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Home My WebLink About223-124Alaska 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 Chris Brillon Wells Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CRU CD5-330 ConocoPhillips Alaska, Inc. Permit to Drill Number: 223-124 Surface Location: 461’ FNL, 1934’ FWL, Sec. 18, T11N, R4E, UM Bottomhole Location: 338’ FNL, 2507’ FWL, Sec. 03, T10N, R3E, UM Dear Mr. Brillon: 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 March, 2024. Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.11 17:39:33 -08'00' 11 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5.Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 30,747 TVD: 7508 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property:14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 88.2 15. Distance to Nearest Well Open Surface: x- 348981 y- 5965759 Zone- 4 33.6 to Same Pool: 5720' to CD5-316 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 80 55 55 135 135 16" 13-3/8" 68# L80 H563 2567 55 55 2567 2203 19426 9-5/8" 47# T95 H563 19426 55 55 19426 6003 8-1/2" x 9-1/2"7-5/8" 29.7#L80 H563 4898.68 19276 5970 24175 7469 6-3/4" 4-1/2" 12.6# L80 H563 6747 24000 7460 30747 7508 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Chris Brillon Contact Email:tom.g.polasek@conocophillips.com Wells Engineering Manager Contact Phone: 907-263-3740 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3709 P.O. Box 100360 Anchorage, Alaska, 99510-0360 461 FNL, 1934 FWL, S18 T11N R4E, UM ASRC-NPR4, AA092347, ASRC-AA092344, AA081817, AA094165, AA094167 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips 59-52-180 CD5-330 922 FSL, 1945 FWL, S27 T11N R3E, UM LONS 09-009, LONS 09-009, LONS 09-009, LONS 09-009, LONS 09-009, LONS 09-009 338 FNL, 2507 FWL, S03 T10N R3E, UM 5032, 1280, 3122, 2525, 2560, 1916 GL / BF Elevation above MSL (ft): 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Casing Length Size Cement Volume MD Intermediate Surface Conductor/Structural Perforation Depth MD (ft): Perforation Depth TVD (ft): Liner Production If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Tom Polasek Commission Use Only See cover letter for other requirements. Colville River Unit Alpine Oil Pool 2/10/2024 2507' to AA087896 N/A 136 sx of 13.0 ppg Ext. Class G + 204 sx of 15.8 ppg Class G Cement to surface with 10 yds slurry 1259 sx of 11.0 ppg DeepCRETE + 330 sx of 15.8 ppg Class G 290 sx of 13.0 ppg Ext. Class G + 126 sx of 15.8 ppg Class G 2958 Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 2:23 pm, Dec 18, 2023 CRU X 12-1/4" Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig. Annular preventer test to 2500 psig Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT to the AOGCC as soon as available. Results of Sonic required to verify competent cement behind casing 11/2024 DSR-12/18/23 50-103-20874-00-00 Diverter variance granted per 20 AAC 25.035(h)(2) based on CPAI review of offset CD5 wells. -A.Dewhurst 08JAN24 223-124 A.Dewhurst 26JAN24 Provide field copy of well survey and INT1 hole section LWD logs to AOGCC with CPAI evaluation of any significant HC-zone when available. -A.Dewhurst 11JAN24 Alaska, Inc. VTL 2/14/2024 VTL 03/11/2024($8 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.03.11 17:39:12 -08'00' 03/11/24 03/11/24 ZhϱͲϯϯϬ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 2, 2023 Mr. Luke Lawrence Wells Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Re: Docket Number: OTH-21-018 CPAI Rotary Rig BOPE Test Frequency Dear Mr. Lawrence: By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope. OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25, 2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6, 2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of the CPAI-operated rigs during 2022 in considering the requested continuance.1 During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21- day intervals.2 CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions: - The pilot test duration is for ONE year from the approval date of this letter, subject to potential extension and expansion to include other CPAI operated rigs with at least 3 months of continuous rig work and AOGCC review of a rig’s BOPE system reliability. 1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of component failures during BOPE testing by replacing components that indicate suspect integrity before those components fail during testing. 2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre- determined time intervals while drilling specific sections in an ultra-extended reach well. Docket Number: OTH-21-018 March 2, 2023 Page 2 of 2 - CPAI must continue to implement the BWM program as approved by AOGCC. - Development drilling wells only are included in this approval. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. - 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to witness. If you have questions regarding this, please contact Jim Regg at (907) 793-1236. Sincerely, Brett W. Huber, Sr. Chair, Commissioner cc: Greg Hobbs (CPAI) Mike Kneale (CPAI) Victoria Loepp (AOGCC) AOGCC Inspectors (email) Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:09:23 -09'00' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Telephone 907-276-1215 December 18, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill CD5-330, Dear Sir or Madam, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Kuparuk C Sand - Single Lateral Producer from the CD5 drilling pad. The intended spud date for this well is February 10, 2024. It is intended that Doyon 26 be used to drill the well. CD5-330 will drill a 16" surface hole reaching total depth above the C30 Formation. 13-3/8" casing will be run and cemented to surface. The 19426 intermediate 1 hole section will be drillied to approximatly the top of the Albian 95 formation. 9-5/8” will be run and cemented in place with a 500’ or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. If an additional hydrocarbon zone is present, a 2 nd stage cement job will be performed to cover 250’ TVD above the interval. The 8-1/2" x 9-1/2" intermediate 2 hole section will be drilled to and landed in the Kuparuk C Sand. A 7-5/8" liner will be set and cemented from total depth to secure the shoe and cover 500’ MD or 250’ TVD, whichever is greater,above any hydrocarbon bearing zone.The 6-3/4" production interval will be drilled horizontally and geo-steered within the Kuparuk C sand. The well will be completed with a 4-1/2" liner including pre-perforated liner. The upper completion run from surface will include a production packer and GLM’s. It is requested that a variance from the diverter requirement under 20 AAC 25.035 (h) (2) is granted. At CD5 there has been 30+ wells drilled and there has been no significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a) 2. Proposed drilling program 3. Proposed drilling fluids program summary 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.005 (c) (4) (a-c) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) 7. Area of Review Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2.A description of the drilling fluids handling system. 3.Diagram of riser set up. If you have any questions or require further information, please contact Tom Polasek at 907-263-3740 (tom.g.polasek@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Regards, Tom Polasek Senior Drilling Engineer cc: CD5-330 Well File / Jenna Taylor ATO 1732 David Lee ATO 1552 Chris Brillon ATO 1548 Andy Mack Kuukpik Corp It is requested that a variance from the diverter requirement under 20 AAC 25.035 (h)(2)is granted. A Recommend granting variance. -A.Dewhurst 08JAN24 *Thirty-five wells have been drilled to date from the CD5 pad. Mud log from CD5-04 (215-072, 1,830' east) reports 29 unit max gas drilling to surface casing shoe at 2,191' TVD. Daily Ops Summaries from two nearest wells (CD5-316 and CD5-21; 820' and 1,000' away, respectively) report no shallow gas hazards encountered while drilling to surface casing shoe. Maximum gas recorded while drilling to surface casing point in CD5-21 is 45 units. -A.Dewhurst 26JAN24 12-1/4" CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 1 | 19 CD5-330 Well Plan Application for Permit to Drill Table of Contents 1. Well Name ............................................................................................................................................. 2 2. Location Summary ................................................................................................................................. 2 3. Proposed Drilling Program ..................................................................................................................... 5 4. Diverter and BOP Information ................................................................................................................ 6 5. MASP Calculations ................................................................................................................................. 6 6.Procedure for Conducting Formation Integrity Tests ............................................................................... 8 7. Casing and Cementing Program .............................................................................................................. 8 8. Drilling Fluid Program .......................................................................................................................... 10 9.Abnormally Pressured Formation Information ...................................................................................... 11 10. Seismic Analysis ................................................................................................................................... 11 11. Seabed Condition Analysis ................................................................................................................... 11 12. Evidence of Bonding ............................................................................................................................. 11 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ............................................................ 12 14. Drilling Hazards Summary .................................................................................................................... 13 15. Proposed Completion Schematic .......................................................................................................... 15 16. CD5-330 Intermediate 1 MPSP Review & Ram Configuration ................................................................ 16 17. Area of Review..................................................................................................................................... 19 CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 2 | 19 1. Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as CD5-330 2.Location Summary Requirements of 20 AAC 25.005(c)(2) Location at Surface 461 FNL, 1934 FWL, S18 T11N R4E, UM NAD27 Northing: 5965759.02 Easting: 348980.86 RKB Elevation 54.6’ AMSL Pad Elevation 33.6’ AMSL Top of Productive Horizon (Heel) 922 FSL, 1945 FWL, S27 T11N R3E, UM NAD27 Northing: 5951641.05 Easting: 332862.96 Measured Depth, RKB: 24175 True Vertical Depth, RKB: 7469 True Vertical Depth, SS: 7381 Total Depth (Toe) 338 FNL, 2507 FWL, S03 T10N R3E, UM NAD27 Northing: 333291.2 Easting: 5945090.48 Measured Depth, RKB: 30747‘ MD True Vertical Depth, RKB: 7508‘ TVD True Vertical Depth, SS: 7420‘ TVDss Please see attached well stick diagram for the current planned development of the pad. CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 3 | 19 Pad Layout CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 4 | 19 Well Plat CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 5 | 19 3. Proposed Drilling Program 1. MIRU Doyon 26 onto well over pre-installed 20” insulated conductor. Install diverter and function test. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16” hole to the surface casing point as per the directional plan, with DrillPlex. (LWD Program: GR/RES). 4. Run and cement new 13-3/8” surface casing to surface. Results of the cement operation will be submitted as soon as possible. 5. Install BOPE with the following equipment/configuration: x 18-5/8” Annular, Upper: 9-5/8” FBR, Middle: Blind Ram, Lower: 4-1/2” x 7-5/8” VBR x See section 16 for ram configuration justification. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program : GR/RES, DEN/NEU/IMAGE) 8. Chart casing pressure test to 3500 psi for 30 minutes. 9. Drill out shoe track and 20’ of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. Minimum LOT required to drill ahead is 12 ppg EMW. 11. Displace well to 9.8 ppg WBM. 12. Drill 12-1/4” hole to the casing point. 13. Circulate wellbore clean and POOH. 14. Run 9-5/8" Intermediate 1 casing to TD. 15. Pump single stage cement job to isolate the casing shoe by 250’ TVD above uppermost hydrocarbon bearing zone. Note that a shallower hydrocarbon bearing sand may be encountered, and a 2nd stage cement job will be completed if the one is detected while drilling. Results of the cement operation will be submitted as soon as possible. x There is potential for the presence of the Albian Sub 97 sand, which may be hydrocarbon bearing and require a second stage cement job from below the interval to 250’ TVD above the interval. The required equipment and cement plans are prepared if this becomes necessary. 16. Change upper 9-5/8" solid body rams to 4-1/2” x 7-5/8” VBR’s. Test BOPE to 250/3,500 psi. (24-48 hr. regulatory notice). 17. Pick up and run in hole with 8-1/2" x 9-1/2" drilling BHA to drill Intermediate 2 hole. SimOps, perform 9-5/8” annulus LOT with Ball mill and freeze protect. 18. Chart casing pressure test to 3500 psi for 30 minutes. 19. Drill out shoe track and 20’ of new hole. 20. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12 ppg EMW. There is potential for the presence of the Albian Sub 97 sand, which may be hydrocarbon bearing a (LWD Program: GR/RES) Albian Sub 97 was HC-bearing at adjacent CD5-316 (2017). -A.Dewhurst (LWD Program : GR/RES, DEN/NEU/IMAGE) CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 6 | 19 21. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 11.0 ppg NAF. 22. Drill 8-1/2" x 9-1/2"hole to section TD. 23. Circulate wellbore clean and POOH. 24. Pick up and run in hole with the 7-5/8" liner on 5.875” DP to section TD. 25. Circulate and condition mud in preparation for cementing. 26. Cement 7-5/8" liner to required TOC. Set liner top packer. POOH laying down 5.875” drill pipe. Results of the cement operation will be submitted as soon as possible. 27. Pick up 4.5” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice). 28. Pick up and RIH with 6-3/4" drilling assembly. 29. Displace well to FloPro WBM. Chart casing pressure test to 3500 psi for 30 minutes and record results. 30. Drill out and perform FIT to 13.5 ppg EMW maximum. Minimum acceptable leak-off for drilling ahead is 12 ppg EMW. 31. Drill 6-3/4" horizontal hole to section TD (LWD Program: GR/RES/DEN/NEU). 32. Circulate the hole clean and POOH. 33. Run 4-1/2” liner on 4.5” DP, set liner hanger and packer. POOH LD DP. 34. Run 4-1/2” tubing with production packer, DHG, GLMs and 2x landing nipples. Locate and space out tubing. Terminate TEC wire and land tubing hanger. 35. Pressure test hanger seals to 2500 psi. 36. Drop ball & rod, pressure up and set production packer. 37. Pressure test tubing and IA and shear SOV. 38. Install BPV. ND BOPE and install tubing head adapter. Pressure test adapter to 5000 psi. 39. Install 5k tree and test. 40. Remove BPV and freeze protect well. 41. Secure well and RDMO. 4. Diverter and BOP Information Requirements of 20 AAC 25.005(c)(3 & 7) Please reference BOP and diverter schematics on file for Doyon 26 5. MASP Calculations Requirements of 20 AAC 25.005(c)(4) (A) maximum downhole pressure and maximum potential surface pressure; Maximum Potential Surface Pressure (MPSP) is determined as the lesser of: Method 1: surface pressure at breakdown of the formation casing seat with a gas gradient to the surface Method 2: formation pore pressure at the next casing point less a gas gradient to the surface (LWD Program: GR/RES/DEN/NEU) CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 7 | 19 Method 1 Method 2 ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ Where: FG – Fracture gradient at the casing seat in lb/gal 0.052 – Conversion from lb/gal to psi/ft Gas Gradient – 0.1 psi/ft TVD – True Vertical Depth of casing seat in ft RKB Where: FPP – Formation Pore Pressure at the next casing point Gas Gradient – 0.1 psi/ft The following presents data used for calculation of Maximum Potential Surface Pressure (MPSP) while drilling: Section Hole Size Previous CSG Section TD MPSP psi MPSP MPSP Size MD TVD FG ppg Pore Pressure ppg | psi MD TVD Pore Pressure ppg | psi Method 1 psi Method 2 psi SURF 16"20" 135 135 10.9 8.6 60 2567 2203 8.6 985 63 63 765 INT1 19426 13-3/8" 2567 2203 16 8.6 985 19426 6003 8.6 2,685 1,613 1,613 2,085 INT2 8-1/2" x 9-1/2" 9-5/8" 19426 6003 15.3 8.6 2,685 24175 7469 9.5 3,689 2,942 4,176 2,942 PROD 6-3/4" 7-5/8" 24175 7469 12.5 9.5 3,689 30747 7508 9.5 3,709 2,958 4,108 2,958 (B) data on potential gas zones; The planned wellbore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 8 | 19 6.Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Drill out casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 7. Casing and Cementing Program Requirements of 20 AAC 25.005 (c)(6) Casing and Cementing Program OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 13-3/8" 16" 68# L80 H563 Cement to Surface 9-5/8" 12-1/4" 47# T95 H563 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 7-5/8" 8-1/2" x 9-1/2" 29.7# L80 H523 250’ TVD or 500’ MD, whichever is greater, above highest significant hydrocarbon bearing zone 4-1/2" 6-3/4" 12.6# L80 H563 Uncemented open hole liner with pre-perforations 13-3/8" Surface Casing run to 2567' MD/ 2203' TVD Cement Plan: Cement from 2567’ MD to 2067’ (500’ of tail) with DeepCRETE + Adds @ 15.8 ppg, and from 2067' to surface with 11.0 ppg DeepCRETE. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1367’ MD), zero excess in 20” conductor. Lead 431 bbls => 1259 sx of 11.0 ppg DeepCRETE + Add's @ 1.92 ft³/sk Tail 68 bbls => 330 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk 9-5/8" Intermediate Casing run to 19426' MD/ 6003' TVD Cement Plan: Primary cement job consists of 500 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be at 18926’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone INT1 shoe. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2nd stage cement job will be performed to isolate this zone. Assume 30% excess annular volume. Lead 46 bbls => 136 sx of 13.0 ppg Ext. Class G + Add's @ 1.9 ft³/sk Tail 42 bbls => 204 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk 7-5/8" Intermediate Liner run to 24175' MD/ 7469' TVD Cement Plan: Top of slurry is designed to be at 21642’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone Albian_Sub_93. Assume 30% + 20 Additional bbls excess annular volume. Lead 98 bbls => 290 sx of 13.0 ppg Ext. Class G + Add's @ 1.9 ft³/sk Tail 26 bbls => 126 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk t 21642’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone Albian_Sub_93. A CD 5 - 3 3 0 A O G C C 1 0 - 4 0 1 A P D 12 / 1 8 / 2 0 2 3 C D 5 - 3 3 0 A O G C C 1 0 - 4 0 1 A P D 9 | 1 9 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k Co n d u c t o r 0 ' - 8 0 ' 8 0 0 . 1 8 2 0 % 8 2 1 4 . 5 2 0 0 . 0 0 0 0 8 2 1 4 . 5 2 4 2 1 1 . 0 p p g D e e p C R E T E 1 . 9 2 Co n d u c t o r t o B a s e P e r m a f r o s t 8 0 ' - 13 6 7 ' 1 2 8 7 0 . 0 7 5 2 5 0 % 5 4 1 9 6 . 4 2 1 3 5 3 2 4 1 . 0 5 0 0 1 8 9 5 3 3 7 . 4 7 9 8 7 1 1 . 0 p p g D e e p C R E T E 1 . 9 2 Ba s e P e r m a f r o s t t o T o p o f T a i l 1 3 6 7 ' - 2 0 6 7 ' 6 9 9 0 . 0 7 5 5 0 % 2 9 4 5 2 . 3 9 1 4 7 2 6 . 2 0 0 0 4 4 1 7 8 . 5 9 2 3 0 1 1 . 0 p p g D e e p C R E T E 1 . 9 2 91 7 1 6 3 . 3 3 1 5 0 0 2 6 7 . 2 5 0 0 24 1 8 4 3 0 . 5 8 1 2 5 9 1 1 . 0 p p g D e e p C R E T E 1 . 9 2 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k To p o f T a i l t o S h o e 2 0 6 7 ' - 2 5 6 7 ' 5 0 0 0 . 0 7 5 5 0 % 2 1 0 3 7 . 4 5 1 0 5 1 8 . 7 3 0 0 3 1 5 5 6 . 1 8 2 7 2 1 5 . 8 p p g C l a s s G 1 . 1 6 Sh o e T r a c k 2 4 8 7 ' - 2 5 6 7 ' 8 0 0 . 1 5 0 0 % 6 7 1 1 . 9 8 0 0 . 0 0 0 0 6 7 1 1 . 9 8 5 8 1 5 . 8 p p g C l a s s G 1 . 1 6 27 8 4 9 . 4 3 1 0 5 1 8 . 7 3 0 0 38 3 6 8 . 1 6 3 3 0 1 5 . 8 p p g C l a s s G 1 . 1 6 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k Le a d 2 5 0 ' T V D ј I N T 1 t o T o p T a i l 1 8 2 9 4 ' - 1 8 9 2 6 ' 6 3 3 0 . 0 5 6 3 0 % 1 9 8 3 5 . 2 9 5 9 1 0 . 5 9 0 0 2 5 8 4 5 . 8 8 1 3 6 1 3 . 0 p p g E x t . C l a s s G 1 . 9 19 8 3 5 . 2 9 5 9 1 0 . 5 9 0 0 25 8 4 5 . 8 8 1 3 6 1 3 . 0 p p g E x t . C l a s s G 1 . 9 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k To p T a i l ( 5 0 0 ' T a i l C o v e r a g e ) t o S h o e 1 8 9 2 6 ' - 1 9 4 2 6 ' 5 0 0 0 . 0 5 6 3 0 % 1 5 7 2 7 . 8 9 4 7 8 . 3 7 0 0 2 0 4 3 6 . 2 6 1 7 5 1 5 . 8 p p g C l a s s G 1 . 1 6 Sh o e T r a c k 1 9 3 4 6 ' - 1 9 4 2 6 ' 8 0 0 . 0 7 3 0 % 3 3 5 . 8 6 0 0 . 0 0 0 0 3 3 5 . 8 6 2 8 1 5 . 8 p p g C l a s s G 1 . 1 6 18 9 3 3 . 7 5 4 7 8 . 3 7 0 0 23 6 4 2 . 1 1 2 0 4 1 5 . 8 p p g C l a s s G 1 . 1 6 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k Le a d 2 5 0 ' T V D ј A l b i a n _ S u b _ 9 3 t o T o p T a i l 2 1 6 4 2 ' - 2 3 6 7 5 ' 2 0 3 3 0 . 0 3 1 3 0 % 3 5 6 6 3 . 4 1 1 0 7 1 9 . 0 2 8 8 1 6 5 5 1 9 8 . 1 1 2 9 0 1 3 . 0 p p g E x t . C l a s s G 1 . 9 35 6 6 3 . 4 1 1 0 7 1 9 . 0 2 8 8 1 6 55 1 9 8 . 1 1 2 9 0 1 3 . 0 p p g E x t . C l a s s G 1 . 9 We i g h t Y i e l d ft 3 bb l s ft 3 bb l s ft 3 bb l s ft 3 bb l s p p g ft 3/ S a c k 9. 5 ' ' O H ( 4 0 0 ' ) 2 3 6 7 5 ' - 2 4 0 7 5 ' 4 0 0 0 . 0 3 1 3 0 % 7 0 1 2 . 4 8 2 1 3 . 7 4 1 7 3 1 0 8 1 9 . 3 0 9 3 1 5 . 8 p p g C l a s s G 1 . 1 6 8. 5 ' ' P i l o t H o l e ( 1 0 0 ' ) 2 4 0 7 5 ' - 2 4 1 7 5 ' 1 0 0 0 . 0 1 4 3 0 % 8 1 . 3 7 2 0 . 4 1 7 1 1 7 3 . 0 3 1 5 1 5 . 8 p p g C l a s s G 1 . 1 6 Sh o e T r a c k 2 4 0 9 5 ' - 2 4 1 7 5 ' 8 0 0 . 0 4 6 0 % 2 1 3 . 6 7 0 0 . 0 0 0 0 2 1 3 . 6 7 1 8 1 5 . 8 p p g C l a s s G 1 . 1 6 98 1 7 . 5 2 2 3 4 . 1 5 2 4 4 14 6 2 6 . 0 0 1 2 6 1 5 . 8 p p g C l a s s G 1 . 1 6 To t a l T a i l V o l u m e = 1 9 . 3 0 + 3 . 0 3 + 3 . 6 7 b b l s = 2 6 . 0 0 b b l s = > 1 2 6 s x o f 1 5 . 8 p p g C l a s s G @ 1 . 1 6 f t ³ / s k To t a l L e a d V o l u m e = 4 5 . 8 8 b b l s = > 1 3 6 s x o f 1 3 . 0 p p g E x t . C l a s s G @ 1 . 9 f t ³ / s k To t a l T a i l V o l u m e = 3 6 . 2 6 + 5 . 8 6 b b l s = 4 2 . 1 1 b b l s = > 2 0 4 s x o f 1 5 . 8 p p g C l a s s G @ 1 . 1 6 f t ³ / s k To t a l T a i l V o l u m e = 5 6 . 1 8 + 1 1 . 9 8 b b l s = 6 8 . 1 6 b b l s = > 3 3 0 s x o f 1 5 . 8 p p g C l a s s G @ 1 . 1 6 f t ³ / s k Fo o t a g e Vo l u m e Pl a c e m e n t Vo l u m e Ta i l Sa c k s B l e n d XS V o l u m e XS V o l u m e Ad d i t i o n a l b b l s To t a l V o l u m e bb l / f t Le a d Pl a c e m e n t bb l / f t % E x c e s s Fo o t a g e bb l / f t % E x c e s s Pl a c e m e n t Fo o t a g e Su r f a c e In t e r m e d i a t e 2 L i n e r In t e r m e d i a t e 1 Sa c k s B l e n d Ta i l Ta i l To t a l L e a d V o l u m e = 1 4 . 5 2 + 3 3 7 . 4 7 + 7 8 . 5 9 b b l s = 4 3 0 . 5 8 b b l s = > 1 , 2 5 9 s x o f 1 1 . 0 p p g D e e p C R E T E @ 1 . 9 2 f t ³ / s k Fo o t a g e Fo o t a g e Sa c k s B l e n d Pl a c e m e n t bb l / f t % E x c e s s Vo l u m e % E x c e s s Pl a c e m e n t bb l / f t % E x c e s s Vo l u m e Pl a c e m e n t Fo o t a g e b b l / f t % E x c e s s Vo l u m e To t a l L e a d V o l u m e = 9 8 . 1 1 b b l s = > 2 9 0 s x o f 1 3 . 0 p p g E x t . C l a s s G @ 1 . 9 f t ³ / s k XS V o l u m e To t a l V o l u m e Sa c k s B l e n d Ad d i t i o n a l b b l s To t a l V o l u m e Ad d i t i o n a l b b l s To t a l V o l u m e Bl e n d Sa c k s To t a l V o l u m e XS V o l u m e Ad d i t i o n a l b b l s To t a l V o l u m e Sa c k s B l e n d Vo l u m e XS V o l u m e Ad d i t i o n a l b b l s XS V o l u m e Ad d i t i o n a l b b l s CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 10 | 19 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate #1 Intermediate #2 Production Hole Size in 16" 12.25 8-1/2" x 9-1/2" 6-3/4" Casing Size in 13-3/8" 9-5/8" 7-5/8" 4-1/2" Density ppg 10.0 – 11.0 9.8 – 10.8 11.0 – 12.0 8.8 – 9.5 PV cP 30-80 10 40 15 YP lb./100 ft2 100-200 20 - 28 20 - 35 15 - 20 Funnel Viscosity s/qt 300 50 - 60 70 - 90 60 - 80 Initial Gels lb./100 ft2 50 10 14 10 10 Minute Gels lb./100 ft2 60 15 42 15 API Fluid Loss cc/30 min N.C. – 15.0 4 N/A 4 HPHT Fluid Loss cc/30 min n/a 8.0 – 12.0 5.0 10.0 pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5 Surface Hole: A freshwater drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 300 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.8-10.8 ppg and be prepared to add loss circulations materials as needed. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as needed) will all be important in maintaining wellbore stability. Intermediate #2: Versaclean OBM will be used in this section for shale stability purpose. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 11.0-12.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 8.8-9.5 ppg. MPD will be used. Back pressure may be used to keep the well dynamically balanced. Diagram of Doyon 26 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations. CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 11 | 19 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 12 | 19 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Incidental fluids developed from drilling operations on well CD5-330 will be disposed of into a permitted annulus on the CD5 pad or hauled to the Class 1 disposal well on CD1. The CD5-330 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to ~2000' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre-drill interpretations. Once CD5-330 has been drilled and completed, consideration may be given to permit this well for annular disposal. An application for Sundry Operations form 10-403 will then be filed. Annular disposal of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular disposal. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the C40 formation, above the C30. The maximum volume of fluids to be disposed of down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12 ppg for drilling fluid wastes. Using 12 ppg fluid and the rig’s specified maximum pumping pressure of 1500 psi for annular disposal, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure: [ (12 ppg) * (0.052) * (Surf. Shoe TVD) ] + 1500 psi [ (12 ppg) * (0.052) * (2203’) ] + 1500 psi Max Shoe Pressure = 2875 psi Pore Pressure: 985 psi Therefore Differential Pressure: 2875 – 985 = 1890 psi. The internal casing pressure is conservative since frictional losses while pumping has not been taken into consideration. The surface and intermediate casing strings exposed to annular disposal operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Weight (ppf) Grade Range Conn. Collapse (psi) 85% of Collapse (psi) Burst (psi) 85% of Burst (psi) 13-3/8" 68# L80 3 H563 2260 1921 5020 4267 9-5/8" 47# T95 3 H563 5090 4327 8150 4573 CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 13 | 19 14. Drilling Hazards Summary 16" Hole | 13-3/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running speeds 12.25 Hole | 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, MPD stripping practices Abnormal Pressure in Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow hazard study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 8-1/2" x 9-1/2" Hole | 7-5/8" Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-3/4" Hole | 4-1/2" Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers To be posted in Rig Floor Doghouse Prior to Spud CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 14 | 19 Well Proximity Risks: Directional drilling / collision avoidance information is provided in the following attachments. Drilling Area Risks: x Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. x Lower Shale Stability: HRZ/Kalubik in the Intermediate 2 hole section will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 15 | 19 15. Proposed Completion Schematic CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 16 | 19 16. CD5-330 Intermediate 1 MPSP Review & Ram Configuration Proposal Requesting approval to use a BOPE stack equipped with an annular preventer, fixed 9-5/8” solid body rams, blind/shear rams and, variable rams (4-1/2” x 7-5/8”) while drilling and running casing in the Intermediate 1 section of CD5-330. The Maximum Potential Surface Pressure (MPSP) is expected to be 1613 psi while drilling the 12-1/4” Intermediate 1 hole section with 5.875” drill pipe, satisfying 20 AAC 25.035.e.1.A. Please find the review below for more detail. 20 AAC 25.035.e.1.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sized to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Proposed Configuration: x Annular Preventer (iii) x 9-5/8” Solid Body Rams x Blind/Shear Rams (ii) x 4-1/2” x 7-5/8” VBR’s (i) CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 17 | 19 Pore Pressure Assessment A Normal Compaction Trend (NCT) is defined using the Bowers Method on a calibration well with little/no erosion and global constants as a starting point. Both source rock and non-source rock NCTs are then defined. For a given unit/zone, deviations slower than NCT indicate overpressure and allow calculation of its magnitude. The NCT for individual wells is defined by modifying Bowers parameters to account for specific erosion amounts. The maximum estimated reservoir pressure in the Intermediate 1 section is 8.6 ppg. Interval TVD TVD Max Note Top Base PPG Surface to Permafrost Base 0 1338 8.3 Hydrostatic Permafrost Base to C40 1338 1773 9 Hydrostatic C40 to C30 1773 2313 9.1 Offset Well DT/ Res Estimates C30 to C20 2313 2583 8.45 Hydrostatic C20 to C10 2583 2792 8.48 Hydrostatic C10 to K3 2792 3737 9.2 Offset Well DT/ Res Estimates K3 to Albian_97 (Qannik Sand if present) 3737 4261 8.5 Hydrostatic Albian 97 to Albian 96 (Sub 97 Sand if present) 4261 4823 8.6 Hydrostatic Albian 96 to Albian 95 4823 5940 8.6 Hydrostatic Albian 95 to Albian 94 5940 6443 8.6 Hydrostatic Albian 94 to Albian 93 6443 6773 8.6 Hydrostatic Albian 93 to HRZ (Sub 93 Sand if present) 6773 7081 8.6 Hydrostatic HRZ to Kuparuk C 7081 7468 11 Nuiqsut1 Estimates Kuparuk C 7468 7508 9.5 Res Estimates CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 18 | 19 Maximum Potential Surface Pressure Surface Casing Point: 2567' MD/ 2203' TVD Intermediate 1 Casing Point: 19426' MD/ 6003' TVD Max Anticipated Pore Pressure: 8.6 ppg | Albian Sub 97 (if present) Surface Casing Shoe FG: 16 ppg EMW | C40 Maximum Potential Surface Pressure (MPSP) is determined as the lesser of 1.) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2.) formation pore pressure at the next casing point less a gas gradient to the surface as follows: Method 1 Method 2 ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ ×ܸܶܦ) Where: FG – Fracture gradient at the casing seat in lb/gal 0.052 – Conversion from lb/gal to psi/ft Gas Gradient – 0.1 psi/ft TVD – True Vertical Depth of casing seat in ft RKB Where: FPP – Formation Pore Pressure at the next casing point MPSP CALCULATIONS: Method 1: MPSP = [(FG x 0.052) – Gas Gradient] x TVD MPSP = [(16 ppg EMW x 0.052) - 0.1 psi/ft] x 2203 TVD MPSP = 1613 psi Method 2: MPSP = FPP – (Gas Gradient x TVD) MPSP = (8.6 ppg x .052 x 6003‘ TVD) x (0.1 psi/ft x 6003’ TVD) MPSP = 2085 psi CD5-330 AOGCC 10-401 APD 12/18/2023 CD5-330 AOGCC 10-401 APD 19 | 19 17. Area of Review There are currently no wells within a quarter mile radius of the CD5-330 wellbore. 55 500 500 800 800 1100 1100 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 20000 20000 30750 CD5-330 wp07.1 Plan Summary 0 3 Do g l e g S e v e r i t y 0 4500 9000 13500 18000 22500 27000 31500 Measured Depth 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30.0 30.0 60.0 60.0 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 5565115165 215265315365415465515565 615 664 713 761 809 CD5-31 5565115165 215265315365415465515565 615 664 713 761 809 55101151201251301351401452502552603653 703 753 803 853 903 CD5-32X wp09 5564114164214264314363412461511559 CD5-27 wp06.1 5564114164214264314363413462512561610659707755 CD5-28 wp08 5568118168218268318368418468517567616666715764813862 91195910071055 CD5-29 wp02 5568118168218268319 369420470521572 622673723774824 874 923 972 1020 1067 1113 CD5-33 wp01 v3 (16B) 624674725775825 875 925 974 1022 CD5-34 wp02 0 4000 Tr u e V e r t i c a l D e p t h 0 3500 7000 10500 14000 17500 21000 24500 Vertical Section at 216.04° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 0 15 30 Ce n t r e t o C e n t r e S e p a r a t i o n 0 400 800 1200 1600 2000 2400 2800 Measured Depth DDI 7.539 SURVEY PROGRAM Date: 2017-05-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.60 1200.00 CD5-330 wp07.1 (CD5-330) SDI_URSA1_I4 1200.00 2560.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 1200.00 2560.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 2560.00 3560.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 2560.00 19420.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 19420.00 20420.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 19420.00 24170.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 24170.00 25170.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 24170.00 30748.15 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS Ground / 33.60 CASING DETAILS TVD MD Name 2203.20 2566.63 13-3/8" Surface Casing 6003.20 19426.32 9-5/8" Intermediate Casing 7468.50 24175.00 7-5/8" Intermediate Casing 7508.20 30748.14 4-1/2" Production Liner Mag Model & Date: BGGM2023 01-Mar-24 Magnetic North is 14.88° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.61° 57251.70nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 54.60 0.00 0.00 54.60 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 550.00 3.75 290.00 549.82 2.80 -7.69 1.50 290.00 2.26 Start Build 2.50 4 800.00 10.00 290.00 797.90 13.03 -35.79 2.50 0.00 10.53 Start DLS 3.50 TFO -42.25 5 1316.98 26.34 261.92 1288.20 12.26 -192.83 3.50 -42.25 103.55 Start 111.58 hold at 1316.98 MD 6 1428.56 26.34 261.92 1388.20 5.30 -241.85 0.00 0.00 138.02 Start DLS 3.50 TFO -42.25 7 2552.77 61.00 232.75 2196.48 -341.02 -906.44 3.50 -42.25 809.09 Start 13.86 hold at 2552.77 MD 8 2566.63 61.00 232.75 2203.20 -348.36 -916.09 0.00 0.00 820.70 Start 20.00 hold at 2566.63 MD 9 2586.63 61.00 232.75 2212.90 -358.95 -930.02 0.00 0.00 837.46 Start DLS 3.00 TFO -8.89 10 3134.09 77.25 230.19 2407.35 -676.98 -1328.39 3.00 -8.89 1329.01 Start 18010.23 hold at 3134.09 MD 1121144.31 77.25 230.19 6382.38 -11924.60 -14821.29 0.00 0.0018362.74 Start DLS 2.50 TFO -127.35 12 22832.88 55.88 190.00 7073.93 -13198.31 -15611.24 2.50 -127.3519857.42 Start Build 2.50 13 24157.88 89.00 190.00 7468.20 -14425.10 -15827.56 2.50 0.00 20976.65 CD5-30 T01 (Sun 5) 062421 Start 20.00 hold at 24157.88 MD 14 24177.88 89.00 190.00 7468.55 -14444.79 -15831.03 0.00 0.0020994.61 Start DLS 2.50 TFO -87.59 15 24804.27 89.69 174.35 7475.77 -15068.74 -15854.74 2.50 -87.59 21513.07 Start 5943.88 hold at 24804.27 MD 16 30748.15 89.69 174.35 7508.20 -20983.70 -15270.00 0.00 0.00 25951.66 TD at 30748.15 FORMATION TOP DETAILS TVDPath Formation 1333.20 Base Perm 2313.20 C30 2792.20 C10 3737.20 K-3 3988.20 K-2 4014.20 K-2 Base 4261.20 Alb 97 4345.20 Alb 97 (Minke) 4824.20 Alb 96 5940.20 Alb 95 6442.20 Alb 94 6773.20 Alb 93 7081.20 FSC / HRZ 7320.20 Kalubik 7467.70 Top Kup C By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 54.6+33.6 @ 88.20usft (D26) -3 0 0 0 0 30 0 0 60 0 0 90 0 0 12 0 0 0 True Vertical Depth 0 3 0 0 0 6 0 0 0 9 0 0 0 1 2 0 0 0 1 5 0 0 0 1 8 0 0 0 2 1 0 0 0 2 4 0 0 0 Ve r t i c a l S e c t i o n a t 2 1 6 . 0 4 ° 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 7- 5 / 8 " I n t e r m e d i a t e C a s i n g 4- 1 / 2 " P r o d u c t i o n L i n e r 1 0 0 0 2 0 0 0 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23 0 00 24000 25000 26000 27000 28000 29000 30000 30748 0° 3 0 °60 ° 77° 90° CD5-330 wp07.1 Ba s e P e r m C3 0 C1 0 K- 3 K- 2 K- 2 B a s e Al b 9 7 Al b 9 7 ( M i n k e ) Al b 9 6 Al b 9 5 Al b 9 4 Al b 9 3 FS C / H R Z Ka l u b i k To p K u p C CD 5 - 3 3 0 w p 0 7 . 1 9: 4 0 , N o v e m b e r 0 9 2 0 2 3 Se c t i o n V i e w -2 1 0 0 0 -1 7 5 0 0 -1 4 0 0 0 -1 0 5 0 0 -7 0 0 0 -3 5 0 0 0 South(-)/North(+) -2 1 0 0 0 - 1 7 5 0 0 - 1 4 0 0 0 - 1 0 5 0 0 - 7 0 0 0 - 3 5 0 0 0 3 5 0 0 7 0 0 0 We s t ( - ) / E a s t ( + ) CD 5 - 3 0 T 0 2 ( S u n 5 ) 0 6 2 4 2 1 CD 5 - 3 0 T 0 1 ( S u n 5 ) 0 6 2 4 2 1 13 - 3 / 8 " S u r f a c e C a s i n g 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 7- 5 / 8 " I n t e r m e d i a t e C a s i n g 4- 1 / 2 " P r o d u c t i o n L i n e r CD 5 - 3 3 0 w p 0 7 . 1 Wh i l e d r i l l i n g p r o d u c t i o n s e c t i o n , s t a y w i t h i n 1 0 0 f e e t l a t e r a l l y o f p l a n , u n l e s s n o t i f i e d o t h e r w i s e . 9: 5 1 , N o v e m b e r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e n t r e t o C e n t r e S e p a r a t i o n 0 450 900 1350 1800 2250 Partial Measured Depth CD5- 3 1 CD 5 - 3 2 X w p 0 9 CD 5 -2 7 w p 0 6 . 1 CD5 - 2 8 w p 0 8 CD 5 - 2 9 w p0 2 CD 5 - 3 3 w p 0 1 v 3 ( 1 6B) CD 5 - 3 4 w p 0 2 Equivalent Magnetic Distance CD5-330 wp07.1 Ladder View 0 150 300 Ce n t r e t o C e n t r e S e p a r a t i o n 0 2000 4000 6000 8000 10000 12000 Measured Depth CD 5 - 1 8 CD 5 - 1 8L1 CD 5 - 1 9 CD 5 - 1 9L 1 CD 5 - 2 0 CD 5 - 2 0L 1 CD 5- 2 1 CD 5 - 2 2 CD 5 - 2 3 CD 5 - 2 3L 1 CD 5 - 2 3L 1 -01 CD 5 - 2 4 CD 5 - 2 4L 1 CD 5 - 2 4L 1 P B 1 CD 5 - 2 5 CD 5 - 2 5L 1 CD 5-2 6 CD 5 - 2 6L 1 CD 5 - 3 1 CD 5 - 3 1P B 1 CD 5 - 3 2 X w p 0 9 CD 5 - 2 7 w p 0 6 . 1 CD5- 2 8 w p 0 8 CD 5- 2 9 w p 0 2 CD 5 - 3 3 w p01 v 3 ( 1 6 B ) CD5- 3 4 w p 0 2 CD5- 3 5 w p 0 1 v 3 ( S l i v e r2 ) Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 54.60 1200.00 CD5-330 wp07.1 (CD5-330) SDI_URSA1_I4 1200.00 2560.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 1200.00 2560.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 2560.00 3560.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 2560.0019420.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 19420.00 20420.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 19420.00 24170.00 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 24170.00 25170.00 CD5-330 wp07.1 (CD5-330) MWD OWSG 24170.0030748.15 CD5-330 wp07.1 (CD5-330) MWD+IFR2+SAG+MS 10:06, November 09 2023 CASING DETAILS TVD MD Name 2203.20 2566.63 13-3/8" Surface Casing 6003.20 19426.32 9-5/8" Intermediate Casing 7468.50 24175.00 7-5/8" Intermediate Casing 7508.20 30748.14 4-1/2" Production Liner 55 500 500 800 800 1100 1100 1500 1500 2000 2000 3000 3000 5000 5000 10000 10000 20000 20000 30750 CD5-330 wp07.1 TC View 30 30 60 60 90 90 120 120 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 55587898118138158178198218238258278298317336356375395414433453472491510530549568587605624643661680700 CD5-22 55587898118138158178198218238258278298317337 356376395415434453473492512531550570589608627646665684703722741760779800816834852870888905923 CD5-23 55587898118138158178198218238258278298317337 356376395415434453473492512531550570589608627646665684703722741760779800816834852870888905923 55587898118138158178198218238258278298317337 356376395415434453473492512531550570589608627646665684703722741760779800816834852870888905923 55587898118138158178198218238258278298317337356376395415434454473493512532550570589608627646665684700721740759777796814831849867885900 CD5-24 55557595115135155175195215235255275295315334354373393412432451471490509529548567586605624643662681700719737756775793811829847865882900 55557595115135155175195215235255275295315334354373393412432451471490509529548567586605624643662681700719737756775793811829847865882900 55587898118138158178198218238258278298318337357376396415435455474494513533552572591610629648667686705724743762781800818836854872890908925943961978 CD5-25 55587898118138158178198218238258278298318337357376396415435455474494513533552572591610629648667686705724743762781800818836854872890908925943961978 55557595115135155175195215235255275295 315335354374394413433453472492511531550570589609628647666685704723742761780800818836854872890908926944962980100010151032 CD5-26 55557595115135155175195215235255275295 31533535437439441343345347249251153155057058960962864766668570472374276178080081883685487289090892694496298010001015103255557595115135155 1751952152352552752953153353553753954154354554754955155355555755956156346546746937137327517717908098288478678869049239429609799971015103310511069108711051122 CD5-31 55557595115135155 1751952152352552752953153353553753954154354554754955155355555755956156346546746937137327517717908098288478678869049239429609799971015103310511069108711051122 556181101121141161181201221241261281301321341361381401422442462482502522542563583603623643663683703723743763783803823843863883903924944964984100410241044106410841104112411441164118412041224124312631283130313221341136113801399 CD5-32X wp09 557494114134154174194214234254274294314333353373392412432452471491511530550569588608627646665684703722740759777796814832850868886904922939957974992 CD5-27 wp06.1 55749411413415417419421423425427429431433435337339341343345247249251253255157159061063064966868870772774676578480382284185987889691593395197098810061024104110591076109411111128 CD5-28 wp08 55587898118138158178198218238258278298318338358378398418438458477497517537557577597616636656676695715735754774794813833852872 8919119309499699881007102610451064108311021121114011581177119612141232125112691287130513241343136213821401142014391457147414921510 CD5-29 wp02 55587898118138158178198218238258278298319339 359379400420440460481501521541 5615826026226436636837037237447647848048248448648849039239439629811001102010391058107610951113113211501168118612041221123912561273129013071324134213601378 CD5-33 wp01 v3 (16B) 1181381581781982182382582782983193393593804004204414614815015225425625836036246446646847057257457657858058258458658859059259459649841003102210421061108010981117113611541172119012081226124412611279129613131331 CD5-34 wp02 118138158178198218238258278298319339360380400421441462482502523543563584604625645665685705725745765785805825846866886906926946966985100510241044106310821101112011391157117611941213 CD5-35 wp01 v3 (Sliver2) SURVEY PROGRAM Date: 2017-05-10T00:00:00 Validated: Yes Version: From To Tool 54.60 1200.00 SDI_URSA1_I4 1200.00 2560.00 MWD OWSG 1200.00 2560.00 MWD+IFR2+SAG+MS 2560.00 3560.00 MWD OWSG 2560.00 19420.00 MWD+IFR2+SAG+MS 19420.00 20420.00 MWD OWSG 19420.00 24170.00 MWD+IFR2+SAG+MS 24170.00 25170.00 MWD OWSG 24170.00 30748.15 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2203.20 2566.63 13-3/8" Surface Casing 6003.20 19426.32 9-5/8" Intermediate Casing 7468.50 24175.00 7-5/8" Intermediate Casing 7508.20 30748.14 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 54.60 0.00 0.00 54.60 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 550.00 3.75 290.00 549.82 2.80 -7.69 1.50 290.00 2.26 Start Build 2.50 4 800.00 10.00 290.00 797.90 13.03 -35.79 2.50 0.00 10.53 Start DLS 3.50 TFO -42.25 5 1316.98 26.34 261.92 1288.20 12.26 -192.83 3.50 -42.25 103.55 Start 111.58 hold at 1316.98 MD 6 1428.56 26.34 261.92 1388.20 5.30 -241.85 0.00 0.00 138.02 Start DLS 3.50 TFO -42.25 7 2552.77 61.00 232.75 2196.48 -341.02 -906.44 3.50 -42.25 809.09 Start 13.86 hold at 2552.77 MD 8 2566.63 61.00 232.75 2203.20 -348.36 -916.09 0.00 0.00 820.70 Start 20.00 hold at 2566.63 MD 9 2586.63 61.00 232.75 2212.90 -358.95 -930.02 0.00 0.00 837.46 Start DLS 3.00 TFO -8.89 10 3134.09 77.25 230.19 2407.35 -676.98 -1328.39 3.00 -8.89 1329.01 Start 18010.23 hold at 3134.09 MD 11 21144.31 77.25 230.19 6382.38 -11924.60 -14821.29 0.00 0.0018362.74 Start DLS 2.50 TFO -127.35 12 22832.88 55.88 190.00 7073.93 -13198.31 -15611.24 2.50 -127.3519857.42 Start Build 2.50 13 24157.88 89.00 190.00 7468.20 -14425.10 -15827.56 2.50 0.00 20976.65 CD5-30 T01 (Sun 5) 062421 Start 20.00 hold at 24157.88 MD 14 24177.88 89.00 190.00 7468.55 -14444.79 -15831.03 0.00 0.0020994.61 Start DLS 2.50 TFO -87.59 15 24804.27 89.69 174.35 7475.77 -15068.74 -15854.74 2.50 -87.59 21513.07 Start 5943.88 hold at 24804.27 MD 16 30748.15 89.69 174.35 7508.20 -20983.70 -15270.00 0.00 0.00 25951.66 TD at 30748.15 CD 5 - 3 3 0 w p 0 7 . 1 AC F l i p b o o k SU R V E Y P R O G R A M De p t h F r o m D e p t h T o T o o l 54 . 6 0 1 2 0 0 . 0 0 S D I _ U R S A 1 _ I 4 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D O W S G 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D + I F R 2 + S A G + M S 25 6 0 . 0 0 3 5 6 0 . 0 0 M W D O W S G 25 6 0 . 0 0 1 9 4 2 0 . 0 0 M W D + I F R 2 + S A G + M S 19 4 2 0 . 0 0 2 0 4 2 0 . 0 0 M W D O W S G 19 4 2 0 . 0 0 2 4 1 7 0 . 0 0 M W D + I F R 2 + S A G + M S 24 1 7 0 . 0 0 2 5 1 7 0 . 0 0 M W D O W S G 24 1 7 0 . 0 0 3 0 7 4 8 . 1 5 M W D + I F R 2 + S A G + M S CA S I N G D E T A I L S TV D M D Na m e 22 0 3 . 2 0 25 6 6 . 6 3 13 - 3 / 8 " S u r f a c e C a s i n g 60 0 3 . 2 0 19 4 2 6 . 3 2 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 74 6 8 . 5 0 24 1 7 5 . 0 0 7- 5 / 8 " I n t e r m e d i a t e C a s i n g 75 0 8 . 2 0 30 7 4 8 . 1 4 4- 1 / 2 " P r o d u c t i o n L i n e r 5 510 1015 1520 2025 2530 3035 35 0 90 18 0 27 0 30 21 0 60 24 0 12 0 30 0 15 0 33 0 Tr a v e l l i n g C y l i n d e r A z i m u t h ( T F O + A Z I ) [ ° ] v s T r a v e l l i n g C y l i n d e r S e p a r a t i o n [ 1 0 u s f t / i n ] 5555759511 5 13 5 15 5 17 5 19 5 21 5 23 5 25 5 27 5 29 5 31 5 33 5 35 5 37 5 39 541 5 43 5 45 5 47 5 49 5 51 5 53 5 55 5 57 5 59 5 61 5 63 4 65 4 67 4 69 3 CD 5 - 3 1 5555759511 5 13 5 15 5 17 5 19 5 21 5 23 5 25 5 27 5 29 5 31 5 33 5 35 5 37 5 39 541 5 43 5 45 5 47 5 49 5 51 5 53 5 55 5 57 5 59 5 61 5 63 4 65 4 67 4 69 3 5558789811 8 13 8 15 8 17 8 19 8 21 8 23 8 25 8 27 8 29 8 31 8 33 8 35 8 37 8 39 841 843 845 847 749 751 753 755 7 57 7 59 7 61 6 63 6 65 6 67 6 69 5 71 5 73 5 75 4 77 4 CD 5 - 2 9 w p 0 2 78 4 80 4 82 4 84 4 86 4 88 4 90 3 92 3 94 3 96 2 98 1 10 0 1 10 2 0 CD 5 - 3 3 w p 0 1 v 3 ( 1 6 B ) 55 5 0 0 50 0 8 0 0 80 0 1 1 0 0 11 0 0 1 5 0 0 15 0 0 2 0 0 0 20 0 0 3 0 0 0 30 0 0 5 0 0 0 50 0 0 1 0 0 0 0 10 0 0 0 2 0 0 0 0 20 0 0 0 3 0 7 5 0 Fr o m C o l o u r T o M D 54 . 6 0 T o 2 6 0 0 . 0 0 MD A z i T F a c e 54 . 6 0 0 . 0 0 0 . 0 0 30 0 . 0 0 0 . 0 0 0 . 0 0 55 0 . 0 0 2 9 0 . 0 0 2 9 0 . 0 0 80 0 . 0 0 2 9 0 . 0 0 0 . 0 0 13 1 6 . 9 8 2 6 1 . 9 2 - 4 2 . 2 5 14 2 8 . 5 6 2 6 1 . 9 2 0 . 0 0 25 5 2 . 7 7 2 3 2 . 7 5 - 4 2 . 2 5 25 6 6 . 6 3 2 3 2 . 7 5 0 . 0 0 25 8 6 . 6 3 2 3 2 . 7 5 0 . 0 0 31 3 4 . 0 9 2 3 0 . 1 9 - 8 . 8 9 21 1 4 4 . 3 1 2 3 0 . 1 9 0 . 0 0 22 8 3 2 . 8 8 1 9 0 . 0 0 - 1 2 7 . 3 5 24 1 5 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 1 7 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 8 0 4 . 2 7 1 7 4 . 3 5 - 8 7 . 5 9 30 7 4 8 . 1 5 1 7 4 . 3 5 0 . 0 0 CD 5 - 3 3 0 w p 0 7 . 1 AC F l i p b o o k SU R V E Y P R O G R A M De p t h F r o m D e p t h T o T o o l 54 . 6 0 1 2 0 0 . 0 0 S D I _ U R S A 1 _ I 4 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D O W S G 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D + I F R 2 + S A G + M S 25 6 0 . 0 0 3 5 6 0 . 0 0 M W D O W S G 25 6 0 . 0 0 1 9 4 2 0 . 0 0 M W D + I F R 2 + S A G + M S 19 4 2 0 . 0 0 2 0 4 2 0 . 0 0 M W D O W S G 19 4 2 0 . 0 0 2 4 1 7 0 . 0 0 M W D + I F R 2 + S A G + M S 24 1 7 0 . 0 0 2 5 1 7 0 . 0 0 M W D O W S G 24 1 7 0 . 0 0 3 0 7 4 8 . 1 5 M W D + I F R 2 + S A G + M S CA S I N G D E T A I L S TV D M D Na m e 22 0 3 . 2 0 25 6 6 . 6 3 13 - 3 / 8 " S u r f a c e C a s i n g 60 0 3 . 2 0 19 4 2 6 . 3 2 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 74 6 8 . 5 0 24 1 7 5 . 0 0 7- 5 / 8 " I n t e r m e d i a t e C a s i n g 75 0 8 . 2 0 30 7 4 8 . 1 4 4- 1 / 2 " P r o d u c t i o n L i n e r 30 3060 6090 9012 0 12 0 15 0 15 0 18 0 18 0 21 0 21 0 0 90 18 0 27 0 30 21 0 60 24 0 12 0 30 0 15 0 33 0 Tr a v e l l i n g C y l i n d e r A z i m u t h ( T F O + A Z I ) [ ° ] v s T r a v e l l i n g C y l i n d e r S e p a r a t i o n [ 6 0 u s f t / i n ] 25 0 1 25 1 8 25 3 5 25 5 2 25 6 9 25 8 7 26 0 4 26 2 0 26 3 6 26 5 2 26 6 8 26 8 4 27 0 0 CD 5 - 3 2 X w p 0 9 55 5 0 0 50 0 8 0 0 80 0 1 1 0 0 11 0 0 1 5 0 0 15 0 0 2 0 0 0 20 0 0 3 0 0 0 30 0 0 5 0 0 0 50 0 0 1 0 0 0 0 10 0 0 0 2 0 0 0 0 20 0 0 0 3 0 7 5 0 Fr o m C o l o u r T o M D 25 0 0 . 0 0 T o 2 4 2 0 0 . 0 0 MD A z i T F a c e 54 . 6 0 0 . 0 0 0 . 0 0 30 0 . 0 0 0 . 0 0 0 . 0 0 55 0 . 0 0 2 9 0 . 0 0 2 9 0 . 0 0 80 0 . 0 0 2 9 0 . 0 0 0 . 0 0 13 1 6 . 9 8 2 6 1 . 9 2 - 4 2 . 2 5 14 2 8 . 5 6 2 6 1 . 9 2 0 . 0 0 25 5 2 . 7 7 2 3 2 . 7 5 - 4 2 . 2 5 25 6 6 . 6 3 2 3 2 . 7 5 0 . 0 0 25 8 6 . 6 3 2 3 2 . 7 5 0 . 0 0 31 3 4 . 0 9 2 3 0 . 1 9 - 8 . 8 9 21 1 4 4 . 3 1 2 3 0 . 1 9 0 . 0 0 22 8 3 2 . 8 8 1 9 0 . 0 0 - 1 2 7 . 3 5 24 1 5 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 1 7 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 8 0 4 . 2 7 1 7 4 . 3 5 - 8 7 . 5 9 30 7 4 8 . 1 5 1 7 4 . 3 5 0 . 0 0 CD 5 - 3 3 0 w p 0 7 . 1 AC F l i p b o o k SU R V E Y P R O G R A M De p t h F r o m D e p t h T o T o o l 54 . 6 0 1 2 0 0 . 0 0 S D I _ U R S A 1 _ I 4 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D O W S G 12 0 0 . 0 0 2 5 6 0 . 0 0 M W D + I F R 2 + S A G + M S 25 6 0 . 0 0 3 5 6 0 . 0 0 M W D O W S G 25 6 0 . 0 0 1 9 4 2 0 . 0 0 M W D + I F R 2 + S A G + M S 19 4 2 0 . 0 0 2 0 4 2 0 . 0 0 M W D O W S G 19 4 2 0 . 0 0 2 4 1 7 0 . 0 0 M W D + I F R 2 + S A G + M S 24 1 7 0 . 0 0 2 5 1 7 0 . 0 0 M W D O W S G 24 1 7 0 . 0 0 3 0 7 4 8 . 1 5 M W D + I F R 2 + S A G + M S CA S I N G D E T A I L S TV D M D Na m e 22 0 3 . 2 0 25 6 6 . 6 3 13 - 3 / 8 " S u r f a c e C a s i n g 60 0 3 . 2 0 19 4 2 6 . 3 2 9- 5 / 8 " I n t e r m e d i a t e C a s i n g 74 6 8 . 5 0 24 1 7 5 . 0 0 7- 5 / 8 " I n t e r m e d i a t e C a s i n g 75 0 8 . 2 0 30 7 4 8 . 1 4 4- 1 / 2 " P r o d u c t i o n L i n e r 60 6012 0 12 0 18 0 18 0 24 0 24 0 30 0 30 0 36 0 36 0 42 0 42 0 0 90 18 0 27 0 30 21 0 60 24 0 12 0 30 0 15 0 33 0 Tr a v e l l i n g C y l i n d e r A z i m u t h ( T F O + A Z I ) [ ° ] v s T r a v e l l i n g C y l i n d e r S e p a r a t i o n [ 1 2 0 u s f t / i n ] 55 5 0 0 50 0 8 0 0 80 0 1 1 0 0 11 0 0 1 5 0 0 15 0 0 2 0 0 0 20 0 0 3 0 0 0 30 0 0 5 0 0 0 50 0 0 1 0 0 0 0 10 0 0 0 2 0 0 0 0 20 0 0 0 3 0 7 5 0 Fr o m C o l o u r T o M D 24 1 0 0 . 0 0 T o 3 0 7 5 0 . 0 0 MD A z i T F a c e 54 . 6 0 0 . 0 0 0 . 0 0 30 0 . 0 0 0 . 0 0 0 . 0 0 55 0 . 0 0 2 9 0 . 0 0 2 9 0 . 0 0 80 0 . 0 0 2 9 0 . 0 0 0 . 0 0 13 1 6 . 9 8 2 6 1 . 9 2 - 4 2 . 2 5 14 2 8 . 5 6 2 6 1 . 9 2 0 . 0 0 25 5 2 . 7 7 2 3 2 . 7 5 - 4 2 . 2 5 25 6 6 . 6 3 2 3 2 . 7 5 0 . 0 0 25 8 6 . 6 3 2 3 2 . 7 5 0 . 0 0 31 3 4 . 0 9 2 3 0 . 1 9 - 8 . 8 9 21 1 4 4 . 3 1 2 3 0 . 1 9 0 . 0 0 22 8 3 2 . 8 8 1 9 0 . 0 0 - 1 2 7 . 3 5 24 1 5 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 1 7 7 . 8 8 1 9 0 . 0 0 0 . 0 0 24 8 0 4 . 2 7 1 7 4 . 3 5 - 8 7 . 5 9 30 7 4 8 . 1 5 1 7 4 . 3 5 0 . 0 0 CD 5 - 3 3 0 w p 0 7 . 1 Sp i d e r P l o t 10 : 2 4 , N o v e m b e r 0 9 2 0 2 3 T o 3 0 7 5 0 . 0 0 Northing (7500 usft/in) Ea s t i n g ( 7 5 0 0 u s f t / i n ) 4 04550556065 70 7 5 CD 5-01 40455055606570 CD5-0 2 40455055606570 CD 5-02A 40455055606570 CD 5 -03 404550556065 707 5 CD5-04 4 0455055606570 75 CD 5 -05 40455055 60 65 7 0 7 5 CD 5-0 6 40455055 60 65 7 0 7 5 CD5-06 L1 4045505560657 0 CD 5 -07 404550556065 70 7 5 CD 5 -08 40455055606570 CD5- 0 9 4 04550556065707 5 CD5- 10 404550556065 70 7 5 CD5-11 40455055606570 7 5 CD 5 -12 40 45 50 55 60 65 70 7 5 CD5-17 40 45 50 55 60 65 70 7 5 CD 5 - 1 7L1 40 45 50 55 60 65 7 0 7 5 CD 5-18 40 45 50 55 60 65 7 0 7 5 CD 5 - 18 L1 4 0 4 5 5 0 5 5 60 6 5 7 0 7 5 CD5-19 4 0 4 5 5 0 5 5 60 6 5 7 0 7 5 CD5 -19 L1 4 0 4 5 5 0 5560657 0 7 5 CD5-20 4 0 4 5 5 0 5560657 0 7 5 CD5- 2 0 L1 4 045505560657075 CD5 -21 4 0 4 5 5 0 5 5 6 0 6 5 7 0 CD5-22 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5-23 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD5-23L1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD5-23L1-01 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD5-24 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD5-24 L1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5-24 L1P B1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5-2 5 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5 - 25 L1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5 -26 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5 - 2 6L1 4 0 4 5 5 0 55 6 0 6570 7 5 CD5 -31 40 45 5 0 55 6 0 6570 7 5 CD5-31P B 1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 CD 5-3 1 3 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD5-31 3 P B 1 CD5-314 40 45 50 55 60 65 70 7 5 CD 5 - 3 14 X 4 0 4 5 50 55606570 CD5-3 154 0 4 5 50 556 0 6 5 7 075 CD 5 -31 5 P B 1 4 0 4 5 50 5 5 60 65 70 CD 5 -316 4 0 4 5 50 5 5 60 65 70 CD5- 31 6PB 1 4 0 45 CD 5 - 32 X w p09 4 0 4 5 5 0 5 5 60 6 57075 CD 5-90 4 0 4 5 5 0 5 5 60 6 57075 CD5-90 L 1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 CD5-92 4 0 45 5 0 55 6 0 6 5 7 0 7 5 CD5- 9 3 40 45 50 55 6 0 65 70 7 5 CD5-96 40 45 50 55 6 0 65 70 7 5 CD5-96 L1 4 0 4 5 50 55 606 5 7 0 7 5 CD 5 -98 4 0 4 5 50 55 606 5 7 0 7 5 CD 5-98 L 1 40 45 50 55 60 65 70 7 5 CD 5-99 40 45 50 55 60 65 70 75 CD 5-99A 40 45 50 55 60 65 70 75 CD 5-99 AL1 4 0 4 5 5 0 5 5 6 0 6 5 7 0 7 5 CD 5-27 w p06.1 404550556065707 5 CD 5 - 28 wp 0 8 4045 50 55 60 65707 5 CD 5 - 2 9 w p02 40 45 50 55 60 6570 7 5 CD 5 - 33 w p01 v3 (1 6 B) 40 45 50 5 5 6 0 65 70 7 5 CD 5 - 3 4 wp 0 2 40 45 50 55 60 65 70 75 CD 5 - 3 5 w p 0 1 v3 (Sli ver2 ) 40 45 50 55 60 65 70 7 5 CD 5-94 wp 06 40 45 50 55 60 65 70 7 5 CD 5-95 w p 02 40 45 50 55 60 65 70 7 5 CD 5-97 wp01 v3 ( 16A) 40 45 5 0 5 5 60 6570 7 5 CD 5 - 3 3 0 wp 0 7 .1 CD 5 - 3 3 0 w p 0 7 . 1 Sp i d e r P l o t 10 : 3 2 , N o v e m b e r 0 9 2 0 2 3 0 T o 3 0 7 5 0 . 0 0 Northing (2000 usft/in) Ea s t i n g ( 2 0 0 0 u s f t / i n ) 3 033 35 38 40 4 345 48 5 053 CD 5-01 3033353840CD 5 -02 3033353840CD 5 - 0 2 A 3033353840CD 5-0 3 3 0 3 3 3 5 3 8 40 43 4 5 4 8 5 0 53 5 5 58 CD5- 04 30 3 3 3 53840 43 45 4 8 50 5 355 58 60 CD 5 -05 3033353840434548505355586063 65 6 8 7 0 7 3 7 5 CD 5-06 3033353840434548505355586063 65 6 8 7 0 7 3 7 5 CD5-06 L1 3 03335384043454850535558606365687 0 7 3 CD 5 -07 303335384043454850535558606365 68 70 73 7 5 CD5- 0 8 3 033 3 5 384043 CD 5-0 9 3 033353840434548505355586063656870737 5 CD 5-1 0 303335384043454850535558606365 68 70 73 7 5 CD5-1 1 303335384043454850535558606365687073 7 5 CD 5 -12 30 33 35 38 40 43 45 48 50 CD5- 1 7 30 33 35 38 40 43 45 48 50 CD5-17 L 1 30 33 35 38 40 43 45 48 50 53 CD5- 18 30 33 35 38 40 43 45 48 50 53 CD 5 - 1 8L1 303335 38 4 0 4 3 4 5 48 5 0 5 3 5 5 5 8 60 6 3 6 5 6 8 CD5-19 303335 38 4 0 4 3 4 5 48 5 0 5 3 5 5 5 8 60 6 3 6 5 6 8CD 5 - 19 L 1 3 0 3 3 3 5 3 8 4 0 7 5 CD 5-20 3 0 3 3 3 5 3 8 4 0 7 5 CD 5 - 20 L1 30 33 3 5 3 8 40 43 4 5 4 8 5 0 53 5 5 58 60 63 65 68 70 7 3 75 CD 5-21 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 CD5-22 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 7 5 CD5-23 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 7 5 CD 5 - 2 3L1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 7 5 CD 5 - 23L1-01 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 CD5-24 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 CD 5 - 2 4L1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 CD5-24L1PB 1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 7 5 CD 5-25 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 7 0 7 3 7 5 CD 5 - 2 5L1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 CD 5-2 6 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 6 8 CD 5 - 2 6L1 30 33 35 3 8 4 0 43 45 48 50 CD 5-3 1 30 3 3 3 5 38 40 43 45 48 5 0 CD 5 - 3 1PB 1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 6 3 6 5 CD 5 -31 3 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 CD 5-31 3 P B 1 CD 5 -31 4 30 33 35 38 40 43 45 48 50 53 55 58 60 63 65 68 70 CD5-314X 3 0 3 3 35 3 8 4 0 43 4 5 4 8 50 5 3 55 58 60 63 65 68 70 CD 5 -31 5 3 0 3 3 35 3 8 4 0 43 4 5 4 8 50 5 3 55 5 8 6 0 6 3 6 5 CD 5 -31 5 P B 1 30 3 3 35 38 4 0 43 45 48 50 5 3 55 5 8 60 6 3 CD5- 3 16 30 3 3 35 38 4 0 43 45 48 50 5 3 55 5 8 60 63 CD5- 316P B 1 3033353840 434548 CD 5 - 32X w p 0 9 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 CD 5-90 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 CD5-90 L 1 3 0 3 3 3 5 3 8 4 0 43 4 5 4 8 5 0 5 3 5 5 5 8 CD5-92 3 0 3 3 3 5 3 8 40 43 45 48 5 0 5 3 55 5 8 6 0 CD5-93 30 33 35 38 40 43 45 48 50 53 55 58 60 6 3 6568 70 7 3 7 5 CD 5 -96 30 33 35 38 40 43 45 48 50 53 55 58 60 6 3 6568 70 7 3 7 5 CD 5 - 9 6L1 3 0 3 3353 8 4 0 CD5-98 3 0 3 3353 8 4 0 7 5 CD5-98L1 30 33 35 38 40 43 CD5-99 30 33 35 38 40 43 45 CD 5 - 9 9A 30 33 35 38 40 43 45 CD5-99AL 1 3 0 3 3 3 5 3 8 4 0 4 3 4 5 4 8 5 0 5 3 5 5 5 8 6 0 CD 5 - 27 wp06.1 30 33 35 38 40 43 45 48 50 53 55 58 60 63 65 68 70 73 7 5 CD 5 - 28 w p 0 8 3 033 3538 40 43 45 48 50 53 55 58 60 63 65 68 70 7 3 7 5 CD 5-29 wp 02 30 33 35 3 8 40 43 45 48 50 53 55 58 60 63 65 6870 73 7 5 CD 5 - 3 3 w p01 v3 ( 16B) 30 33 35 38 40 43 45 48 50 5 3 CD 5 - 34 wp 0 2 30 33 35 38 40 43 45 48 CD 5-35 wp01 v3 (Sliver2) 30 33 35 38 40 43 45 48 50 53 55 58 60 63 65 68 70 CD 5 - 9 4 w p 0 6 30 33 35 38 40 43 45 48 50 53 55 58 60 63 65 CD 5 - 95 wp 0 2 3033 35 38 40 43 45 48 50 53 55 58 CD 5 - 97 wp 0 1 v3 (16A) 3 0 33 35 38 40 43 45 48 50 53 CD 5 - 3 3 0 wp07 .1 CD 5 - 3 3 0 w p 0 7 . 1 Sp i d e r P l o t 10 : 3 9 , N o v e m b e r 0 9 2 0 2 3 54 . 6 0 T o 3 0 7 4 8 . 1 5 Northing (650 usft/in) Ea s t i n g ( 6 5 0 u s f t / i n ) 20 22 2 4 26 28CD 5-01 2022 24 CD5-0 2 2022 24 26 CD 5 -02 A 202224CD 5 -03 20 22 24 26 2 8 3 0 32 CD 5-0 4 20 2 2 24 2 6 28 3 0 CD 5 -05 20222426283032CD 5-06 20222426283032CD5- 0 6 L1 20 22 24 2 6 28 3 0 3 2 CD 5-07 2022 24 26 28 30 CD 5 -08 202224 CD5-09 20 2 2 2 4 26 2 8 30 3 2 34 3 6 CD5-10 20 22 2 4 2 6 28 30 32 3 4 36 38 CD5-1 1 2022242628303234363840424446485052CD 5 -12 20 2 2 24 26 28 30 32 34 CD5-17 20 2 2 24 26 28 30 32 34 CD5-17 L1 2 0 2 2 2 4 26 28 30 CD 5-1 8 2 0 2 2 2 4 26 28 30 CD 5 - 1 8L1 2 02 22 4 26 28 30 32 34 36 3 8 4 0 4 2 4 4 CD 5 - 19 2 02 22 4 26 28 30 32 34 36 3 8 4 0 4 2 4 4 CD 5 - 19 L 1 2 0 2 2 2 4 2 6 CD5-20 2 0 2 2 2 4 2 6 CD5-20L1 20 22 24 26 2 8 30 32 3 4 3 6 3 8 40 42 44 46 48 5 0CD5-21 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 CD 5 - 2 2 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 6 4 8 5 0 5 2 5 4 5 6 CD5-23 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 6 4 8 5 0 5 2 5 4 5 6 CD 5 - 23 L1 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 6 4 8 5 0 5 2 5 4 5 6 CD5- 23 L1-01 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 CD5- 2 4 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 CD5 - 2 4 L1 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 CD 5 - 2 4 L 1 P B 1 2 0 222 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 6 4 8 5 0 5 25 4 5 6 5 8 6 06 2 6 4 6 6 6 8 7 0 7 2 7 4 7 6 CD5-25 2 0 222 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 6 4 8 5 0 5 25 4 5 6 5 8 6 06 2 6 4 6 6 6 8 7 0 7 2 7 4 CD 5 - 2 5L1 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 CD 5 - 26 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 3 6 3 8 CD5 -26L1 20 22 2 4 2 6 28 30 3 2 34 CD 5-31 20 22 24 26 28 30 3 2 CD5-31PB1 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 CD 5 -313 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 CD5-313P B 1 2 0 2 2 CD5- 3 14 20 22 24 26 28 30 32 34 36 CD5-314X 2 0 22 24 2 6 2 8 3 0 3 2 34 CD5- 3 152 0 22 24 2 6 2 8 3 0 3 2 34 CD5-3 15P B 1 20 22 24 26 28 30 32 3 4 3 6 CD 5-316 20 22 24 26 28 30 32 3 4 3 6 20 22 2 4 2 6 2 8 30 3 2 3 4 363840 42444648 CD 5-32 X wp 09 2 0 2 2 2 4 2 6 2 8 3 0 3 2 CD5-90 2 0 2 2 2 4 2 6 2 8 3 0 3 2 2 0 2 2 2 4 2 6 2 8 3 0 3 2 CD 5 -92 20 22 24 26 28 3 0 3 2 3 4 36 3 8 40 CD 5 -93 2 0 2 2 2 4 26 28 30 CD 5 -96 2 0 2 2 2 4 26 28 30 CD5-96 L1 2 0 2 2 2 4 2 6 2 8 3 0 7 6 CD 5 -98 2 0 2 2 2 4 2 6 2 8 3 0 CD5-98L 1 20 22 24 26 CD5-99 20 22 24 26 28 CD 5 - 9 9A 20 22 24 26 28 CD5-99AL 1 2 0 2 2 2 4 2 6 2 8 3 0 3 2 3 4 CD 5 - 27 wp06.1 20 22 24 26 28 30 32 34 36 38 40 CD 5 - 2 8 w p 08 20 22 24 26 2 8 3 0 32 34 36 38 40 42 44 46 48 50 52 54 CD 5 - 29 w p 02 20 22 24 26 28 30 32 34 36 38 40 42 44 CD 5 - 3 3 w p01 v3 ( 16B) 20 22 24 26 28 30 32 34 36 CD 5 - 34 wp 0 2 20 22 24 26 28 30 32 CD 5 - 3 5 w p 0 1 v3 (Sliver2 ) 20 22 24 26 28 30 32 34 CD 5 - 9 4 w p 0 6 20 22 24 26 28 30 32 34 36 CD 5 - 95 wp 0 2 20 2 2 24 26 28 30 32 34 36 38 40 42 44 CD 5 - 97 w p 01 v3 (16 A) 2 0 22 24 2 6 2 8 30 3 2 CD 5-33 0 w p07 .1 CD 5 - 3 3 0 w p 0 7 . 1 Sp i d e r P l o t 10 : 3 9 , N o v e m b e r 0 9 2 0 2 3 54 . 6 0 T o 3 0 7 4 8 . 1 5 Northing (75 usft/in) Ea s t i n g ( 7 5 u s f t / i n ) 1 1 1 2 CD5-09 1 234567 891 0 1 1 121314 CD5-1 1 1234 5 678910111213 14CD5-12 123456789 10 11 12 13 1 4 1 5 16 17 CD5- 1 7 123456789 10 11 12 13 1 4 1 5 16 17 CD 5-17 L 1 1 23 4 5 6 7 8 9 1 0 1 1 1 2 1 3 1 4 1 5 CD 5-18 1 23 4 5 6 7 8 9 1 0 1 1 1 2 1 3 1 4 1 5 CD5-1 8 L 1 1234 567891 0 1 1 1 2 1 3 1 4 15 16 1 7 1 8 1 9 2 0 2 1 CD5-19 1234 567891 0 1 1 1 2 1 3 1 4 15 16 1 7 1 8 1 9 2 0 2 1 CD 5 - 19 L1 1 23 4 5 6 7 8 9 1 0 1 1 1 2 1 3 1 4 CD 5 -20 1 23 4 5 6 7 8 9 1 0 1 1 1 2 1 3 1 4 CD 5 - 2 0 L 1 123 4567891 0 1 1 1 2 1 3 1 4 1 5 1 6 CD 5-21 12345678 91011 12 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD 5 - 2 2 12345 6 7 8 91 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 CD 5 -23 12345 6 7 8 91 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 CD5-23L1 12345 6 7 8 91 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 CD 5 - 2 3L1-01 123456789 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD5-24 123456789 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD 5 - 2 4L1 123456789 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD 5 -24 L1P B1 123456789 1011 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 2 1 2 2 23 2 4 2 5 2 6 2 7 2 8 2 9 3 0 CD 5 -25 123456789 1011 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 2 1 2 2 23 2 4 2 5 2 6 2 7 2 8 2 9 3 0 CD 5 - 2 5L1 123456 7 891 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD5-26 123456 7 891 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 CD5-2 6L1 1 23456 7 8 9 10 11 12 13 14 CD5 -31 1 23456 7 8 9 10 11 12 13 14 CD5 -31PB1 12345678 9 1 0 1 1 1 2 1 3 1 4 1 5 CD 5 -313 12345678 9 1 0 1 1 1 2 1 3 1 4 1 5 CD 5-31 3 P B 1 1234567 8 9 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 CD 5 -31 4 123456 7 8 9 10 11 12 13 14 15 16 17 CD 5-314X 12345 6 7 8 9 10 11 1 2 1 3 1 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4 L 1 CD 5 - 2 4 L 1 P B 1 CD 5 - 2 5 CD 5 - 2 5 L 1 CD 5 - 2 6 L 1 CD 5 - 3 1 CD 5 - 3 1 P B 1 CD 5 - 3 1 3 CD 5 - 3 1 3 P B 1 CD 5 - 3 1 4 CD 5 - 3 1 4 X CD 5 - 3 1 5 CD 5 - 3 1 5 P B 1 CD 5 - 3 1 6 CD 5 - 3 1 6 P B 1 CD 5 - 3 2 X w p 0 9 CD 5 - 9 0 CD 5 - 9 0 L 1 CD 5 - 9 6 CD 5 - 9 6 L 1 CD 5 - 9 8 CD 5 - 9 8 L 1 CD 5 - 9 9 CD 5 - 9 9 A CD 5 - 9 9 A L 1 CD 5 - 2 9 w p 0 2 CD 5 - 3 3 w p 0 1 v 3 ( 1 6 B ) 3- D V i e w CD 5 - 3 3 0 w p 0 7 . 1 10 : 4 5 , N o v e m b e r 0 9 2 0 2 3 -2 2 0 0 0 -2 0 0 0 0 -1 8 0 0 0 -1 6 0 0 0 -1 4 0 0 0 -1 2 0 0 0 South(-)/North(+) (2000 usft/in) -2 0 0 0 0 - 1 8 0 0 0 - 1 6 0 0 0 - 1 4 0 0 0 - 1 2 0 0 0 - 1 0 0 0 0 - 8 0 0 0 - 6 0 0 0 - 4 0 0 0 We s t ( - ) / E a s t ( + ) ( 2 0 0 0 u s f t / i n ) 7 4 5 0 C D 5 - 3 1 4 X 7 4 5 0 C D 5 - 3 1 6 74 50 CD 5 -3 16 PB1 745 0 7 50 0 CD 5 - 3 3 0 w p 0 7 . 1 CD 5 - 3 3 0 w p 0 7 . 1 Qu a r t e r M i l e V i e w 10 : 4 8 , N o v e m b e r 0 9 2 0 2 3 WE L L B O R E T A R G E T D E T A I L S ( M A P C O - O R D I N A T E S ) Na m e T V D S h a p e CD 5 - 3 0 T 0 1 ( S u n 5 ) 0 6 2 4 2 1 7 4 6 8 . 2 0 C i r c l e ( R a d i u s : 1 0 0 . 0 0 ) CD 5 - 3 0 T 0 1 Q M 7 4 6 8 . 2 0 C i r c l e ( R a d i u s : 1 3 2 0 . 0 0 ) CD 5 - 3 0 T 0 2 ( S u n 5 ) 0 6 2 4 2 1 7 5 0 8 . 2 0 C i r c l e ( R a d i u s : 1 0 0 . 0 0 ) CD 5 - 3 0 T 0 2 Q M 7 5 0 8 . 2 0 C i r c l e ( R a d i u s : 1 3 2 0 . 0 0 ) -1 2 0 0 -9 0 0 -6 0 0 -3 0 0 0 30 0 South(-)/North(+) (300 usft/in) -1 8 0 0 - 1 5 0 0 - 1 2 0 0 - 9 0 0 - 6 0 0 - 3 0 0 0 3 0 0 6 0 0 We s t ( - ) / E a s t ( + ) ( 3 0 0 u s f t / i n ) C D 5 - 0 1 C D 5 - 0 2 C D 5 - 0 2 A C D 5 - 0 3 C D 5 - 0 4 C D 5 - 0 5 C D 5 - 0 6 C D 5 - 0 6 L 1 2 2 C D 5 - 0 7 C D 5 - 0 8 C D 5-09 C D 5 - 1 0 2222 C D 5 - 1 1 C D 5 - 1 2 2222 C D 5 - 1 7 2222 C D 5 - 1 7 L 1 2 2 2 2 C D 5 - 1 8 2 2 2 2 C D 5 - 1 8 L 1 2 2 2 2 C D 5 - 1 9 2 2 2 2 C D 5 - 1 9 L 1 C D 5 - 2 0 C D 5 - 2 0 L 1 2222 C D5 -2 1 2 2 2 2 C D 5 - 2 2 2 2 2 2 C D 5 - 2 3 2 2 2 2 C D 5 - 2 3 L 1 2 2 2 2 C D 5 - 2 3 L 1 - 0 1 2 2 2 2 C D 5 - 2 4 2 2 2 2 C D 5 - 2 4 L 1 2 2 2 2 C D 5 - 2 4 L 1 P B 1 2222 C D 5 - 2 5 2222 C D 5 - 2 5 L 1 2 2 2 2 C D 5 - 2 6 2 2 2 2 C D 5 - 2 6 L 1 2 22 2 C D 5 - 3 1 2 22 2 C D 5 - 3 1 P B 1 2 2 2 2 C D 5 - 3 1 3 2 2 2 2 C D 5 - 3 1 3 P B 1 2 2 2 2 C D 5 - 3 1 4 2222 C D 5 - 3 1 4 X 2 222 C D 5 - 3 1 5 2 222 C D 5 - 3 1 5 P B 1 2222 C D 5 - 3 1 6 2222 CD 5 -3 16 PB1 2222 CD 5 - 3 2 X w p 0 9 C D 5 - 9 0 C D 5 - 9 0 L 1 C D 5 - 9 2 2222 C D 5 - 9 3 C D 5 - 9 6 C D 5 - 9 6 L 1 C D 5 - 9 8 C D 5 - 9 8 L 1 C D 5 - 9 9 C D 5 - 9 9 A C D 5 - 9 9 A L 1 2 2 2 2 C D 5 - 2 7 w p 0 6 . 1 2222 C D 5 - 2 8 w p 0 8 2222 C D 5 - 2 9 w p 0 2 2222 C D 5 - 3 3 w p 0 1 v 3 ( 1 6 B ) 2222 C D 5 - 3 4 w p 0 2 2222 C D 5 - 3 5 w p 0 1 v 3 ( S l i v e r 2 ) C D 5 - 9 4 w p 0 6 2222 C D 5 - 9 5 w p 0 2 2222 C D 5 - 9 7 w p 0 1 v 3 ( 1 6 A ) 13 - 3 / 8 " S u r f a c e C a s i n g 22 2 2 CD 5 - 3 3 0 w p 0 7 . 1 CD 5 - 3 3 0 w p 0 7 . 1 Su r f a c e C a s i n g 5 0 0 ' r 10 : 5 4 , N o v e m b e r 0 9 2 0 2 3 WE L L B O R E T A R G E T D E T A I L S ( M A P C O - O R D I N A T E S ) Na m e T V D S h a p e CD 5 - 3 0 T 0 1 ( S u n 5 ) 0 6 2 4 2 1 7 4 6 8 . 2 0 C i r c l e ( R a d i u s : 1 0 0 . 0 0 ) CD 5 - 3 0 S u r f C s g 7 4 6 8 . 2 0 C i r c l e ( R a d i u s : 5 0 0 . 0 0 ) CD 5 - 3 0 T 0 1 Q M 7 4 6 8 . 2 0 C i r c l e ( R a d i u s : 1 3 2 0 . 0 0 ) CD 5 - 3 0 T 0 2 ( S u n 5 ) 0 6 2 4 2 1 7 5 0 8 . 2 0 C i r c l e ( R a d i u s : 1 0 0 . 0 0 ) CD 5 - 3 0 T 0 2 Q M 7 5 0 8 . 2 0 C i r c l e ( R a d i u s : 1 3 2 0 . 0 0 ) CD5-330wp07.1 Surface Location CD5-330wp07.1 Surface Location CD5-330wp07.1 Surface Casing CD5-330wp07.1 Surface Casing CD5-330wp07.1 Intermediate Casing 1 CD5-330wp07.1 Intermediate Casing 1 CD5-330wp07.1 Top Kup C CD5-330wp07.1 Top Kup C CD5-330wp07.1 Intermediate Casing 2 CD5-330wp07.1 Intermediate Casing 2 CD5-330wp07.1 TD CD5-330wp07.1 TD 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:Polasek, Tom G To:Loepp, Victoria T (OGC) Subject:RE: Update: CD5-330 Schedule and Timing Date:Friday, February 2, 2024 10:51:50 AM You don't often get email from tom.g.polasek@conocophillips.com. Learn why this is important Hi Victoria, This email is to inform you of ConocoPhillips schedule change regarding CD5-330 surface section drilling. Because of 1) schedule delays, our advantageous gap between CD5-32X and Titan has closed and 2) further engineering regarding rig bridge crossings between CD5 and MT7 has relieved our ice season schedule pressure in 2025, plus 3) other smaller considerations, we have decided not to drill the surface section of CD5-330 in the coming months. We will drill CD5-330 as one continuous drilling operation, likely starting in November of 2024. Current Rig D26 Drilling Schedule (as of 2/2/24): 1. CD5-32X 2. Titan 3. MT7 (multiple wells, likely 4-5) 4. CD5-330 (forecasted spud ~Nov 5 – 20) Thank you Victoria and please let me know if you have any follow up questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Polasek, Tom G Sent: Monday, January 29, 2024 12:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: Update: CD5-330 Schedule and Timing Hi Victoria, Update on current Doyon 26 drilling schedule in WNS. Original drilling schedule plan was for rig Doyon 26 to drill CD5-32X, then if there was enough time before the ice road and pad was ready for Titan, we would drill the surface section of CD5-330, which was predicted to take ~8 days, then move out on the ice to Titan. The rest of CD5-330 would be finished in Q1 of 2025. If the gap between CD5-32X rig release and Titan ice readiness closed, we would move CD5-330 to after Titan. CD5-32X spud has been delayed from original schedule and there is no longer a gap between CD5- 32X predicted rig release and Titan ice being ready. Because of this CD5-330 Surface section has been moved to after Titan. Current D26 predicted schedule and times: 1. CD5-32X Spud to rig release ~Feb 7th - ~March 4th 2. Titan Spud to rig release ~March 8th – April 9th 3. CD5-330 Surface Section Spud to rig release ~April 13th - ~April 21st (On the phone I mentioned spud possibly 1st week of April, but upon more careful look at schedule, dates listed are should be more accurate) 4. Start Move to MT7 ~April 21st Notes: 1. The reasons for drilling only the surface section on CD5-330 in Q1 of 2024, is to relieve schedule pressure on the ice season of 2025 and was to take advantage of rig standby time while Titan ice was prepared. 2. CD5-330 PTD timing and original predicted spud on the PTD application of ~Feb 10th was to be ready for the gap between CD5-32X and Titan, but as mentioned above, that gap between CD5-32X and Titan is no longer there. Therefore, with the new predicted CD5-330 Surface spud of ~April 13th, we do not need the approved PTD until closer to April. 3. There is a relatively high chance that further schedule delays will cause CD5-330 Surface section to be removed from the schedule in Q1/Q2 of 2024. In that scenario the entire CD5- 330 will be drilled at one time and will likely be moved to Q4 2024 or Q1 2025. I will notify AOGCC if Conoco removes CD5-330 Surface section from Q1/Q2 2024 schedule. Please let me know if you have any other questions. Thank You, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com 1 Dewhurst, Andrew D (OGC) From:Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent:Wednesday, January 17, 2024 10:00 To:Dewhurst, Andrew D (OGC) Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions Follow Up Flag:Follow up Flag Status:Flagged Hi Andy, Please see answers in blue: x What is the LWD program for the Intermediate 2 hole section? x Answer: For Intermediate 2 hole section we plan on GR/RES/Deep Azimuthal RES. We will use the deep azimuthal resistivity to aid in landing in the reservoir section. x Also, I’d like to confirm triple combo in the 6-3/4” hole: x Answer: That is correct for 6-3/4” hole we plan on GR/RES/DEN/NEU x Would you please confirm that neither of the two identified significant HC zones (Albian Sub 97 and Albian Sub 93) are anticipated to be gas bearing: x Answer: The Sub97 is being evaluated as a viable economic target for recoverable hydrocarbons. While fluid phase is one of the key uncertainties, the most recent analysis of the zone suggests this well will be in the oil leg. It is possible the wellbore could encounter a Sub97 gas cap if it’s present. This zone will be cemented if pay quality hydrocarbon bearing reservoir is identified. x Answer: There have been no fluid tests of the Sub93 in this area, so phase of the hydrocarbon is unknown. The Sub 93 is expected to encounter the water leg in the Sun 5 location. Analysis of offset mud logs suggest hydrocarbon phase could be oil or gas. If pay quality hydrocarbon-bearing reservoir is encountered the team is prepared to cement the section. Thanks Andy and please let me know if you have any other questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Oĸce: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Thursday, January 11, 2024 4:16 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Some people who received this message don't often get email from tom.g.polasek@conocophillips.com. Learn why this is important 2 Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions Tom, x What is the LWD program for the Intermediate 2 hole secƟon? x Also, I’d like to conĮrm triple combo in the 6-3/4” hole: x Would you please conĮrm that neither of the two idenƟĮed signiĮcant HC zones (Albian Sub 97 and Albian Sub 93) are anƟcipated to be gas bearing: Thanks, Andy From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, January 10, 2024 17:01 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions Andy, Good catch and you are correct. Den/Nue/Image should have been removed from the PTD. We will NOT run Den/Nue/Image in the INT1 BHA. We will run GR/RES in the INT1 BHA. Thanks, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, January 10, 2024 3:59 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions Tom, Thanks for the info. Just to conĮrm, will you not also have DEN/NEU on the LWD program for the intermediate 1 hole secƟon? 3 Andy From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, January 10, 2024 13:50 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions Hi Andy, Thanks for your patience waiting for my reply. I wanted to make sure I have the most accurate information. Answers to your questions: x I see an example of the Sub Albian 97 HC zone in the oīset well CD5-316. Would you provide a summary of how your team plans to evaluate this zone for hydrocarbon at CD5-330? For development wells at CD4, CPAI has been applying a petrophysical model developed from learnings at CD1 to evaluate potenƟal shallow HC zones, and sharing the results with the AOGCC. Do you have access to this model? o Answer: We intend to evaluate the Sub Albian 97 with our LWD tools (gamma ray and resisƟvity). We have access to the petrophysical model developed from the CD1 learnings but believe oīset well analysis of the Sub 97 speciĮc to the CD5 area provides a more reĮned model for idenƟfying pay in that formaƟon. x Would you please provide both the most recent and maximum H2S reading for the CD5 pad? o Answer: Maximum H2S on our most recent batch of tesƟng was CD5-96 at 200 ppm on 12/9/23 o Answer: Maximum H2S was CD5-314X at 400 ppm on 9/8/23 (CD5-314X on most recent batch was 150 ppm on 12/9/23) x Would you conĮrm that the well path crosses though the AA092347 lease? It’s not clear from the plat which lease SecƟon 13 belongs to. o Answer: Yes, the well path (red line on map) crosses through lease AA092347. We have several leases that are not in a “solid block” but are secƟons that touch corner to corner of the secƟons. See map below. Outline of lease in blue. 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. 4 o Thanks and please let me know if you have any other questions, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, January 8, 2024 2:44 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]CRU CD5-330 (PTD 223-124) - Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 5 Tom, I’m compleƟng the review of the CRU CD5-330 PTD and have a couple quesƟons: x I see an example of the Sub Albian 97 HC zone in the oīset well CD5-316. Would you provide a summary of how your team plans to evaluate this zone for hydrocarbon at CD5-330? For development wells at CD4, CPAI has been applying a petrophysical model developed from learnings at CD1 to evaluate potenƟal shallow HC zones, and sharing the results with the AOGCC. Do you have access to this model? x Would you please provide both the most recent and maximum H2S reading for the CD5 pad? x Would you conĮrm that the well path crosses though the AA092347 lease? It’s not clear from the plat which lease SecƟon 13 belongs to. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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. X CRU CD5-330 ALPINE OIL POOL 223-124 COLVILLE RIVER 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 Co n o c o P h i l l i p s A l a s k a , I n c . We l l N a m e : CO L V I L L E R I V U N I T C D 5 - 3 3 0 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 50 3 6 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 2 4 0 CO L V I L L E R I V E R , A L P I N E O I L - 1 2 0 1 0 0 NA 1 Pe r m i t f e e a t t a c h e d Ye s AS R C - N P R 4 , AA 0 9 2 3 4 7 , A S R C - A A 0 9 2 3 4 4 , AA 0 8 1 8 1 7 , A A 0 9 4 1 6 5 , AA 0 9 4 1 6 7 2 Le a s e n u m b e r a p p r o p r i a t e Ye s 3 Un i q u e w e l l n a m e a n d n u m b e r Ye s CO L V I L L E R I V E R , A L P I N E O I L - 1 2 0 1 0 0 - g o v e r n e d b y 4 4 3 D 4 We l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 We 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 We 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 Su 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 If 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 Op 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 Op 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 Pe 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 Pe 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 Ca 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 We 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 Al 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 Pr 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 No 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 . 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R e c e n t r e a d i n g o f 1 5 0 p p m ( 1 2 / 2 0 2 3 ) 35 Pe 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 se e c o m m e n t s b e l o w 36 Da 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 Se 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 Se 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 Co n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 1/ 8 / 2 0 2 4 Ap p r VT L Da t e 2/ 2 1 / 2 0 2 4 Ap p r AD D Da t e 1/ 5 / 2 0 2 4 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e Ma x p r e s s u r e ( i n H R Z / K a l u b i k ) a n t i c i p a t e d t o b e 1 1 p p g E M W . 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