kick tolerance. - mgr Email promptly upon completion: melvin.rixse@alaska.gov Page 29 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 15.10 12-1/4” hole section mud program summary: System Type:9.0 – 11.0 ppg LSND drilling fluid Properties: Interval Density PV YP API FL HPHT Drill Solids MBT Hardness ~6,868’ – ~10,543’ Shoe –UG4 9.0 – 9.4 5 – 20 15 – 30 < 8 N/A <6% <12 <200 ~10,543’ – ~15,994’ UG4 –CM3 9.4 – 10.5 5 – 20 15 – 30 < 8 N/A <6% <20 <200 ~15,994’ – ~18,188’ CM3 –TD 10.5 – 11.0 5 – 20 15 – 30 < 6 N/A <6% <20 <200 Product Quantity Water 0.916 bbls/bbl Soda Ash 0.17 ppb DUO-VIS 1.0 –1.5 ppb (as needed) DUAL-FLO/ FLO-TROL 3.0 ppb SCREENKLEEN 0.25% v/v M-I Wate 55 ppb (as needed for wt.) Busan 1060 2.1 gals/100 bbls Sodium Metabisulfite 0.25 ppb (added at rig only) Primary Products Viscosifiers DUO-VIS/ XCD Fluid Loss Additives FLO-TROL/ DUAL-FLO Bit & BHA Balling SCREENKLEEN (only if needed for balling/Ugnu/WS) Bridging Agent SAFE-CARB 20 & 40 Alkalinity Control Soda Ash Inhibition Potassium Chloride Lubricants LUBE 776 & LOTORQ Corrosion Control Sodium Metabisulfite (added at rig only) Bacteria Control Busan 1060 Contingency Products Cement Contamination Sodium Bicarbonate & SAPP Weight Material MI-WATE Foaming/Aeration SCREENKLEEN, DEFOAM EXTRA Lost Circulation Material NUT PLUG FINE & MEDIUM, SAFE-CARB 40, 250 & 750 x Density: Weighting material to be used for the hole section will be Barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. 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. Page 30 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Rheology: Keep viscosifier additions to an absolute minimum (DUO-VIS / XCD). Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. 15.11 TIH with 12-1/4” directional assembly to bottom. 15.12 Displace wellbore to LSND for upcoming hole section. Initial mud weight is either 9.0 ppg or the mud weight used to TD surface section, whichever is higher. 15.13 Obtain initial ECD benchmark readings prior to drilling ahead. 15.14 Drill 12-1/4” hole section from 13-3/8” shoe to ~ 10,350’ MD (~200’ MD above UG4) per Geologist and Drilling Engineer Utilizing the following parameters: x Flow Rate: 900-975 GPM x RPM: Maximize RPM when rotating Take the first couple stands to understand BHA tendency. Maintenance slides may be necessary to keep sail angle x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication. Attempt to limit drilling ECD to 1.0 ppg over calculated cleanhole ECD. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across any sands for any extended period of time. x Limit maximum instantaneous ROP to < 200 FPH. The SV sands will drill faster than this, but good hole cleaning practices now reduces time needed to cleanup prior to running casing. x Target ROP is as fast as we can clean the hole without having to backream connections x 12-1/4” Interval A/C: x There are no wells with a CF < 1.0 15.15 Toward the end of the above interval, begin to weight up to 9.4 ppg. Ensure mud is a consistent 9.4 ppg ~200’ before entering the UG4. x Overpressure is not expected in the UG4 through UG1. Page 31 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 15.16 Drill 12-1/4” hole section from ~10,350’ MD to ~ 15,800’ MD (~200’ MD above CM3) per Geologist and Drilling Engineer Utilizing the following parameters: x Flow Rate: 800-950 GPM x RPM: Maximize RPM when rotating x Limit WOB to 20k max to maintain bit stability when encountering hard stringers in the UG4-UG1 x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication. Attempt to limit drilling ECD to 1.0 ppg over calculated cleanhole ECD. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across any sands for any extended period of time. x Limit maximum instantaneous ROP to < 200 FPH. Good hole cleaning practices now reduces time needed to cleanup prior to running casing. x Target ROP is as fast as we can clean the hole without having to backream connections x 12-1/4” Interval A/C: x There are no wells with a CF < 1.0 15.17 Toward the end of the above interval, begin to weight up from 9.4 ppg to 10.5 ppg. Ensure mud is a consistent 10.5 ppg ~200’ before entering the CM3. x If using a spike fluid to weight up, ensure the fluid is heated to avoid shocking the formation and inducing losses/breathing 15.18 Drill 12-1/4” hole section from ~15,800’ MD to section TD (projected at ~18,188’ MD) per Geologist and Drilling Engineer Utilizing the following parameters: x Flow Rate: 800 – 950 GPM x RPM: Maximize RPM when rotating x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x 12-1/4” Interval A/C: x There are no wells with a CF < 1.0 15.19 Intermediate 1 Casing Pick for NK-24: x TD for the Intermediate 1 interval is toward the base of the CM3. x Ensure drop to 40° inc is completed before calling TD. 15.20 At TD, CBU at least 3 times at max gpm and RPM. Pump tandem sweeps if needed Page 32 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Monitor BU for increase in cuttings, cuttings in high sail angle hole sections come back in waves and not a consistent stream, circulate more if necessary x Obtain BHCT from MWD tools and provide to Halliburton cementers. 15.21 Short trip to the previous trip point x Pull slow in and out of the slips to avoid swabbing. x If tight hole is encountered, RIH 2-3 stands and CBU. If tight spot is at the same depth, begin backreaming. x If backreaming operations are commenced, continue backreaming to the shoe x Monitor pressure, ECD, torque, and return flow to indicate potential packing off. x If backreaming is initiated, utilize MPD to close on connections while BROOH. x CBU minimum two times at trip point. 15.22 RIH to TD on elevators and circulate hole clean. 15.23 POOH and LD BHA. 15.24 Set test plug and change out upper rams to 9-5/8” fixed-bore rams. Test with 9-5/8” test joint to 250/4,000 psi for 5/5 minutes. Page 33 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 16.0 Run 9-5/8” Intermediate 1 Casing 16.1 Well control preparedness: In the event of an influx of formation fluids while running the intermediate casing, the following well control response procedure will be followed: x P/U & M/U the 5” safety joint (with 9-5/8” crossover installed on bottom, TIW valve in open position on top, 5” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 9-5/8” casing. x Slack off and with 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW. x Proceed with well kill operations. 16.2 R/U 9-5/8” casing running equipment. x Ensure 9-5/8” 47# DWC/C x XT50 crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck 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. 16.3 Run 9-5/8” intermediate casing x Use BOL 2000 or equivalent thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Centralization: x 1 centralizer every joint to ~ 2000’ MD from surface casing shoe x 1 centralizer every 2 joints from ~2,000’ above shoe to 1 jt below 13-3/8” surface casing shoe (~6,900’ MD) x Utilize a collar clamp until weight is sufficient to keep slips set properly. x If liner length exceeds surface casing length, ensure centralizers are placed 1/jt for each joint outside of the surface shoe. x Obtain up and down weights of the casing before entering open hole. Record rotating torque at 10 and 20 rpm x See data sheets on the next page for MU torque for the 9-5/8” casing connection. 12.15 Continue M/U & thread locking 80’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8”, 2 Centralizers 10’ from each end w/ stop rings 1 joint –9-5/8”, 1 Centralizer mid joint w/ stop ring 9-5/8” Float Collar 1 joint – 9-5/8”, 1 Centralizer free floating 9-5/8” 47/# L-80 DWC/C Make-up Torque Casing OD Minimum Optimum Maximum 9-5/8” 40,000 ft-lbs 45,000 ft-lbs 50,000 ft-lbs Page 34 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 35 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 16.4 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.5 Slow in and out of slips. 16.6 RIH with 9-5/8” intermediate casing to 13-3/8” shoe at ~ 6,868’ MD. CBU and establish PU, SO, and rotating weights prior to exiting shoe. 16.7 Continue to RIH with 9-5/8” intermediate casing using the following circulation strategy (Note: Take special care when staging pumps up and down to avoid packing off and breaking down formation): x 13-3/8” shoe to TD: Every 5th joint, staging up to planned cementing rate. Circulate for 5 minutes. x If pickup/slackoff weights are deviating from trend, circulate consecutive joints down to achieve a bottoms-up. 16.8 P/U hanger and landing joint and M/U to casing string. Casing shoe +/- 5’ from TD. 16.9 Break circulation at 1 bpm to avoid breaking down formation. Slowly stage up to full circulating rate (planned cementing rates). Allow circulating pressures to stabilize before increasing circulating rate to the next stage. Circulate 2 BU or more if needed to condition hole for cementing. Reduce YP to < 18 to help ensure success of cement job. Do not start the YP drop until casing is on bottom and cementers are ready. Page 36 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 17.0 Cement 9-5/8” Intermediate 1 Casing 17.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 17.2 Document efficiency of all possible displacement pumps prior to cement job. 17.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 17.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 17.5 Fill surface cement lines with water and pressure test. 17.6 Pump remaining 120 bbls 12.5 ppg tuned spacer. 17.7 Drop bottom plug – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 17.8 Cement volume based on annular volume + 40% open hole excess. Job will consist of lead & tail, TOC brought to above TWS. Estimated Total Cement Volume: Page 37 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Cement Slurry Design: 17.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 17.10 After pumping cement, drop top plug and displace with the rig pumps and LSND mud out of mud pits. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 17.11 Displacement calculation: = (18,188-80)*.0732 = 1326 bbls 17.12 Monitor returns closely while displacing cement. Adjust pump rate if losses or packing off are seen at any point during the job. 17.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±3.0 bbls before consulting with Drilling Engineer. 17.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. 17.15 Set packoff and test per wellhead tech. 17.16 Change upper rams from 9-5/8” casing rams to 2-7/8” x 5” VBRs and test to 250/4,000 psi for 5/5 minutes with 5” test joint. 17.17 Freeze protect 13-3/8” x 9-5/8” casing annulus to ~2,200’ MD with dead crude or diesel after cement tests indicate cement has reached 500 psi compressive strength. Note: Injection after packoff set & tested not required as there’s ~8,100’ between planned TOC and the casing shoe. x Initiate injection down with drilling mud. Pump 1-2 bbls down the annulus (after reaching breakdown pressure) to ensure an open annulus in preparation for the freeze protect job. Lead Slurry Tail Slurry Density 13.0 lb/gal 15.3 lb/gal Yield 1.84 ft3/sk 1.23 ft3/sk Mix Water 10.13 gal/sk 5.57 gal/sk Injection immediately after plug bump not necessary due to distance between planned TOC and surface casing shoe. - mgr per Franck Roach email 01-DEC-23 Page 38 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Freeze protect with 131 bbls of dead crude/diesel x Ensure total injection volume injected down the annulus (including mud used to keep annulus open) doesn’t exceed 110% of the 13-3/8” x 9-5/8” annular volume. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to jengel@hilcorp.com and joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 39 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 18.0 Drill 8-1/2” x 9-7/8” Intermediate 2 Hole Section 21.1 MU 8-1/2” x 9-7/8” directional BHA x RSS and Triple Combo x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Halliburton underreamer will be utilized above the MWD to allow for 9-7/8” hole x Drill string will be 5” 19.5# S-135 XT50. x Run a solid float in the intermediate 2 hole section. 21.2 TIH w/ 8-1/2” x 9-7/8” BHA to float collar. Note depth TOC tagged on AM report. Drill out shoe track to 10’ above float shoe. 21.3 RU and test casing to 4,000 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 21.4 Intermediate 2 hole section will use the same mud used to TD Intermediate 1 hole section. 21.5 Drill out remaining shoe track and 20’ of new formation. 21.6 CBU and condition mud for FIT. 21.7 Conduct FIT to 12.9 ppg EMW. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. Submit casing test and FIT digital data to AOGCC. x 12.9 ppg FIT provides >>25bbls based on 12.0 ppg MW, 10.50 ppg EMW PP (swabbed kick at 12.0 ppg EMW BHP) 21.8 8-1/2” x 9-7/8” hole section mud program summary: System Type:10.5 – 12.0 ppg LSND drilling fluid Email: melvin.rixse@alaska.gov Notify AOGCC if FIT <12.9 ppg Page 40 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Properties: Interval Density PV YP API FL HPHT Drill Solids MBT Hardness ~18,188’ – ~18,845’ Shoe –CM1 10.5 – 10.8 5 – 20 15 – 30 < 6 N/A <6% <20 <200 ~18,845’ – TD CM1 –TD 10.8 – 12.0 5 – 20 15 – 30 < 6 <10 <6% <20 <200 Product Quantity Water 0.916 bbls/bbl Soda Ash 0.17 ppb DUO-VIS 1.0 –1.5 ppb (as needed) DUAL-FLO/ FLO-TROL 3.0 ppb SCREENKLEEN 0.25% v/v M-I Wate 55 ppb (as needed for wt.) Busan 1060 2.1 gals/100 bbls Sodium Metabisulfite 0.25 ppb (added at rig only) Primary Products Viscosifiers DUO-VIS/ XCD Fluid Loss Additives FLO-TROL/ DUAL-FLO Bit & BHA Balling SCREENKLEEN (only if needed for balling/Ugnu/WS) Bridging Agent SAFE-CARB 20 & 40 Alkalinity Control Soda Ash Inhibition Potassium Chloride Lubricants LUBE 776 & LOTORQ Corrosion Control Sodium Metabisulfite (added at rig only) Bacteria Control Busan 1060 Contingency Products Cement Contamination Sodium Bicarbonate & SAPP Weight Material M-I Wate Foaming/Aeration SCREENKLEEN, DEFOAM EXTRA Lost Circulation Material NUT PLUG FINE & MEDIUM, SAFE-CARB 40, 250 & 750 x Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. 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 Rheology: Keep viscosifier additions to an absolute minimum (DUO-VIS / XCD). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning Page 41 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Run the centrifuge as needed while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. 21.9 Install MPD RCD 21.10 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 21.11 Once ~300’ outside of the 9-5/8” shoe, pick up off bottom and activate underreamer per Halliburton procedure. Verify reamer blades are unlocked. 21.12 Drill 8-1/2” x 9-7/8” hole section to ~18,650’ MD (~200’ above CM1) per geologist and Drilling Engineer utilizing the following parameters: x Flow Rate: 500-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Limit maximum instantaneous ROP to < 200 FPH. This is to minimize cutter damage if encountering concretions or the Tuffs section in the Colville. x Do not initiate backreaming while the underreamer is unlocked. Backreaming can damage the reamer cutting blocks or possibly back off the pilot BHA. x Prior to picking up off bottom for a connection, ensure WOB has drilled off (hookload and torque returning to free rotating values) and RPM gradutally slowed to zero. This is to mitigate the risk of backing off the pilot BHA. x Target ROP is as fast as we can clean the hole without having to backream connections x MPD will be utilized to hold ECD and monitor any pressure build up on connections. x 8-1/2” x 9-7/8” Hole Section A/C: X 9-7/8" -mgr Page 42 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x There are no wells with a CF < 1.0 21.13 Toward the end of the above interval, begin to weight up from 10.5 ppg to 10.8 ppg. Ensure mud is a consistent 10.8 ppg ~200’ before entering the CM1. x If using a spike fluid to weight up, ensure the fluid is heated to avoid shocking the formation and inducing losses/breathing 21.14 Drill 8-1/2” hole section from ~18,650’ to section TD per Geologist and Drilling Engineer. x Flow Rate: 500-550 GPM, target min. AV’s 200 ft/min, 385 GPM x RPM: 120+ x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Limit maximum instantaneous ROP to < 200 FPH. This is to minimize cutter damage if encountering concretions or the Tuffs section in the Colville. x Do not initiate backreaming while the underreamer is unlocked. Backreaming can damage the reamer cutting blocks or possibly back off the pilot BHA. x Prior to picking up off bottom for a connection, ensure WOB has drilled off (hookload and torque returning to free rotating values) and RPM gradutally slowed to zero. This is to mitigate the risk of backing off the pilot BHA. x Target ROP is as fast as we can clean the hole without having to backream connections x MPD will be utilized to hold ECD and monitor any pressure build up on connections. x 8-1/2” x 9-7/8” Hole Section A/C: x There are no wells with a CF < 1.0 21.15 TD will be in the SGR formation and confirmed via samples. Do not lock the underreamer blades until SGR samples are verified. Follow Halliburton parameters for rotating while circulating up samples with the blades unlocked. 21.16 Once samples are verified and the underreamer blades are locked closed, CBU at drilling rate and max rotation. Pump sweeps if needed x Monitor BU for increase in cuttings 21.17 Perform wiper trip to the 9-5/8” casing shoe x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If pulling tight, trip back to TD and begin backreaming operations. x If backreaming operations are commenced, continue backreaming to the shoe X 9-7/8" -mgr Page 43 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 21.18 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 21.19 If trip to 9-5/8” shoe is clean, continue to POOH and LD BHA for upcoming liner run. 21.20 If trip to the shoe is troublesome, run back to TD and CBU 2x or until well cleans up, whichever comes later. 21.21 POOH and LD BHA. Rabbit DP that will be used to run liner. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 44 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 19.0 Run 7” Intermediate 2 Liner 22.1 Well control preparedness: In the event of an influx of formation fluids while running the injection liner, the following well control response procedure will be followed: x P/U & M/U the 5” safety joint (with 7” crossover installed on bottom, TIW valve in open position on top, 5” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 7” liner. x Slack off and with 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW. x Proceed with well kill operations. 22.2 Change upper VBRs to 7” casing rams and test to 250 psi low, 4,000 psi high for 5/5 minutes using 7” test joint. 22.3 R/U 7” liner running equipment. x Ensure 7” 26# VT x XT50 crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck 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. 22.4 Run 7” injection liner x Use Vam approved thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x If liner length exceeds surface casing length, ensure centralizers are placed 1/jt for each joint outside of the surface shoe. x Obtain up and down weights of the liner before entering open hole. x See data sheet on the next page for MU torque for the 7” liner connections. x Run 1 centralizer per joint. 7” 26/# L-80 VT – Make up Torque Casing OD Minimum Optimum Maximum 7” 7,470 ft-lbs 8,300 ft-lbs 9,130 ft-lbs Page 45 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 46 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 22.5 Ensure hanger/pkr will not be set in a 9-5/8” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Plan is to place liner hanger with ~150’ overlap. Do not place liner hanger/packer across 9-5/8” connection. 22.6 Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 22.6 M/U Baker SLZXP liner top packer to 7” liner. Circulate 2 liner volumes to clear string and allow for PAL mix to set 22.7 Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 22.8 RIH with liner no faster than 30 ft/min – Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. x Ensure 5” DP has been drifted x Fill drill pipe on the fly. Monitor FL and if filling is required due to losses/surging. 22.9 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 22.10 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. If torque approaches make-up torque of liner, discontinue rotation. 22.11 Tag bottom and PU to position float shoe ~2’ off bottom. 22.12 Break circulation. Begin circulating at ~0.5 – 1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating for risk of prematurely setting liner hanger. Note all losses. Confirm all pressures with Baker. Page 47 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 20.0 Cement 7” Intermediate 2 Liner 23.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 23.2 Document efficiency of all possible displacement pumps prior to cement job. 23.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 23.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 23.5 Fill surface cement lines with water and pressure test. 23.6 Pump remaining 60 bbls 12.5 ppg tuned spacer. 23.7 Cement volume based on annular volume + 40% open hole excess. Job will consist of tail slurry, TOC brought to top of liner. Estimated Total Cement Volume: Cement Slurry Design: Tail Slurry Density 15.8 lb/gal Yield 1.16 ft3/sk Mix Water 4.98 gal/sk 23.0 Page 48 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 23.8 Drop drillpipe dart and displace with drilling mud. If hole conditions allow – continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 23.9 Displace cement at max rate of 7 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 23.10 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 23.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 23.12 Slack off 20K lbs on the SLZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool Slack off total liner weight plus 30k to confirm hanger is set. 23.13 Bleed DP pressure to 0 psi and check floats. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 23.14 PU to neutral weight, close BOP and test annulus to 1,500 psi for 5 minutes to confirm liner top packer is set. 23.15 Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, repeat setting process in 20.13. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting. 23.16 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top) 23.17 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 23.18 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. While cement returns will be challenging to observe, watch for them and record the estimated volume. Rotate & circulate to clear cmt from DP. Nominal Capacity of 5" S-135 19.5 #/ft ~.01733 bpf -mgr Page 49 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 23.19 RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. 23.20 Change upper rams from 7” fixed to 2-7/8” x 5” VBRs and test with 4” and 5” test joints to 250 psi low / 4,000 psi high for 5/5 minutes. If not completed in the previous BOP test, test the lower VBRs with 4” and 5” test joints to the same criteria. 23.21 Pressure test casing and liner to 250 psi low / 4,000 psi high for 30 minutes. Do not test until cement has reached minimum 1,000 psi compressive strength. Page 50 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 21.0 Drill 6-1/8” Production Hole Section 21.1 MU 6-1/8” directional BHA x RSS and Triple Combo x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. Visually verify no debris inside components that cannot be drifted. x Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be a tapered string 5” 19.5# S-135 XT50 and 4” 14.0# S-135 XT39. x Run a solid float in the production hole section. 21.2 TIH w/ 6-1/8” BHA to float collar. Note depth TOC tagged on AM report. Drill out shoe track to 10’ above float shoe. 21.3 RU and test casing/liner envelope to 4,000 psi / 30 min. Ensure to record volume / pressure (every ¼ bbl) and plot on FIT graph. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 21.4 Displace well to 9.7 ppg solids-free drilling fluid. 21.5 Drill out remaining shoe track and 20’ of new formation. 21.6 CBU and condition mud for FIT. 21.7 Conduct FIT to 10.9 ppg EMW. Chart Test. Ensure test is recorded on same chart as casing test. Document incremental volume pumped (and subsequent pressure) and volume returned. Submit casing test and FIT digital data to AOGCC. x 10.9 ppg FIT provides >>25bbls based on 10.4 ppg MW, 9.40 ppg EMW PP (swabbed kick at 10.4 ppg EMW BHP) 21.8 6-1/8” hole section mud program summary: System Type:9.6 – 10.4 ppg PowerPro drilling fluid Properties: Interval Density PV YP API FL HPHT Drill Solids MBT Hardness Production 9.6-10.4 5 –20 15 –25 <10 NA <8 <10.0 <200 FIT and Casing Test digital data to: melvin.rixse@alaska.gov Page 51 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Product Quantity Water 0.916 bbls/bbl Soda Ash 0.17 ppb POWERVIS 0.75 –1.25 ppb (as needed) DUAL-FLO/ FLO-TROL 4.0 ppb SCREENKLEEN 0.125% v/v KLC 21.8 ppb (6% by wt.) SAFE-CARB 20 22 ppb SAFE-CARB 40 22 ppb Salt 14.4 ppb (as needed for density) LUBE 776 1.0% v/v LOTORQ 1.0% v/v Busan 1060 2.1 gals/100 bbls Sodium Metabisulfite 0.25 ppb (added at rig only) Primary Products Viscosifiers POWERVIS Fluid Loss Additives FLO-TROL/ DUAL-FLO Bridging Agent SAFE-CARB 20 & 40 Alkalinity Control Soda Ash Inhibition Potassium Chloride Lubricants LUBE 776 & LOTORQ Corrosion Control Sodium Metabisulfite (added at rig only) Bacteria Control Busan 1060 Bridging/Density SAFE-CARB 20 & 40, Salt Contingency Products Cement Contamination Sodium Bicarbonate & SAPP Weight Material SAFE-CARB 20 & 40, Salt Foaming/Aeration SCREENKLEEN, DEFOAM EXTRA Lost Circulation Material NUT PLUG FINE & MEDIUM, SAFE-CARB 40, 250 & 750 x Density: Primary weighting material to be used for the hole section will be sodium chloride. Additional NaCl will be on location to weight up the active system (1) ppg above highest anticipated MW. 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 Rheology: Keep viscosifier additions to a minimum (FLO-VIS). Utilize high vis sweeps and tandem sweeps as necessary for hole cleaning. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge as needed while drilling the production hole, this will help with solids removal. Page 52 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. 21.9 Install MPD RCD 21.10 Begin drilling 6-1/8” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes 21.11 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 250-350 GPM, target min. AV’s in the open hole section: 200 ft/min, 175 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Reservoir plan is to drill down into the Ivishak sands before turning up and landing back in the Sag River sands for the horizontal. x There are 3 potential fault crossings (~20,700’MD, ~21,000’MD, and ~21,850’MD) in the production interval. x After the sump and landing back in the Sag, additional lubes will likely be required. x After making a connection, it may be necessary to start rotation prior to bringing on the pumps. This is to help break the static gels in the mud and minimize the ECD. x Limit maximum instantaneous ROP to < 200 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x MPD will be utilized to hold ECD and monitor pressure build up on connections. x 6-1/8” Hole Section A/C: x There are no wells with a CF < 1.0 21.12 At TD, CBU at drilling rate and max rotation. Pump sweeps if needed Page 53 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure x Monitor BU for increase in cuttings 21.13 Perform wiper trip to the 7” liner top. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If pulling tight, trip back to TD and begin backreaming operations. x If backreaming operations are commenced, continue backreaming to the shoe 21.14 CBU minimum two times at the 7” liner top at maximum rate and clean casing with high vis sweeps. 21.15 Trip back to TD and CBU 2x or until well cleans up, whichever comes later. 21.16 POOH and LD BHA. Rabbit DP that will be used to run liner. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 54 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 22.0 Run 4-1/2” Production Liner 22.1 Well control preparedness: In the event of an influx of formation fluids while running the injection liner, the following well control response procedure will be followed: x P/U & M/U the 5” safety joint (with 7” crossover installed on bottom, TIW valve in open position on top, 5” handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 7” liner. x Slack off and with 5” DP across the BOP, shut in ram or annular on 5” DP. Close TIW. x Proceed with well kill operations. 22.2 Upper VBRs to cover the 4-1/2” liner, 5” x 4” drillpipe used in this operation. 22.3 R/U 4-1/2” liner running equipment. x Ensure 4-1/2” 12.6# VT x XT50 crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck 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. 22.4 Run 4-1/2” production liner x Use Vam approved thread compound. Dope pin end only w/ paint brush. Wipe off excess. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x If liner length exceeds surface casing length, ensure centralizers are placed 1/jt for each joint outside of the surface shoe. x Obtain up and down weights of the liner before entering open hole. x See data sheet on the next page for MU torque for the 4-1/2” liner connections. x Run 2 centralizers per joint. One centralizer free floating with stop rings at 4’ and 10’ above pin. Second centralizer locked down 10’ below box. Centralize no higher than 50’ below 7” shoe. 4-1/2” 12.6/# 13Cr-80 VT – Make up Torque Casing OD Minimum Optimum Maximum 4-1/2” 4,000 ft-lbs 4,440 ft-lbs 4,880 ft-lbs Page 55 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 56 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 22.5 Ensure hanger/pkr will not be set in a 7” connection. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Plan is to place liner hanger with ~150’ overlap. Do not place liner hanger/packer across 9-5/8” connection. 22.6 Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 22.7 M/U Baker SLZXP liner top packer to 4-1/2” liner. Circulate 2 liner volumes to clear string and allow for PAL mix to set 22.8 Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 22.9 RIH with liner no faster than 30 ft/min – Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. x Ensure all 4” and 5” DP for the liner run has been drifted x Fill drill pipe on the fly. Monitor FL and if filling is required due to losses/surging. 22.10 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 22.11 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 RPM. If torque approaches make-up torque of liner, discontinue rotation. 22.12 Tag bottom and PU to position float shoe ~2’ off bottom. 22.13 Break circulation. Begin circulating at ~0.5 – 1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating for risk of prematurely setting liner hanger. Note all losses. Confirm all pressures with Baker. Page 57 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 23.0 Cement 4-1/2” Production Liner 23.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 23.2 Document efficiency of all possible displacement pumps prior to cement job. 23.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 23.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 23.5 Fill surface cement lines with water and pressure test. 23.6 Pump remaining 60 bbls 12.5 ppg tuned spacer. 23.7 Cement volume based on annular volume + 40% open hole excess. Job will consist of tail slurry, TOC brought to top of liner. Estimated Total Cement Volume: Cement Slurry Design: Tail Slurry Density 15.8 lb/gal Yield 1.16 ft3/sk Mix Water 4.98 gal/sk Page 58 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 23.8 Drop drillpipe dart and displace with perf pill before swapping to drilling mud. If hole conditions allow – continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 23.9 Displace cement at max rate of 7 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 23.10 If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 23.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 23.12 Slack off 20K lbs on the SLZXP liner hanger/packer to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi to release the HRDE running tool Slack off total liner weight plus 30k to confirm hanger is set. 23.13 Bleed DP pressure to 0 psi and check floats. Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 23.14 PU to neutral weight, close BOP and test annulus to 1,500 psi for 5 minutes to confirm liner top packer is set. 23.15 Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, repeat setting process in 20.13. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting. 23.16 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top) 23.17 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 23.18 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. While cement returns will be challenging to observe, watch for them and record the estimated volume. Rotate & circulate to clear cmt from DP. Page 59 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 23.19 RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. 23.20 Pressure test casing and liner to 250 psi low / 4,000 psi high for 30 minutes. Do not test until cement has reached minimum 1,000 psi compressive strength. Note: Once running tool is LD, swap to the completion AFE. Page 60 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 24.0 Perforate 4-1/2” Liner 24.1 If not completed in the previous BOPE test, test annular, upper and lower VBRs with 2-7/8” test joint to 250psi low 4,000psi high for 5/5 minutes. 24.2 RU to run 2-7/8” perforating assembly per vendor procedure. x Initial plan is ~4,000’ of 2-7/8” PowerJet Omega (or equivalent) perforation guns will be needed. x Exact perforated intervals to be determined by as-drilled logs data. Depths to be determined and confirmed by Geo/OE/DE. x Include a contingency hydraulic ball-drop disconnect in assembly x Limit personnel on rig floor to those required to make up DPC guns. 24.3 RIH with the perforating assembly. Stop to take PU/SO weights at the top of the 7” and 4-1/2” liners. 24.4 Space out DPC assembly by tagging the landing collar and spacing out on the upstroke. 24.5 Perforate the well per vendor procedure x An electronic firing head will be used. Review and follow vendor procedures for arming and firing the DPC guns. 24.6 Immediately after confirming guns have fired, POOH while keeping the hole full to get guns above the top shot. x This is to minimize sticking issues from possible sanding x Flow check well and establish loss rate prior to POOH 24.7 POOH, keeping the hole filled with KWF. x Record loss rate x Flow check at the 4-1/2” liner top, 7” liner top, and before pulling BHA through the BOPE 24.8 POOH and LD perf gun assembly. Verify all shots have fired. x Hydraulic tongs may be used with no backup tongs to spin out guns during rig down to minimize trapped pressure issues. Page 61 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 25.0 Run Upper Completion/ Post Rig Work 24.9 RU to run 4-1/2” 12.6#, 13Cr-80 Vam Top tubing. x Ensure wear bushing is pulled. x Ensure 4-1/2”, 12.6#, Vam Top x 5” XT50 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 RU casing tools. x Record OD’s, ID’s, lengths, SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 24.10 PU, MU and RH with the following 4-1/2” completion jewelry (tally to be provided by Operations Engineer): x Torque Turn All Connections x Tubing Jewelry to include (top to bottom): x 1x SSSV x 6x GLMs (size and final number to be determined by OE) x 1x ‘X’ Nipple x 1x Production Packer x 1x ‘X’ Nipple x 1x ‘XN’ Nipple with RHC profile installed x 1x WLEG x Tubing is 4-1/2”, 12.6#, 13Cr-80, Vam Top 4-1/2” 12.6/# 13Cr-80 Vam Top – Make up Torque Casing OD Minimum Optimum Maximum 4-1/2” 4,000 ft-lbs 4,440 ft-lbs 4,880 ft-lbs Page 62 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 63 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 24.11 Space out the completion to land such that the 4-1/2” WLEG is inserted half-way into the PBR on the 4-1/2” production liner. Record PU and SO weights prior to picking up tubing hanger. 24.12 MU the tubing hanger and land same. Run in the lock-down screws and torque to spec. 24.13 Reverse circulate heated kill-weight brine. Circulate surface-to-surface at a maximum of 4 BPM with brine and inhibited brine as follows: x Clean brine within the tubing from WLEG to surface x Inhibited brine on the annular side from the shear valve depth to the WLEG x Clean brine on the annular side from surface down to the shear valve. x At the end of the above displacement, reverse circulate an additional 5 bbls clean brine x With the 5 bbls over displacement complete, spot the fluids back in place by pumping 5 bbls clean brine down the tubing. This is to clean the RHC-M plug face before dropping the ball & rod. 24.14 Drop the ball & rod to the RHC-M (roller stem is required due to the sail angle of the well). 24.15 Once ball & rod has landed, pressure up and set the packer. 24.16 Pressure test the tubing to 250 psi low, 4,000 psi high for 30 minutes. 24.17 Slowly bleed tubing pressure to 2,000 psi (confirm shear valve pressure) and test the IA to 250 psi low, 4,000 psi high for 30 minutes. 24.18 Hold pressure on the IA and bleed off the tubing pressure to shear the GLM valve. Confirm 2- way communication through the shear valve. 24.19 Install and pressure test TWC from above. 24.20 ND BOPE. NU the tubing head adapter and tree. 24.21 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 24.22 RU lubricator and pull TWC. 24.23 Freeze protect the wellbore. x Rig up to pump heated diesel down the IA, taking returns up the tubing up the tubing. Reverse 155 bbls heated diesel into the IA. Do not exceed 3bpm while circulating. x Shut in the IA. x Line up to U-tube from the IA to the tubing. x U-tube the diesel and freeze protect the tubing and IA to ~2,200’ MD. 24.24 After u-tube is complete, RU lubricator and install BPV. 24.25 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. Page 64 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 24.26 RDMO Parker 273 i. POST RIG WELL WORK (sundry to follow) 1. Slickline/Fullbore a. Pull BPV. b. Change out GLV per GL ENGR c. Pull B&R and RHC 2. Well Tie-In Page 65 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 26.0 Parker 273 Rig Diverter Schematic Page 66 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 27.0 Parker 273 Rig BOP Schematic Page 67 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 28.0 Wellhead Schematic See corrected wellhead schematic at end of PTD Page 68 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 29.0 Days Vs Depth Page 69 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 30.0 Formation Tops & Information Page 70 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 71 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 72 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Page 73 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 31.0 Anticipated Drilling Hazards 16” Hole Section: Lost Circulation 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. Gas Hydrates/Free Gas Gas hydrates have NOT been seen on NK Pad, nor the closest Drillsites (DS-L5 and DS-L3). Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. 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 RPM’s when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Well Specific A/C: x There are no wells with a clearance factor of <1.0 Wellbore stability (Faults): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. Page 74 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure H2S: DS-NK is an H2S location. Below are the most recent H2S values of monitored wells in the Ivishak Pool. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level NK-25 20 ppm 4/20/2012 #2 Closest SHL Well H2S Level NK-26A 84 ppm 6/15/2023 #1 Closest BHL Well H2S Level NK-42 76 ppm 2/26/2023 #2 Closest BHL Well H2S Level NK-22A 180 ppm 1/22/2023 Max. Recorded H2S on nearest Pad/Facility NK-21 1,580 ppm 6/25/2022 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. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 75 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 12-1/4” Hole Section: Hole Cleaning: Maintain rheology of mud system. Utilize sweeps to evaluate and maintain good hole cleaning (weighted, high-vis, and low-vis/high-vis tandem sweeps all have seen success, depending on hole angle). Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge as needed to control drilled solids. Monitor ECDs 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 of > 800 gpm Lost Circulation: 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. Faulting: Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. H2S: DS-NK is an H2S location. Below are the most recent H2S values of monitored wells in the Ivishak Pool. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level NK-25 20 ppm 4/20/2012 #2 Closest SHL Well H2S Level NK-26A 84 ppm 6/15/2023 #1 Closest BHL Well H2S Level NK-42 76 ppm 2/26/2023 #2 Closest BHL Well H2S Level NK-22A 180 ppm 1/22/2023 Max. Recorded H2S on nearest Pad/Facility NK-21 1,580 ppm 6/25/2022 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. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 76 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Abnormal Pressures and Temperatures: P Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Ugnu/West Sak Hardstreaks: Hard formations (which are not necessarily predictable) can be encountered resulting in damage to PDC cutters. Damage occurs due to high impact loading of the bit cutting structure when hard streaks are hit at high ROP. Follow the appropriate mitigation strategy of reducing rotary speed while maintaining WOB. Colville Breathing: This is associated with higher mud weights and higher ECD’s in the Colville mudstones. Monitor ECDs and mud properties. Fingerprint connections to confirm breathing and not a well control event. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. 12-1/4” Hole Section Specific AC: x There are no wells with a CF < 1.0 0.520 psi/ft predicted at 15,994' MD per geo prog. -A.Dewhurst 20NOV23 Page 77 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 8-1/2” x 9-7/8” Hole Section: Hole Cleaning: Maintain rheology of mud system. Utilize sweeps to evaluate and maintain good hole cleaning (weighted, high-vis, and low-vis/high-vis tandem sweeps all have seen success, depending on hole angle). Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge as needed to control drilled solids. Monitor ECDs 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. Reduce ROP (as opposed to flow rate) to control ECD. Maintain circulation rate of > 500 gpm Lost Circulation: 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. Faulting: No faults are forecasted to be crossed in this interval. Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. H2S: DS-NK is an H2S location. Below are the most recent H2S values of monitored wells in the Ivishak Pool. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level NK-25 20 ppm 4/20/2012 #2 Closest SHL Well H2S Level NK-26A 84 ppm 6/15/2023 #1 Closest BHL Well H2S Level NK-42 76 ppm 2/26/2023 #2 Closest BHL Well H2S Level NK-22A 180 ppm 1/22/2023 Max. Recorded H2S on nearest Pad/Facility NK-21 1,580 ppm 6/25/2022 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. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 78 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Colville Breathing: This is associated with higher mud weights and higher ECD’s in the Colville mudstones. Monitor ECDs and mud properties. Fingerprint connections to confirm breathing and not a well control event. Tuffs or “Shale Wall” (CM1): The top of the CM1 is lithologically similar to the shallower CM intervals, but contains some interbedded volcanic tuff beds. Tuffs are hard and abrasive, especially at the top of the interval. Reduce WOB and ROP to maximize bit and reamer life when drilling through the CM1. Formation Breakout (HRZ/Kingak instability): This is related to the fissile (finely laminated) nature of the formation in conjunction with higher pore pressure, which requires higher mud weight to maintain wellbore stability. If splintering cuttings are observed at surface, additional circulations and mud weight may be required. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. 8.5” x 9-7/8” Hole Section Specific AC: x There are no wells with a CF < 1.0. 0.545 psi/ft gradient predicted at 18,845' MD per geo prog. -A.Dewhurst 20NOV23 Page 79 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 6-1/8” Hole Section: Hole Cleaning: Maintain rheology of mud system. Utilize sweeps to evaluate and maintain good hole cleaning (weighted, high-vis, and low-vis/high-vis tandem sweeps all have seen success, depending on hole angle). Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge as needed to control drilled solids. Monitor ECDs 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. Reduce ROP (as opposed to flow rate) to control ECD. Maintain circulation rate of > 250 gpm Lost Circulation: 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. Faulting: There are 3 possible fault crossings in this interval (2 high probability and 1 low probability). All 3 faults have throws < 100’ and have a low lost circulation risk. Crossing faults, known or unknown, can result in drilling into unstable formations that may impact future drilling and liner runs. Talk with Geologist to ensure all known faults are identified and prepared for accordingly. H2S: DS-NK is an H2S location. Below are the most recent H2S values of monitored wells in the Ivishak Pool. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level NK-25 20 ppm 4/20/2012 #2 Closest SHL Well H2S Level NK-26A 84 ppm 6/15/2023 #1 Closest BHL Well H2S Level NK-42 76 ppm 2/26/2023 #2 Closest BHL Well H2S Level NK-22A 180 ppm 1/22/2023 Max. Recorded H2S on nearest Pad/Facility NK-21 1,580 ppm 6/25/2022 4. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 5. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Page 80 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 6. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Reservoir pressures are expected to be normal. Utilize MPD to mitigate any abnormal pressure seen. Shublik Breathing: This is associated with higher mud weights and higher ECD’s in the Shublik carbonates. This is different in comparison to the breathing potential in the Colville Mudstones in that the formation will take fluid, but release gas. If treated like a traditional influx, the subsequent weight-up will start the process over with more fluid being lost and then more gas being released. Circulating out the gas via driller’s method and monitor pressures to determine if this is a breathing event or if it is an influx. Zone 4 and Zone 3 Conglomerates; Zone 2 Hard Streaks: The top of the CM1 is lithologically similar to the shallower CM intervals, but contains some interbedded volcanic tuff beds. Tuffs are hard and abrasive, especially at the top of the interval. Reduce WOB and ROP to maximize bit and reamer life when drilling through the CM1. Formation Breakout (HRZ/Kingak instability): This is related to the fissile (finely laminated) nature of the formation in conjunction with higher pore pressure, which requires higher mud weight to maintain wellbore stability. If splintering cuttings are observed at surface, additional circulations and mud weight may be required. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. 6-1/8” Hole Section Specific AC: x There are no wells with a CF < 1.0. Page 81 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 32.0 Parker 273 Rig Layout Page 82 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 33.0 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. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 83 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 34.0 Parker 273 Rig Choke Manifold Schematic Page 84 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 35.0 Casing Design Page 85 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 36.0 12-1/4” Hole Section MASP Page 86 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 37.0 8-1/2” x 9-7/8” Hole Section MASP Page 87 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 38.0 6-1/8” Hole Section MASP $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $ $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $)$) $) $) $) $) $) $)$) $) $) $)$) $)$) $) $) $) $)$) $) $) $) $)$) $) $) $)$) $) ! ! ! !!!!!!! !!! !!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!! !!!!!!!!!!!!!!!!!!!! ! !! ! ! D $) DUCK IS UNIT MPI 2-30A DUCK IS UNIT MPI 2-56DUCK IS UNIT MPI 2-56A SAG DELTA 08 DUCK IS UNIT MPI 2-50 SAG DELTA 05 SAG DELTA 33-12-16 PRUDHOE BAY UN NIA NK-25 PRUDHOE BAY UN NIA NK-23 PRUDHOE BAY UN NIA NK-26 PRUDHOE BAY UN NIA NK-38 PRUDHOE BAY UN NIA NK-41A PRUDHOE BAY UN NIA NK-42 PRUDHOE BAY UN NIA NK-41 DIU 2-71-PROP L5-18 L5-24 NK-04 NK-05 NK-06 NK-12 NK-14B NK-15A NK-16 NK-18 NK-19 NK-19A NK-20 NK-20A NK-21 NK-22 NK-22A NK-23 NK-25 NK-26 NK-26A NK-38 NK-38A NK-41 NK-41A NK-42 NK-43 NK-62NK-62A NK-65 NK-65A SAGD-01 SAGD-02SAGD-02A SD-08 2-56 2-56A 2-56A 2-56A 2-30A 2-30A 2-30A 2-50 Duck Island Unit Prudhoe Bay Unit Sec. 20 Sec. 13 Sec. 16 Sec. 22 Sec. 24 Sec. 21 Sec. 15 Sec. 17 Sec. 33 Sec. 4Sec. 5 Sec. 27 Sec. 32 Sec. 8 Sec. 36 Sec. 3 Sec. 1 Sec. 25 Sec. 28 Sec. 29 Sec. 34 Sec. 12 Sec. 9 Sec. 10 Sec. 31 (591) Sec. 18 (583) Sec. 19 (585) Sec. 6 (593) Sec. 30 (588) Sec. 7 (596) U012N016E U011N015E U012N015E U011N016E DSNK ADL28338 ADL390314 ADL28320 ADL34635 ADL34625 ADL391381 ADL28337 ADL34630 ADL34634 NK-24_SHL NK-24_TPH NK-24_BHL Map Date: 2/9/2024 Prudhoe Bay Unit NK-24 wp19 Well E0 2,700 5,400Feet Legend NK_24_wp19 $)NK-24_BHL !NK-24_SHL D NK-24_TPH $)Other Bottom Holes (BHL) Other Well Paths Oil and Gas Unit Boundary Pad Footprint Raven PA AIO 31 CO 570 Do c u m e n t P a t h : O : \ A W S \ G I S \ P r o d u c t s \ A l a s k a \ N S \ W e l l s \ T R S _ D i s t a n c e \ m x d s \ 2 0 2 4 \ N o r t h S l o p e _ P B U _ N K - 2 4 _ w p 1 9 . m x d Page 88 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 39.0 Spider Plot (NAD 27) (Governmental Sections) Superseded by updated plat. -A.Dewhurst 09FEB24 Page 89 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 40.0 Surface Plat (As Built) (NAD 27) Page 90 Prudhoe Bay East NK-24 Sag Producer Drilling Procedure 6WDQGDUG3URSRVDO5HSRUW 1RYHPEHU 3ODQ1.ZS +LOFRUS1RUWK6ORSH//& 1LDNXN 1. 3ODQ1. 1. -1 2 5 0 0 12 5 0 25 0 0 37 5 0 50 0 0 62 5 0 75 0 0 87 5 0 10 0 0 0 11 2 5 0 True Vertical Depth (2500 usft/in) 0 1 2 5 0 2 5 0 0 3 7 5 0 5 0 0 0 6 2 5 0 7 5 0 0 8 7 5 0 1 0 0 0 0 1 1 2 5 0 1 2 5 0 0 1 3 7 5 0 1 5 0 0 0 1 6 2 5 0 1 7 5 0 0 1 8 7 5 0 2 0 0 0 0 2 1 2 5 0 2 2 5 0 0 2 3 7 5 0 Ve r t i c a l S e c t i o n a t 6 0 . 7 6 ° ( 2 5 0 0 u s f t / i n ) NK - 2 4 w p 1 9 p o l y g o n NK - 2 4 w p 1 9 t g t 2 NK - 2 4 w p 1 9 t g t 3 NK - 2 4 w p 1 9 t g t 4 NK - 2 4 w p 1 9 t g t 5 NK - 2 4 w p 1 9 t g t 6 NK - 2 4 w p 1 9 t g t 7 NK - 2 4 w p 1 9 t g t 8 NK - 2 4 w p 1 9 t g t 1 13 3 / 8 " x 1 6 " 9 5 / 8 " x 1 2 1 / 4 " 7" x 8 1 / 2 " x 9 1 / 4 " 4 1 / 2 " x 6 1 / 4 " 500 1 0 0 0 1 5 0 0 2 0 0 0 2 5 0 0 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 16000 16500 17000 17500 1 8 0 0 0 1 8 5 0 0 1 9 0 0 0 1 9 5 0 0 2000020500 21000 21500 22000 22500 23000 23500 24000 24500 25000 25500 26000 26335 NK - 2 4 w p 1 9 St a r t D i r 1 . 5 º / 1 0 0 ' : 3 5 0 ' M D , 3 5 0 ' T V D St a r t D i r 2 º / 1 0 0 ' : 6 5 0 ' M D , 6 4 9 . 6 9 ' T V D St a r t D i r 3 º / 1 0 0 ' : 1 8 5 0 ' M D , 1 7 9 1 . 8 8 ' T V D En d D i r : 3 2 1 4 . 4 8 ' M D , 2 6 9 0 . 0 7 ' T V D Start Dir 3º/100' : 17268' M D, 8047.74'TVD End Dir : 18187.86' M D, 8585.85' TVD Start Dir 6º/100' : 19693' M D, 9738.85'TVD Fault #1 Start Dir 3º/100' : 20776.33' M D, 10047.42'TVD End Dir : 20793.43' M D, 10042.99' TVD Fault #2 Start Dir 6º/100' : 21273.07' M D, 9918.18'TVD Start Dir 2º/100' : 21491.25' M D, 9885.85'TVD End Dir : 21540.91' M D, 9884.55' TVD Fault #3 Start Dir 2º/100' : 21922.07' M D, 9877.85'TVD End Dir : 21927.83' M D, 9877.75' TVD Start Dir 3º/100' : 22720.47' M D, 9862.85'TVD End Dir : 23064.18' M D, 9873.87' TVD Start Dir 2º/100' : 23758.38' M D, 9931.29'TVD Start Dir 3º/100' : 23899.96' M D, 9940.85'TVD End Dir : 24159.67' M D, 9951.52' TVD Start Dir 3º/100' : 24978.39' M D, 9975.85'TVD End Dir : 25181.46' M D, 9974.58' TVD Total Depth : 26335.19' M D, 9925.85' TVD BP R F SV 6 SV 5 SV 4 SV 3 SV 2 SV 1 UG 4 UG 3 UG 1 TW S CM 3 CM 2 CM 1 HR Z TK U P TK N G TS G R TS H U TS A D TK V K Hi l c o r p N o r t h S l o p e , L L C 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 Er r o r S y s t e m : IS C W S A Sc a n M e t h o d : C l o s e s t A p p r o a c h 3 D Er r o r S u r f a c e : E l l i p s o i d S e p a r a t i o n Wa r n i n g M e t h o d : E r r o r R a t i o WE L L D E T A I L S : P l a n : N K - 2 4 19 . 5 0 +N / - S + E / - W No r t h i n g Ea 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 5 W SU R V E Y P R O G R A M Da t e : 2 0 2 3 - 1 0 - 2 7 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 T o o l 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g FO R M A T I O N T O P D E T A I L S TV D P a t h T V D s s P a t h M D P a t h F o r m a t i o n 18 6 5 . 8 5 1 8 0 0 . 0 0 1 9 3 5 . 1 3 B P R F 36 9 2 . 8 5 3 6 2 7 . 0 0 5 8 4 4 . 8 3 S V 6 37 9 8 . 8 5 3 7 3 3 . 0 0 6 1 2 2 . 8 8 S V 5 41 0 2 . 8 5 4 0 3 7 . 0 0 6 9 2 0 . 2 9 S V 4 44 2 0 . 8 5 4 3 5 5 . 0 0 7 7 5 4 . 4 3 S V 3 46 0 7 . 8 5 4 5 4 2 . 0 0 8 2 4 4 . 9 4 S V 2 50 5 2 . 8 5 4 9 8 7 . 0 0 9 4 1 2 . 2 0 S V 1 54 8 3 . 8 5 5 4 1 8 . 0 0 1 0 5 4 2 . 7 5 U G 4 60 3 0 . 8 5 5 9 6 5 . 0 0 1 1 9 7 7 . 5 6 U G 3 64 3 8 . 8 5 6 3 7 3 . 0 0 1 3 0 4 7 . 7 8 U G 1 73 8 6 . 8 5 7 3 2 1 . 0 0 1 5 5 3 4 . 4 4 T W S 75 6 1 . 8 5 7 4 9 6 . 0 0 1 5 9 9 3 . 4 8 C M 3 86 8 5 . 8 5 8 6 2 0 . 0 0 1 8 3 1 8 . 4 0 C M 2 90 8 8 . 8 5 9 0 2 3 . 0 0 1 8 8 4 4 . 4 8 C M 1 92 6 0 . 8 5 9 1 9 5 . 0 0 1 9 0 6 9 . 0 1 H R Z 94 3 9 . 8 5 9 3 7 4 . 0 0 1 9 3 0 2 . 6 8 T K U P 96 0 8 . 8 5 9 5 4 3 . 0 0 1 9 5 2 3 . 2 9 T K N G 97 3 8 . 8 5 9 6 7 3 . 0 0 1 9 6 9 3 . 0 0 T S G R 98 1 6 . 8 5 9 7 5 1 . 0 0 1 9 8 0 0 . 0 7 T S H U 98 8 1 . 8 5 9 8 1 6 . 0 0 1 9 9 0 0 . 0 5 T S A D 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Ca l c u l a t i o n M e t h o d : M i n i m u m C u r v a t u r e Pr o j e c t : Ni a k u k Si t e : NK We l l : Pl a n : N K - 2 4 We l l b o r e : NK - 2 4 De s i g n : NK - 2 4 w p 1 9 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 Na m e 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x 6 1 / 4 " 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 4 6 . 3 5 0 . 0 0 0 . 0 0 4 6 . 3 5 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 2 3 5 0 . 0 0 0 . 0 0 0 . 0 0 3 5 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 S t a r t D i r 1 . 5 º / 1 0 0 ' : 3 5 0 ' M D , 3 5 0 ' T V D 3 6 5 0 . 0 0 4 . 5 0 7 5 . 0 0 6 4 9 . 6 9 3 . 0 5 1 1 . 3 7 1 . 5 0 7 5 . 0 0 1 1 . 4 1 S t a r t D i r 2 º / 1 0 0 ' : 6 5 0 ' M D , 6 4 9 . 6 9 ' T V D 4 1 8 5 0 . 0 0 2 8 . 5 0 7 5 . 0 0 1 7 9 1 . 8 8 9 0 . 6 1 3 3 8 . 1 8 2 . 0 0 0 . 0 0 3 3 9 . 3 4 S t a r t D i r 3 º / 1 0 0 ' : 1 8 5 0 ' M D , 1 7 9 1 . 8 8 ' T V D 5 3 2 1 4 . 4 8 6 7 . 5 9 5 7 . 3 8 2 6 9 0 . 0 7 5 3 3 . 8 9 1 2 2 1 . 7 5 3 . 0 0 - 2 5 . 2 9 1 3 2 6 . 8 6 E n d D i r : 3 2 1 4 . 4 8 ' M D , 2 6 9 0 . 0 7 ' T V D 6 1 7 2 6 8 . 0 0 6 7 . 5 9 5 7 . 3 8 8 0 4 7 . 7 4 7 5 3 7 . 7 2 1 2 1 6 4 . 4 8 0 . 0 0 0 . 0 0 1 4 2 9 6 . 4 8 S t a r t D i r 3 º / 10 0 ' : 1 7 2 6 8 ' M D , 8 0 4 7 . 7 4 ' T V D 7 1 8 1 8 7 . 8 6 4 0 . 0 0 5 8 . 1 1 8 5 8 5 . 8 5 7 9 3 0 . 7 4 1 2 7 8 5 . 6 7 3 . 0 0 1 7 8 . 9 9 1 5 03 0 . 5 1 N K - 2 4 w p 1 9 t g t 1 E n d D i r : 1 8 1 8 7 . 8 6 ' M D , 8 5 8 5 . 8 5 ' T V D 8 1 9 6 9 3 . 0 0 4 0 . 0 0 5 8 . 1 1 9 7 3 8 . 8 5 8 4 4 1 . 8 6 1 3 6 0 7 . 1 3 0 . 0 0 0 . 0 0 1 5 9 9 6 . 9 6 N K - 2 4 w p 1 9 t g t 2 S t a r t D i r 6 º / 1 0 0 ' : 1 9 6 9 3 ' M D , 9 7 3 8 . 8 5 ' T V D 9 2 0 7 7 6 . 3 3 1 0 5 . 0 0 5 8 . 1 1 1 0 0 4 7 . 4 2 8 9 5 8 . 8 8 1 4 4 3 8 . 0 8 6 . 0 0 0 . 0 0 1 6 9 7 4 . 5 9 S t a r t D i r 3 º / 1 0 0 ' : 2 0 7 7 6 . 3 3 ' M D , 10 0 4 7 . 4 2 ' T V D 10 2 0 7 9 3 . 4 3 1 0 5 . 0 8 5 8 . 6 3 1 0 0 4 2 . 9 9 8 9 6 7 . 5 4 1 4 4 5 2 . 1 4 3 . 0 0 8 0 . 7 3 1 6 9 9 1 . 0 8 E n d D i r : 20 7 9 3 . 4 3 ' M D , 1 0 0 4 2 . 9 9 ' T V D 1 1 2 1 2 7 3 . 0 7 1 0 5 . 0 8 5 8 . 6 3 9 9 1 8 . 1 8 9 2 0 8 . 5 9 1 4 8 4 7 . 5 9 0 . 0 0 0 . 0 0 1 7 4 5 3 . 8 9 S t a r t D i r 6 º / 1 0 0 ' : 2 1 2 7 3 . 0 7 ' M D , 99 1 8 . 1 8 ' T V D 12 2 1 4 9 1 . 2 5 9 2 . 0 0 5 8 . 1 5 9 8 8 5 . 8 5 9 3 2 1 . 4 4 1 5 0 3 0 . 9 3 6 . 0 0 - 1 7 7 . 8 6 1 7 6 6 9 . 0 0 N K - 2 4 w p 1 9 t g t 3 S t a r t D i r 2 º / 1 0 0 ' : 2 1 4 9 1 . 2 5 ' M D , 98 8 5 . 8 5 ' T V D 13 2 1 5 4 0 . 9 1 9 1 . 0 1 5 8 . 1 5 9 8 8 4 . 5 5 9 3 4 7 . 6 4 1 5 0 7 3 . 1 0 2 . 0 0 1 7 9 . 7 4 1 7 7 1 8 . 5 9 E n d D i r : 21 5 4 0 . 9 1 ' M D , 9 8 8 4 . 5 5 ' T V D 14 2 1 9 2 2 . 0 7 9 1 . 0 1 5 8 . 1 5 9 8 7 7 . 8 5 9 5 4 8 . 7 2 1 5 3 9 6 . 8 4 0 . 0 0 0 . 0 0 1 8 0 9 9 . 3 0 N K - 2 4 w p 1 9 t g t 4 S t a r t D i r 2 º / 1 0 0 ' : 21 9 2 2 . 0 7 ' M D , 9 8 7 7 . 8 5 ' T V D 15 2 1 9 2 7 . 8 3 9 1 . 0 8 5 8 . 2 5 9 8 7 7 . 7 5 9 5 5 1 . 7 5 1 5 4 0 1 . 7 3 2 . 0 0 5 2 . 5 4 1 8 1 0 5 . 0 5 E n d D i r : 2 1 9 2 7 . 8 3 ' M D , 9 87 7 . 7 5 ' T V D 16 2 2 7 2 0 . 4 7 9 1 . 0 8 5 8 . 2 5 9 8 6 2 . 8 5 9 9 6 8 . 8 2 1 6 0 7 5 . 6 0 0 . 0 0 0 . 0 0 1 8 8 9 6 . 7 9 N K - 2 4 w p 1 9 t g t 5 S t a r t D i r 3 º / 1 0 0 ' : 22 7 2 0 . 4 7 ' M D , 9 8 6 2 . 8 5 ' T V D 17 2 3 0 6 4 . 1 8 8 5 . 2 6 6 6 . 7 6 9 8 7 3 . 8 7 1 0 1 2 7 . 2 4 1 6 3 7 9 . 9 0 3 . 0 0 1 2 4 . 4 4 1 9 2 3 9 . 7 0 E n d D i r : 23 0 6 4 . 1 8 ' M D , 9 8 7 3 . 8 7 ' T V D 18 2 3 7 5 8 . 3 8 8 5 . 2 6 6 6 . 7 6 9 9 3 1 . 2 9 1 0 4 0 0 . 1 8 1 70 1 5 . 6 1 0 . 0 0 0 . 0 0 19 9 2 7 . 7 2 S t a r t D i r 2 º / 10 0 ' : 2 3 7 5 8 . 3 8 ' M D , 9 9 3 1 . 2 9 ' T V D 19 2 3 8 9 9 . 9 6 8 7 . 0 0 6 9 . 0 0 9 9 4 0 . 8 5 1 0 4 5 3 . 3 5 1 7 1 4 6 . 4 6 2 . 0 0 5 2 . 0 4 2 0 0 6 7 . 8 7 N K - 2 4 w p 1 9 t g t 6 S t a r t D i r 3 º / 1 0 0 ' : 23 8 9 9 . 9 6 ' M D , 9 9 4 0 . 8 5 ' T V D 20 2 4 1 5 9 . 6 7 8 8 . 3 0 7 6 . 6 9 9 9 5 1 . 5 2 1 0 5 2 9 . 8 3 1 7 3 9 4 . 2 2 3 . 0 0 8 0 . 5 9 2 0 3 2 1 . 4 2 E n d D i r : 2 4 1 5 9 . 6 7 ' M D , 9 9 5 1 . 5 2 ' T V D 21 2 4 9 7 8 . 3 9 8 8 . 3 0 7 6 . 6 9 9 9 7 5 . 8 5 1 0 7 1 8 . 2 4 1 8 1 9 0 . 5 9 0 . 0 0 0 . 0 0 2 1 1 0 8 . 3 3 N K - 2 4 w p 1 9 t g t 7 S t a r t D i r 3 º / 1 0 0 ' : 2 4 9 7 8 . 3 9 ' M D , 9 97 5 . 8 5 ' T V D 22 2 5 1 8 1 . 4 6 9 2 . 4 2 8 1 . 1 7 9 9 7 4 . 5 8 1 0 7 5 7 . 2 0 1 8 3 8 9 . 7 8 3 . 0 0 4 7 . 4 2 2 1 3 0 1 . 1 7 E n d D i r : 2 51 8 1 . 4 6 ' M D , 9 9 7 4 . 5 8 ' T V D 23 2 6 3 3 5 . 1 9 9 2 . 4 2 8 1 . 1 7 9 9 2 5 . 8 5 1 0 9 3 4 . 0 5 1 9 5 2 8 . 8 4 0 . 0 0 0 . 0 0 2 2 3 8 1 . 4 5 N K - 2 4 w p 1 9 t g t 8 T o t a l D e p t h : 2 6 3 3 5 . 1 9 ' M D , 99 2 5 . 8 5 ' T V D 0 11 0 0 22 0 0 33 0 0 44 0 0 55 0 0 66 0 0 77 0 0 88 0 0 99 0 0 11 0 0 0 12 1 0 0 13 2 0 0 14 3 0 0 15 4 0 0 South(-)/North(+) (2200 usft/in) 0 1 1 0 0 2 2 0 0 3 3 0 0 4 4 0 0 5 5 0 0 6 6 0 0 7 7 0 0 8 8 0 0 9 9 0 0 1 1 0 0 0 1 2 1 0 0 1 3 2 0 0 1 4 3 0 0 1 5 4 0 0 1 6 5 0 0 1 7 6 0 0 1 8 7 0 0 1 9 8 0 0 2 0 9 0 0 We s t ( - ) / E a s t ( + ) ( 2 2 0 0 u s f t / i n ) NK - 2 4 w p 1 9 t g t 1 NK - 2 4 w p 1 9 t g t 8 NK - 2 4 w p 1 9 t g t 7 NK - 2 4 w p 1 9 t g t 6 NK - 2 4 w p 1 9 t g t 5 NK - 2 4 w p 1 9 t g t 4 NK - 2 4 w p 1 9 t g t 3 NK - 2 4 w p 1 9 t g t 2 NK - 2 4 w p 1 9 p o l y g o n 13 3 / 8 " x 1 6 " 9 5 / 8 " x 1 2 1 / 4 " 7" x 8 1 / 2 " x 9 1 / 4 " 4 1 / 2 " x 6 1 / 4 " 1 2 5 0 2 0 0 0 2 5 0 0 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 5 0 0 0 5 2 5 0 5 5 0 0 5 7 5 0 6 0 0 0 6 2 5 0 6 5 0 0 6 7 5 0 7 0 0 0 7 2 5 0 7 5 0 0 7 7 5 0 8 0 0 0 8 2 5 0 8 7 5 0 9 2 5 0 9 7 5 010000 9 9 2 6 NK - 2 4 w p 1 9 St a r t D i r 1 . 5 º / 1 0 0 ' : 3 5 0 ' M D , 3 5 0 ' T V D St a r t D i r 2 º / 1 0 0 ' : 6 5 0 ' M D , 6 4 9 . 6 9 ' T V D St a r t D i r 3 º / 1 0 0 ' : 1 8 5 0 ' M D , 1 7 9 1 . 8 8 ' T V D En d D i r : 3 2 1 4 . 4 8 ' M D , 2 6 9 0 . 0 7 ' T V D En d D i r : 1 8 1 8 7 . 8 6 ' M D , 8 5 8 5 . 8 5 ' T V D St a r t D i r 6 º / 1 0 0 ' : 1 9 6 9 3 ' M D , 9 7 3 8 . 8 5 ' T V D Fa u l t # 1 St a r t D i r 3 º / 1 0 0 ' : 2 0 7 7 6 . 3 3 ' M D , 1 0 0 4 7 . 4 2 ' T V D Fa u l t # 2 St a r t D i r 6 º / 1 0 0 ' : 2 1 2 7 3 . 0 7 ' M D , 9 9 1 8 . 1 8 ' T V D St a r t D i r 2 º / 1 0 0 ' : 2 1 4 9 1 . 2 5 ' M D , 9 8 8 5 . 8 5 ' T V D En d D i r : 2 1 5 4 0 . 9 1 ' M D , 9 8 8 4 . 5 5 ' T V D Fa u l t # 3 St a r t D i r 2 º / 1 0 0 ' : 2 1 9 2 2 . 0 7 ' M D , 9 8 7 7 . 8 5 ' T V D St a r t D i r 3 º / 1 0 0 ' : 2 2 7 2 0 . 4 7 ' M D , 9 8 6 2 . 8 5 ' T V D En d D i r : 2 3 0 6 4 . 1 8 ' M D , 9 8 7 3 . 8 7 ' T V D St a r t D i r 2 º / 1 0 0 ' : 2 3 7 5 8 . 3 8 ' M D , 9 9 3 1 . 2 9 ' T V D St a r t D i r 3 º / 1 0 0 ' : 2 3 8 9 9 . 9 6 ' M D , 9 9 4 0 . 8 5 ' T V D En d D i r : 2 4 1 5 9 . 6 7 ' M D , 9 9 5 1 . 5 2 ' T V D St a r t D i r 3 º / 1 0 0 ' : 2 4 9 7 8 . 3 9 ' M D , 9 9 7 5 . 8 5 ' T V D En d D i r : 2 5 1 8 1 . 4 6 ' M D , 9 9 7 4 . 5 8 ' T V D CA S I N G D E T A I L S TV D TV D S S M D Si z e N a m e 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 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eparation Factor 0 3 7 5 7 5 0 1 1 2 5 1 5 0 0 1 8 7 5 2 2 5 0 2 6 2 5 3 0 0 0 3 3 7 5 3 7 5 0 4 1 2 5 4 5 0 0 4 8 7 5 5 2 5 0 5 6 2 5 6 0 0 0 6 3 7 5 6 7 5 0 7 1 2 5 Me a s u r e d D e p t h ( 7 5 0 u s f t / i n ) NK - 2 6 NK - 2 3 NK - 2 5 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : N K - 2 4 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 19 . 5 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) 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 - 1 0 - 2 7 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 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + 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) 0 3 7 5 7 5 0 1 1 2 5 1 5 0 0 1 8 7 5 2 2 5 0 2 6 2 5 3 0 0 0 3 3 7 5 3 7 5 0 4 1 2 5 4 5 0 0 4 8 7 5 5 2 5 0 5 6 2 5 6 0 0 0 6 3 7 5 6 7 5 0 7 1 2 5 Me a s u r e d D e p t h ( 7 5 0 u s f t / i n ) NK - 1 8 NK - 4 1 NK - 2 1 NK - 2 6 NK - 2 3 NK - 2 0 NK - 2 5 NK - 4 3 NK - 1 9 NK - 2 2 a w p 0 5 NK - 2 2 NK - 4 2 NK - 6 5 NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 46 . 3 5 T o 2 6 3 3 5 . 1 9 Pr o j e c t : N i a k u k Si t e : N K We l l : P l a n : N K - 2 4 We l l b o r e : N K - 2 4 Pl a n : N K - 2 4 w p 1 9 Ni a k u k La d d e r / S . F . P l o t s 1 o f 4 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 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x 6 1 / 4 " &O H D U D Q F H 6 X P P D U \ $Q W L F R O O L V L R Q 5 H S R U W 1 R Y H P E H U +L O F R U S 1 R U W K 6 O R S H / / & 1L D N X N 1. 3O D Q 1 . 1. 1. Z S 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H :H O O & R R U G L Q D W H V 1 ( 1 : 'D W X P + H L J K W : ( / / # X V I W 2 U L J L Q D O : H O O ( O H Y 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K *H R G H W L F 6 F D O H ) D F W R U $ S S O L H G 9H U V L R Q % X L O G ( 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W */ 2 % $ / ) , / 7 ( 5 $ 3 3 / , ( ' $ O O Z H O O S D W K V Z L W K L Q R I U HI H U H Q F H 6F D Q 7 \ S H 6F D Q 7 \ S H 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 3 % 1 . $ 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . D Z S &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . D Z S (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . D Z S &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 3 % 1 . $ 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . % 1 . % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . % 1 . % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . % 1 . % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 1 . 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(O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S 6X U Y H \ W R R O S U R J U D P )U R P X V I W 7R X V I W 6X U Y H \ 3 O D Q 6 X U Y H \ 7 R R O 1 . Z S * < ' B 4 X H V W * : ' 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J (O O L S V H H U U R U W H U P V D U H F R U U H O D W H G D F U R V V V X U Y H \ W R R O W L H R Q S R LQ W V 6H S D U D W L R Q L V W K H D F W X D O G L V W D Q F H E H W Z H H Q H O O L S V R L G V &D O F X O D W H G H O O L S V H V L Q F R U S R U D W H V X U I D F H H U U R U V &O H D U D Q F H ) D F W R U ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ( O O L S V H 6 H S D U D W L R Q 'L V W D Q F H % H W Z H H Q F H Q W U H V L V W K H V W U D L J K W O L Q H G L V W D Q F H E H W Z H H Q ZH O O E R U H F H Q W U H V $O O V W D W L R Q F R R U G L Q D W H V Z H U H F D O F X O D W H G X V L Q J W K H 0 L Q L P X P & X U Y D WX U H P H W K R G 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 0 3 7 5 7 5 0 1 1 2 5 1 5 0 0 1 8 7 5 2 2 5 0 2 6 2 5 3 0 0 0 3 3 7 5 3 7 5 0 4 1 2 5 4 5 0 0 4 8 7 5 5 2 5 0 5 6 2 5 6 0 0 0 6 3 7 5 6 7 5 0 7 1 2 5 Me a s u r e d D e p t h ( 7 5 0 u s f t / i n ) NK - 2 6 NK - 2 3 NK - 2 5 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : N K - 2 4 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 19 . 5 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) 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 - 1 0 - 2 7 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 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + 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) 0 3 7 5 7 5 0 1 1 2 5 1 5 0 0 1 8 7 5 2 2 5 0 2 6 2 5 3 0 0 0 3 3 7 5 3 7 5 0 4 1 2 5 4 5 0 0 4 8 7 5 5 2 5 0 5 6 2 5 6 0 0 0 6 3 7 5 6 7 5 0 7 1 2 5 Me a s u r e d D e p t h ( 7 5 0 u s f t / i n ) NK - 1 8 NK - 4 1 NK - 2 1 NK - 2 6 NK - 2 3 NK - 2 0 NK - 2 5 NK - 4 3 NK - 1 9 NK - 2 2 a w p 0 5 NK - 2 2 NK - 4 2 NK - 6 5 NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 46 . 3 5 T o 2 6 3 3 5 . 1 9 Pr o j e c t : N i a k u k Si t e : N K We l l : P l a n : N K - 2 4 We l l b o r e : N K - 2 4 Pl a n : N K - 2 4 w p 1 9 Ni a k u k La d d e r / S . F . P l o t s 1 o f 4 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 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x 6 1 / 4 " &O H D U D Q F H 6 X P P D U \ $Q W L F R O O L V L R Q 5 H S R U W 1 R Y H P E H U +L O F R U S 1 R U W K 6 O R S H / / & 1L D N X N 1. 3O D Q 1 . 1. 1. Z S 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H :H O O & R R U G L Q D W H V 1 ( 1 : 'D W X P + H L J K W : ( / / # X V I W 2 U L J L Q D O : H O O ( O H Y 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K *H R G H W L F 6 F D O H ) D F W R U $ S S O L H G 9H U V L R Q % X L O G ( 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W */ 2 % $ / ) , / 7 ( 5 $ 3 3 / , ( ' $ O O Z H O O S D W K V Z L W K L Q R I U HI H U H Q F H 6F D Q 7 \ S H 6F D Q 7 \ S H 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J (Q G 6 D J ' H O W D 1. 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 3 % 1 . $ 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . D Z S &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 3 % 1 . $ 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 3 % 1 . $ 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . % 1 . % (O O L S V H 6 H S D U D W L R Q 3 D V V 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S &R P S D U L V R Q : H O O 1 D P H : H O O E R U H 1 D P H ' H V L J Q #0 H D V X U H G 'H S W K X V I W 0L Q L P X P 'L V W D Q F H X V I W (O O L S V H 6H S D U D W L R Q X V I W #0 H D V X U H G 'H S W K XV I W &O H D U D Q F H )D F W R U 6F D Q 5 D G L X V L V 8 Q O L P L W H G & O H D U D Q F H ) D F W R U F X W R I I L V 8 Q O L P L W H G 0 D [ ( O O L S V H 6 H S D U D W L R Q L V X V I W 6L W H 1 D P H 6F D Q 5 D Q J H W R X V I W 0 H D V X U H G ' H S W K &O R V H V W $ S S U R D F K ' 3 U R [ L P L W \ 6 F D Q R Q & X U U H Q W 6 X U Y H \ ' D W D + L J K VL G H 5 H I H U H Q F H 5H I H U H Q F H ' H V L J Q 1 . 3 O D Q 1 . 1 . 1 . Z S 0H D V X U H G 'H S W K X V I W 6X P P D U \ % D V H G R Q 0L Q L P X P 6H S D U D W L R Q : D U Q L Q J 1. 1 . % 1 . % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ &H Q W U H ' L V W D Q F H 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 1 . (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 1 . &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . $ 1 . $ (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . $ 1 . $ &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1. 1 . 3 % 1 . 3 % (O O L S V H 6 H S D U D W L R Q 3 D V V 1. 1 . 3 % 1 . 3 % &O H D U D Q F H ) D F W R U 3 D V V 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 1L D N X N +L O F R U S 1 R U W K 6 O R S H / / & $Q W L F R O O L V L R Q 5 H S R U W I R U 3 O D Q 1 . 1 . Z S 6X U Y H \ W R R O S U R J U D P )U R P X V I W 7R X V I W 6X U Y H \ 3 O D Q 6 X U Y H \ 7 R R O 1 . Z S * < ' B 4 X H V W * : ' 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J 1 . Z S B 0 : ' + 5 * 0 0 6 6 D J (O O L S V H H U U R U W H U P V D U H F R U U H O D W H G D F U R V V V X U Y H \ W R R O W L H R Q S R LQ W V 6H S D U D W L R Q L V W K H D F W X D O G L V W D Q F H E H W Z H H Q H O O L S V R L G V &D O F X O D W H G H O O L S V H V L Q F R U S R U D W H V X U I D F H H U U R U V &O H D U D Q F H ) D F W R U ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ( O O L S V H 6 H S D U D W L R Q 'L V W D Q F H % H W Z H H Q F H Q W U H V L V W K H V W U D L J K W O L Q H G L V W D Q F H E H W Z H H Q ZH O O E R U H F H Q W U H V $O O V W D W L R Q F R R U G L Q D W H V Z H U H F D O F X O D W H G X V L Q J W K H 0 L Q L P X P & X U Y D WX U H P H W K R G 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 72 0 0 7 8 0 0 8 4 0 0 9 0 0 0 9 6 0 0 1 0 2 0 0 1 0 8 0 0 1 14 0 0 1 2 0 0 0 1 26 0 0 1 3 2 0 0 1 3 8 0 0 1 4 4 0 0 1 5 0 0 0 1 5 6 0 0 1 6 2 0 0 1 6 8 0 0 1 7 4 0 0 1 8 0 0 0 Me a s u r e d D e p t h ( 1 2 0 0 u s f t / i n ) NK - 4 1 A No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : N K - 2 4 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 19 . 5 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) 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 - 1 0 - 2 7 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 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + 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) 72 0 0 7 8 0 0 8 4 0 0 9 0 0 0 9 6 0 0 1 0 2 0 0 1 0 8 0 0 1 14 0 0 1 2 0 0 0 1 26 0 0 1 3 2 0 0 1 3 8 0 0 1 4 4 0 0 1 5 0 0 0 1 5 6 0 0 1 6 2 0 0 1 6 8 0 0 1 7 4 0 0 1 8 0 0 0 Me a s u r e d D e p t h ( 1 2 0 0 u s f t / i n ) NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 46 . 3 5 T o 2 6 3 3 5 . 1 9 Pr o j e c t : N i a k u k Si t e : N K We l l : P l a n : N K - 2 4 We l l b o r e : N K - 2 4 Pl a n : N K - 2 4 w p 1 9 Ni a k u k La d d e r / S . F . P l o t s 2 o f 4 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 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x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Z S (O O L S V H H U U R U W H U P V D U H F R U U H O D W H G D F U R V V V X U Y H \ W R R O W L H R Q S R LQ W V 6H S D U D W L R Q L V W K H D F W X D O G L V W D Q F H E H W Z H H Q H O O L S V R L G V &D O F X O D W H G H O O L S V H V L Q F R U S R U D W H V X U I D F H H U U R U V &O H D U D Q F H ) D F W R U ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ' L V W D Q F H % H W Z H H Q 3 U R I L O H V ( O O L S V H 6 H S D U D W L R Q 'L V W D Q F H % H W Z H H Q F H Q W U H V L V W K H V W U D L J K W O L Q H G L V W D Q F H E H W Z H H Q ZH O O E R U H F H Q W U H V $O O V W D W L R Q F R R U G L Q D W H V Z H U H F D O F X O D W H G X V L Q J W K H 0 L Q L P X P & X U Y D WX U H P H W K R G 1 R Y H P E H U &2 0 3 $ 6 6 3D J H R I 0. 0 0 1. 0 0 2. 0 0 3. 0 0 4. 0 0 Separation Factor 18 1 0 0 1 8 2 0 0 1 8 3 0 0 1 8 4 0 0 1 8 5 0 0 1 8 6 0 0 1 8 7 0 0 1 8 8 0 0 1 8 9 0 0 1 9 0 0 0 1 9 1 0 0 1 9 2 0 0 1 9 3 0 0 1 9 4 0 0 1 9 5 0 0 1 9 6 0 0 1 9 7 0 0 1 9 8 0 0 1 9 9 0 0 2 0 0 0 0 Me a s u r e d D e p t h ( 2 0 0 u s f t / i n ) NK - 4 1 A No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : N K - 2 4 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 19 . 5 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) 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 - 1 0 - 2 7 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 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + 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) 18 1 0 0 1 8 2 0 0 1 8 3 0 0 1 8 4 0 0 1 8 5 0 0 1 8 6 0 0 1 8 7 0 0 1 8 8 0 0 1 8 9 0 0 1 9 0 0 0 1 9 1 0 0 1 9 2 0 0 1 9 3 0 0 1 9 4 0 0 1 9 5 0 0 1 9 6 0 0 1 9 7 0 0 1 9 8 0 0 1 9 9 0 0 2 0 0 0 0 Me a s u r e d D e p t h ( 2 0 0 u s f t / i n ) NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 46 . 3 5 T o 2 6 3 3 5 . 1 9 Pr o j e c t : N i a k u k Si t e : N K We l l : P l a n : N K - 2 4 We l l b o r e : N K - 2 4 Pl a n : N K - 2 4 w p 1 9 Ni a k u k La d d e r / S . F . P l o t s 3 o f 4 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 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x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eparation Factor 19 6 0 0 1 9 9 5 0 2 0 3 0 0 2 0 6 5 0 2 1 0 0 0 2 1 3 5 0 2 1 7 0 0 2 2 0 5 0 2 2 4 0 0 2 2 7 5 0 2 3 1 0 0 2 3 4 5 0 2 3 8 0 0 2 4 1 5 0 2 4 5 0 0 2 4 8 5 0 2 5 2 0 0 2 5 5 5 0 2 5 9 0 0 2 6 2 5 0 Me a s u r e d D e p t h ( 7 0 0 u s f t / i n ) NK - 4 1 A SD - 0 8 No - G o Z o n e - S t o p D r i l l i n g Co l l i s i o n A v o i d a n c e R e q u i r e d Co l l i s i o n R i s k P r o c e d u r e s R e q . NO E R R O R S WE L L D E T A I L S : P l a n : N K - 2 4 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 19 . 5 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 59 7 9 9 2 9 . 0 4 72 1 8 9 7 . 3 0 7 0 ° 2 0 ' 5 0 . 7 1 2 0 N 14 8 ° 1 1 ' 5 4 . 5 7 7 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 : N K - 2 4 , 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 : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) Me a s u r e d D e p t h R e f e r e n c e : WE L L @ 6 5 . 8 5 u s f t ( O r i g i n a l W e l l E l e v ) 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 - 1 0 - 2 7 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 46 . 3 5 1 1 0 0 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) G Y D _ Q u e s t G W D 11 0 0 . 0 0 6 8 6 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 68 6 8 . 0 0 1 8 1 8 8 . 0 0 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 18 1 8 8 . 0 0 1 9 7 0 1 . 0 0 N K - 2 4 w p1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + M S + S a g 19 7 0 1 . 0 0 26 3 3 5 . 1 9 N K - 2 4 w p 1 9 ( N K - 2 4 ) 3 _ M W D + H R G M + 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) 19 6 0 0 1 9 9 5 0 2 0 3 0 0 2 0 6 5 0 2 1 0 0 0 2 1 3 5 0 2 1 7 0 0 2 2 0 5 0 2 2 4 0 0 2 2 7 5 0 2 3 1 0 0 2 3 4 5 0 2 3 8 0 0 2 4 1 5 0 2 4 5 0 0 2 4 8 5 0 2 5 2 0 0 2 5 5 5 0 2 5 9 0 0 2 6 2 5 0 Me a s u r e d D e p t h ( 7 0 0 u s f t / i n ) NO G L O B A L F I L T E R : U s i n g u s e r d e f i n e d s e l e c t i o n & f i l t e r i n g c r i t e r i a 46 . 3 5 T o 2 6 3 3 5 . 1 9 Pr o j e c t : N i a k u k Si t e : N K We l l : P l a n : N K - 2 4 We l l b o r e : N K - 2 4 Pl a n : N K - 2 4 w p 1 9 Ni a k u k La d d e r / S . F . P l o t s 4 o f 4 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 40 8 2 . 9 0 4 0 1 7 . 0 5 6 8 6 7 . 9 6 1 3 - 3 / 8 1 3 3 / 8 " x 1 6 " 85 8 5 . 9 0 8 5 2 0 . 0 5 1 8 1 8 7 . 9 3 9 - 5 / 8 9 5 / 8 " x 1 2 1 / 4 " 97 4 4 . 9 0 9 6 7 9 . 0 5 1 9 7 0 0 . 9 2 7 7 " x 8 1 / 2 " x 9 1 / 4 " 99 2 5 . 8 5 9 8 6 0 . 0 0 2 6 3 3 5 . 1 9 4 - 1 / 2 4 1 / 2 " x 6 1 / 4 " Mel, Thecommentwastheretolettherigteamknowthatthereisn’tanurgencytoestablishinjecƟondueto thedistancebetween9Ͳ5/8”TOCandthe13Ͳ3/8”casingshoe.Thecementvolumepumpedwillnot makeittotheshoe,evenifwehavegaugehole. Asanexample,inPAVE1Ͳ1,plannedTOCofthe9Ͳ5/8”intermediatecementjobis~1,350’MDaway fromthe13Ͳ3/8”surfacecasingshoe.Theplannedopenholeexcessis40%forthecementjob.Ifweend upwithgaugehole,thiswouldputTOCinsidethesurfacecasingandwouldjeopardizetheOAfreeze protect.Thus,it’scalledoutaŌerbumpingtheplugtoinjectdowntheannulustoconĮrmapathfor freezeprotectandconĮrmthepathissƟllopenwithhourlyinjecƟonsunƟlthecementstartsbuilding compressivestrength. ThestatementcouldhavebeenwriƩenbeƩer.Itwillnowread: “InjecƟon immediately aŌer plug bump not necessary due to distance between planned TOC and surface casing shoe.” Thisway,itwillnotconŇictwiththefollowingbulletpointthattalksaboutestablishinginjecƟon. Regards, FrankVRoach DrillingEngineer Hilcorp Alaska, LLC 907.854.2321mobile 907.777.8413office From:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Sent:Monday,November27,202317:05 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]NKͲ24FreezeProtectQuestion Frank, Pleaseexplainthecomment“Note:InjecƟonaŌerpackoīsetandtestednotrequiredas……..andthe casingshoe.” MelRixse CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. SeniorPetroleumEngineer(PE) AlaskaOilandGasConservationCommission 907Ͳ793Ͳ1231Office 907Ͳ297Ͳ8474Cell Mel, Nosir.TheenƟreIntermediate2secƟonwillbeunderreamedto9Ͳ7/8”.SecƟonshouldread:“Drill8Ͳ 1/2”x9Ͳ7/8”holesecƟonfrom~18,650’tosecƟonTD…” Regards, FrankVRoach DrillingEngineer Hilcorp Alaska, LLC 907.854.2321mobile 907.777.8413office From:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Sent:Monday,November27,202317:16 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]NKͲ24holesizereduction? Frank, AreyoureducingholesizeforthissecƟon? MelRixse SeniorPetroleumEngineer(PE) AlaskaOilandGasConservationCommission 907Ͳ793Ͳ1231Office 907Ͳ297Ͳ8474Cell CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 1 Dewhurst, Andrew D (OGC) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Tuesday, February 13, 2024 08:51 To:Joseph Lastufka; Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] RE: PBU NK-24 (PTD unknown) updated map Andrew, Joeiscorrect.TherigdealtwithphaseweatherduringthemovetoDSͲ11andsubsequentlytooklongertorigup.That putusabout5daysbehindplanfromthestart,butwe’vebeenholdingthat5dayssincespud. Currently,weareforecasƟngtoreleasearoundMarch4. Regards, FrankVRoach DrillingEngineer Hilcorp Alaska, LLC 907.854.2321mobile 907.777.8413office From:JosephLastufka<Joseph.Lastufka@hilcorp.com> Sent:Monday,February12,202417:07 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>; Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG (OGC)<melvin.rixse@alaska.gov>;FrankRoach<Frank.Roach@hilcorp.com> Subject:RE:[EXTERNAL]RE:PBUNKͲ24(PTDunknown)updatedmap Andy, ThatlookspreƩyaccuratebutitalsomaybeanextraweek(~3/4orso)ͲI’llhavetodefertoFrankRoachthedrilling engineerforconĮrmaƟon.Oneofuswillgetbacktoyoutomorrow.Thanksforchecking! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Monday,February12,20244:48PM To:JosephLastufka<Joseph.Lastufka@hilcorp.com>;Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl, MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG(OGC) <melvin.rixse@alaska.gov> Subject:[EXTERNAL]RE:PBUNKͲ24(PTDunknown)updatedmap Youdon'toftengetemailfromfrank.roach@hilcorp.com.Learnwhythisisimportant CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 Joe, IwrotedownthatthePBUNKͲ24wasscheduledtospudonthe28thofthismonth.Isthatcorrect? Andy From:JosephLastufka<Joseph.Lastufka@hilcorp.com> Sent:Friday,February9,202410:18 To:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>; Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG (OGC)<melvin.rixse@alaska.gov> Cc:FrankRoach<Frank.Roach@hilcorp.com>;MichaelSchoetz<mschoetz@hilcorp.com> Subject:PBUNKͲ24(PTDunknown)updatedmap Hello, WantedtoprovideyouwithanupdatedmapforPBUNKͲ24submiƩedon11/17/23.LookslikethemapincludedNiakuk PoolwhentheyshouldhavebeenlabeledandshownasRavenPool. ForclariĮcaƟon,HilcorpisawarethattheproducƟveintervalasshowninthismapisoutsideofthecurrentRavenPool aīectedarea.Hilcorphasapendingexpansionrequestthatifgrantedwillencompasstheproposedwellbore. 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: 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 Dewhurst, Andrew D (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Friday, February 9, 2024 10:18 To:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Rixse, Melvin G (OGC) Cc:Frank Roach; Michael Schoetz Subject:PBU NK-24 (PTD unknown) updated map Attachments:NorthSlope_PBU_NK-24_wp19.pdf Follow Up Flag:Follow up Flag Status:Completed Hello, WantedtoprovideyouwithanupdatedmapforPBUNKͲ24submiƩedon11/17/23.LookslikethemapincludedNiakuk PoolwhentheyshouldhavebeenlabeledandshownasRavenPool. ForclariĮcaƟon,HilcorpisawarethattheproducƟveintervalasshowninthismapisoutsideofthecurrentRavenPool aīectedarea.Hilcorphasapendingexpansionrequestthatifgrantedwillencompasstheproposedwellbore. 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. 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 Dewhurst, Andrew D (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Thursday, December 7, 2023 16:31 To:AOGCC Permitting (CED sponsored) Cc:Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC) Subject:PBU 11-42 10-401 Permit to Drill Attachments:PBU 11-42 10-401.pdf; 11-42 wp10.txt; PBU 11-42 10-401.xml Hello, DuetoequipmentavailabilityissueswithtoolsplannedforNKͲ24,thishascontributedtothespuddateonNKͲ24being pushedlaterthanDecember13,andtomoveforwardwithPBU11Ͳ42.PleaseletmeknowifyouhaveanyquesƟons. 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. 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 Dewhurst, Andrew D (OGC) From:Frank Roach <frank.roach@hilcorp.com> Sent:Thursday, December 7, 2023 15:20 To:Dewhurst, Andrew D (OGC) Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Rixse, Melvin G (OGC); Joseph Lastufka Subject:RE: [EXTERNAL] RE: PBU NK-24 (PTD 223-108) - Questions Andy, Thankyouforthephonediscussionearlierthisweek.Toansweryourbulletpointsbelow: x We’vehadsomedownƟmeonPAVE1Ͳ1andhaverunintosomeequipmentavailabilityissueswithtools plannedforNKͲ24.ThesehavecontributedtothespuddateonNKͲ24beingpushedlaterthanDecember13. WewillwaitfortheupdatedpoolordertodrillNKͲ24. x PleaseseethebelowscreenshotandtableshowingdistancesfromtheNKͲ24wellpathtotheclosestpointof theDuckIslandUnitboundary.Theclosestourplancomesisat22,300’MD,wheretheunitboundaryis~652’ away. You don't often get email from frank.roach@hilcorp.com. Learn why this is important 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 LetmeknowifyouhaveanyaddiƟonalquesƟons. Regards, FrankVRoach DrillingEngineer Hilcorp Alaska, LLC 907.854.2321mobile 907.777.8413office From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Tuesday,December5,202308:13 To:FrankRoach<frank.roach@hilcorp.com>;JosephLastufka<Joseph.Lastufka@hilcorp.com> Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby, DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Subject:[EXTERNAL]RE:PBUNKͲ24(PTD223Ͳ108)ͲQuestions 3 Frank, Idon’tthinkIreceivedareplyonthisPTD.WouldyoupleasetakealookatthetwoquesƟonbelow? Thanks, Andy From:Dewhurst,AndrewD(OGC) Sent:Monday,November20,202315:41 To:FrankRoach<frank.roach@hilcorp.com> Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby, DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Subject:PBUNKͲ24(PTD223Ͳ108)ͲQuestions Frank, IamcompleƟngthereviewofthePBUNKͲ24andhavetwoquesƟons: x TheNKͲ24istargeƟngreservoiroutsideofthecurrentRavenOilPoolboundary.Meanwhile,Hilcorphasapplied fortheexpansionofthispool. ItispossiblethattheexpansionmaynotbeissuedbeforetheanƟcipatedspuddateofDecember13th.Inthe meanƟme,youcoulddrillthiswellunderstatewideregulaƟons(vs.poolrules).Fromthedrillingaspect,Idon’t seeanychangethiswouldmake.Doyouwishto(1)drillassoonaspossibleandproceedwiththepermitunder staterules,or(2)waitunƟltheoilpoolorderhasbeenupdated? x WouldyoupleaseprovidetheclosestdistancefromthewellboretotheDuckIslandUnitboundary(SEcornerof SecƟon21,T12N,R16E)? Thanks, Andy AndrewDewhurst SeniorPetroleumGeologist AlaskaOilandGasConservaƟonCommission 333W.7thAve,Anchorage,AK99501 andrew.dewhurst@alaska.gov Direct:(907)793Ͳ1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 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. PBU NK-24 223-108 SAG RIVER UNDEFINED OIL POOL X PRUDHOE BAY W E L L P E R M I T C H E C K L I S T Co m p a n y Hi l c o r p N o r t h S l o p e , L L C We l l N a m e : PR U D H O E B A Y U N R A V N K - 2 4 In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t 11 6 5 0 On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 1 0 8 0 PR U D H O E B A Y , S A G R I V U N D E F O I L - 6 4 0 1 6 5 NA 1 P e r m i t f e e a t t a c h e d Ye s AD L 0 3 4 6 3 0 , A D L 0 3 4 6 3 5 , A D L 0 3 4 6 3 4 , a n d A D L 0 3 9 0 3 1 4 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 No P R U D H O E B A Y , S A G R I V U N D E F O I L - 6 4 0 1 6 5 - g o v e r n e d b y S t a t e w i d e R e g s 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 In C m p t 5 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 W e l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 S u f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 I f d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 O p e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 O p e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 P e r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 P e r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 C a n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 W e l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 A l l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 P r e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 N o n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) Ye s 2 0 " 1 2 9 . 5 # X - 5 2 d r i v e n t o 8 0 ' 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 1 3 - 3 / 8 " L - 8 0 6 8 # t o S V 5 s h a l e 19 S u r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s Ye s 1 3 - 3 / 8 " f u l l y c e m e n t e d f r o m S V 5 t o s u r f a c e . T w o s t a g e c e m e n t j o b t h r o u g h p o r t e d c o l l a r . 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 9 - 5 / 8 " i n t e r m e d i a t e c a s i n g c e m e n t e d f r o m C M 3 ( s h o e d e p t h ) t o 1 5 , 0 0 0 ' M D 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 7 " i n t e r m e d i a t e l i n e r a n d 4 - 1 / 2 " p r o d u c t i o n l i n e r f u l l y c e m e n t e d . 22 C M T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 C a s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s P a r k e r 2 7 3 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 NA T h i s i s a g r a s s r o o t s w e l l . 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 Ye s 1 6 " D i v e r t e r f o r d r i l l i n g 1 6 " s u r f a c e h o l e 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 p l a n n e d t o b e o v e r b a l a n c e d t o p o r e p r e s s u r e . 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 s t a c k t e s t e d t o 4 0 0 0 p s i . 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 1 3 - 5 / 8 " 5 M 3 r a m s t a c k , 1 f l o w c r o s s , 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 1 5 M 3 - 1 / 8 " r e m o t e c h o k e , 1 5 M 3 - 1 / 8 m a n u a l c h o k e , 1 4 3 - 1 / 8 5 M G a t e v a l v e 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 Ye s M o n i t o r i n g w i l l b e r e q u i r e d . 33 I s p r e s e n c e o f H 2 S g a s p r o b a b l e NA T h i s i s a d e v e l o p m e n t w e l l . 34 M e c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No H 2 S m e a s u r e s r e q u i r e d . M a x r e a d i n g a t N K - 2 1 i s 1 , 5 8 0 p p m ( 2 0 2 2 ) 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 O v e r p r e s s u r e ( ~ 1 0 . 4 p p g E M W ) a n t i c i p a t e d i n S e a b e e , H R Z , a n d K i n g a k 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 D a t e Ap p r MG R Da t e 11 / 2 8 / 2 0 2 3 Ap p r AD D Da t e 11 / 1 7 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e Th i s w e l l t o b e d r i l l e d i n t o a r e a o u t s i d e o f c u r r e n t R a v e n O i l P o o l b o u n d a r y . A s s u c h , i t m u s t b e d r i l l e d u s i n g s t a t e r u l e s . O p er a t o r ha s a p p l i e d t o e x p a n d R a v e l O i l P o o l t o i n c l u d e t h i s l o c a t i o n . *& : JL C 2 / 1 3 / 2 0 2 4