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Home My WebLink About221-085CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Joseph Lastufka To:Rixse, Melvin G (OGC); Guhl, Meredith D (OGC) Cc:Trevor Hyatt Subject:PBU E-26C (PTD #221-085) Cancelled Permit to Drill Date:Monday, April 4, 2022 9:21:29 AM Mel, We were able to complete PBU E-26B as requested without needing contingent PBU E-26C (PTD #221-085). Since we won’t be drilling E-26C in the near future, please cancel the permit. If you have any questions or if I need to send to anyone else, please let me know. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Trevor Hyatt Cc:Joseph Lastufka Subject:20220308 1457 APPROVAL PBU E-26B - PTD: 221-084 & 211-085 (Perforate with CDR2) Date:Tuesday, March 8, 2022 2:57:48 PM Trevor, Hilcorp is approved to perform extended perforating with CDR2 as per the procedure below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent: Tuesday, March 8, 2022 2:47 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU E-26B - PTD: 221-084 & 211-085 (Perforate with CDR2) Mel, The original E-26B perforation plan was to utilize the post rig extended add perf procedure on service coil. With that practice not being an option currently, we would like to perforate roughly 300’ on the rig after we run liner and cement. We will perforate under PTD: 221-084 (or 211-085 if the secondary target is necessary) See below for E-26B Perf Plan: 1. Run liner to TD and cement in place 2. Flow check to confirm wellbore fluid is overbalanced to the formation. 3. Trip out of hole and flow check. Lay down liner running / cementing BHA 4. Make up ~300’ of 2” perf guns, 6 SPF, 60 deg phasing. a. Deploy guns on 1.25” CSH and Coil 221 221 221 b. 2-3/8” safety joint with crossovers will be available while handling perf guns and 1.25” CSH 5. Perforate wellbore per plan and pull out of hole. a. Ensure fluid level is at surface b. Flow check wellbore before laying down perf guns 6. Nozzle run to freeze protect well 7. RDMO Let me know what you think and if you need anything else from us to perform this operation with CDR2. Thank you for your time and consideration. Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-26C Hilcorp North Slope, LLC Permit to Drill Number: 221-085 Surface Location: 1520’ FNL, 501’ FEL, Sec. 06, T11N, R14E, UM Bottomhole Location: 1474’ FNL, 1862’ FWL, Sec. 05, T11N, R14E, UM Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie Chmielowski Commissioner DATED this ___ day of October, 2021. 15 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.10.15 11:42:40 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 11,793' TVD: 9,184' 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): 67.7' 15. Distance to Nearest Well Open Surface: x-664479 y- 5975544 Zone- 4 29.97' to Same Pool: 111' 16. Deviated wells: Kickoff depth: 9,285 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 4-1/4"3-1/2"x3-1/4"9.3#/6.6# 13Cr80 STL/TCII 2,744' 9,049' 8,657' 11,793' 9,184' x2-7/8" /6.5# STL 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 117' 2,689' 7,786' 7,657' - 8,733' 8,654' - 8,798' 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: Trevor Hyatt Monty Myers Contact Email:trevor.hyatt@hilcorp.com Drilling Manager Contact Phone:777-8396 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng January 15, 2022 10,665' 50-029-21781-03-00 9,045' - 10,063' 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2,653' 8 cu yds Concrete 117' 2,689'13-3/8" 3723 cu ft Permafrost Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: 4-1/2" 7,987' 230 cu ft Class 'G' Uncemented Slotted Liner Liner Liner 7,953' 1,365' 1,018' Intermediate Authorized Name: 9,045' - 10,040' Conductor/Structural 20"80' LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) 160 sx Class 'G' 2469 18. Casing Program: Top - Setting Depth - BottomSpecifications 3,268 Total Depth MD (ft): Total Depth TVD (ft): 107205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2,388 1919' FNL, 136' FWL, Sec. 05, T11N, R14E, UM, AK 1474' FNL, 1862' FWL, Sec. 05, T11N, R14E, UM, AK 89-111 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 1520' FNL, 501' FEL, Sec. 06, T11N, R14E, UM, AK ADL 028304 PBU E-26C Prudhoe Bay Field Prudhoe Bay Oil Pool Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 8,654' - 8,797' 1865 cu ft Class 'G' 7,833' - 9,198'7" 9-5/8" o o o o Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 10.12.2021 By Samantha Carlisle at 3:48 pm, Oct 12, 2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.10.12 14:46:26 -08'00' Monty M Myers X X MGR14OCT2021 X DLB 10/14/2021 221-085 DSR-10/12/21 X X DLB BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) approved for alternate plug placment Separate sundry required for extended length perforating deploying without PCE. X X dts 10/15/2021 10/15/2021Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.10.15 11:42:23 -08'00' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: October 12, 2021 Re: PBU E-26B Permit to Drill (and Contingency E-26C PTD) Approval is requested for drilling a CTD sidetrack lateral from well PBU E-26A with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for E-26B (and contingency E-26C) Producer: See E-26A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock, dummy mandrels and MIT-IA. E-line will then mill the XN-nipple. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A 4-1/2" whipstock will be set with the rig and a single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Sag, build through the Ivishak and land in Zone 2. The lateral will continue in Zone 1 and 2 to TD (this well is E-26B WP09). If it is determined the primary target is not sufficient to produce from, a billet will be set and the well sidetracked to the contingency target and directional plan. This plan also drills in Zone 1 and 2 to TD (this well is E-26C WP07). The proposed sidetrack will be completed with a 3-1/2"x3- 1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Sag slotted liner. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference E-26A Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1. Slickline: Dummy WS drift and dummy GLMs 2. Fullbore: MIT-IA 3. E-line: Mill XN-nipple Rig Work - (Estimated to start in January 2022): 1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,388 psi a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure 2. Set 4-1/2” flow through whipstock a. Top of whipstock set at 9,285’ MD (top of window - pinch point) b. Oriented 180° ROHS 3. Mill 3.80” single string window (out of 4-1/2”) plus 10’ of rathole. a. Top of window (whipstock pinch point) at 9,285’ MD. b. Mill window with straight motor c. Hold 9.8 ppg MPD while milling window PTD221-084 Sundry 321-540 4. Drill – Build & Lateral (E-26B WP09) a. 3” BHA with GR/RES / Bi-center Bit (4.25”) b. 32° DLS build section – 627’ MD / Planned TD 9,912’ MD c. 12° DLS lateral section – 2,140’ MD / Planned TD 12,052’ MD d. Contingency E-26C plan to set billet and sidetrack: i. Set billet at 9890’ MD and kick off and drill contingency plan (E-26B Cont. WP07) ii. 25° DLS build section – 200’ MD / Planned TD 10,090’ MD iii. 12° DLS lateral section – 1,703’ MD / Planned TD 11,793’ MD e. Drill with a constant bottom hole pressure for entire sidetrack f. Pressure deployment will be utilized g. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run h. No flow test prior to laying down drilling BHA. Assure well is dead prior to picking up liner. 5. Run and Cement Liner a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner b. Run 3-1/2”x3-1/4”x2-7/8” 13Cr solid liner to TD c. Swap well over to KCl d. Cement Liner with 36 bbls (E-26B) or 33 bbls (E-26C) - 15.3 ppg Class G cement (TOC to TOL)* e. Freeze protect well from ~2200’ MD (min) f. RDMO Post Rig: 1. V: Valve & tree work 2. S: Set LTP* (if necessary) and set live GLVs 3. C: Post rig perforate (~300’) and RPM Log * Approved alternate plug placement per 20 AAC 25.112(i) Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (9,285’ MD - 8,758’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,463 psi 4,463 psi 9.8 B Annular friction - ECD (psi/ft)557 psi 0 psi 0.06 C Mud Hydrostatic (ppg)3,825 psi 3,825 psi 8.4 B+C Mud + ECD Combined 4,383 psi 3,825 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 80 psi 638 psi Target BHP at window and deeper gg Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom holegp g q py p pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface DLB Separate sundry required for extended length perforating deploying without PCE pressure. p PTD221-085 PTD221-084 Operation Details: Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,268 psi at 8,800’ TVD (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,388 psi. Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain constant BHP. x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring. x Completion: A minimum MW 8.4 ppg KWF to be used for liner deployment. Will target 9.8 ppg to match managed pressure target. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 4.25” hole for the entirety of the production hole section. Liner Program (E-26B): x 3-1/2”, 9.3#, 13Cr solid/cemented liner: 9,049’ MD – 9,270’ MD (221’ liner) x 3-1/4”, 6.6#, 13Cr solid/cemented liner: 9,270’ MD – 9,885’ MD (615’ liner) x 2-7/8”, 6.5#, 13Cr solid/cemented liner: 9,885’ MD – 12,052’ MD (2,167’ liner) x Contingency Liner Program (E-26C): o 3-1/2”, 9.3#, 13Cr solid/cemented liner: 9,049’ MD – 9,270’ MD (221’ liner) o 3-1/4”, 6.6#, 13Cr solid/cemented liner: 9,270’ MD – 9,885’ MD (615’ liner) o 2-7/8”, 6.5#, 13Cr solid/cemented liner: 9,885’ MD – 11,793’ MD (1,908’ liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary x A X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x An X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole. x Exemption request to 20 AAC 25.036 - Liner rams in the BOPE. A 2-3/8” safety joint will be utilized while running 2-7/8”, 3-1/4”, 3-1/2” solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-installed TIW valve). When closing on a 2-3/8” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached: Primary Plan - WP09 (E-26B) and Contingency Plan - WP07 (E-25C) x Maximum planned hole angle is 100°. Inclination at kick off point is 80°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 8,809’ (E-26B) and 10,665’ (E-26C) x Distance to nearest well within pool – 137’ (E-26B) and 111’ (E-26C) Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. constant BHP. g Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintaing DLB Perforating: x ~300’ perforated post rig (See future extended perforating sundry request) Anti-Collision Failures: x No failures for E-26B WP09 (E-26B) x No failures for E-26C Cont. WP07 (E-25C) Hazards: x PBU E-pad is an H2S pad. The highest recorded H2S well on the pad was from E-102 (130 ppm) in 2009. Last recorded H2S on E-26A was 12 ppm in 2018 x Five fault crossings expected. x Medium lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 6WDQGDUG3URSRVDO5HSRUW 2FWREHU 3ODQ(&ZS +LOFRUS$ODVND//& 3UXGKRH%D\ ( 3ODQ( 3ODQ(& 7700787580508225840085758750892591009275True Vertical Depth (350 usft/in)-175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 2800 2975 3150Vertical Section at 88.88° (350 usft/in)E-26B Fault PolygonE-26B Cont wp06 PolygonE-26B Cont wp07 1E-26B Cont wp07 2E-26B Cont wp07 3E-26B Cont wp07 4E-26B Cont wp07 5E-26B Cont wp07 6E-26B Cont wp07 7800085009 000 9 5 0 0 1 0 0 0 0 1 0 06 5 E-26A80008500900095009775E-269500100001050011000115001200012052E-26B wp092 7/8" x 4 1/4"1000010500110001150011 7 9 3E-26C wp07KOP : Start Dir 25º/100' : 9890' MD, 9076.29'TVD : 100.5° RT TFStart Dir 12º/100' : 10089.76' MD, 9072.41'TVDTotal Depth : 11793' MD, 9184.44' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: E-26Ground Level: 29.97+E/-WNorthingEastingLatitudeLongitude+N/-S0.000.005975544.00664479.0070° 20' 22.1517 N148° 39' 54.8881 WSURVEY PROGRAMDate: 2021-10-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool99.98 7899.98 E26 Survey 1 GCT MS (E-26) 3_Gyro-CT_pre-1998_Csg7975.98 9285.00 E-26A Survey #2 MWD (E-26A) 3_MWD9285.00 9890.00 E-26B wp09 (Plan: E-26B) 3_MWD9890.00 11793.00 E-26C wp07 (Plan: E-26C) 3_MWDREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: E-26, True NorthVertical (TVD) Reference:KB @ 67.70usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 67.70usft (ORIG KELLY BUSHING)Calculation Method: Minimum CurvatureProject:Prudhoe BaySite: EWell: Plan: E-26Wellbore:Plan: E-26CDesign:E-26C wp07CASING DETAILSTVD TVDSS MD SizeName9184.44 9116.74 11793.00 2-7/8 2 7/8" x 4 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 9890.00 94.51 3.88 9076.29 -137.98 648.54 0.00 0.00 645.73 KOP : Start Dir 25º/100' : 9890' MD, 9076.29'TVD : 100.5° RT TF2 9990.00 89.95 28.49 9072.40 -42.79 676.20 25.00 100.50 675.243 10089.76 90.03 53.43 9072.41 31.96 741.08 25.00 89.83 741.56 Start Dir 12º/100' : 10089.76' MD, 9072.41'TVD4 10214.76 90.03 68.43 9072.35 92.52 850.02 12.00 90.00 851.665 10439.76 90.03 95.43 9072.23 123.81 1070.74 12.00 90.00 1072.946 10689.82 75.55 122.00 9104.09 46.04 1303.22 12.00 119.99 1303.877 10834.82 67.48 105.72 9150.31 -9.74 1428.19 12.00 -120.02 1427.738 10984.82 83.28 96.77 9188.12 -37.52 1570.01 12.00 -30.00 1568.989 11097.41 95.00 90.04 9189.81 -44.181682.13 12.00 -30.00 1680.9510 11297.41 94.57 65.95 9172.89 -3.021875.62 12.00 -90.00 1875.2011 11572.41 85.77 97.79 9172.05 35.30 2144.11 12.00 105.00 2144.3912 11677.41 82.63 85.53 9182.70 32.25 2248.31 12.00 -105.00 2248.5113 11787.46 95.05 81.03 9184.93 45.11 2357.34 12.00 -20.00 2357.7714 11793.00 95.05 80.36 9184.44 46.00 2362.79 12.00 -90.00 2363.23 Total Depth : 11793' MD, 9184.44' TVD -700-525-350-175017535052570087510501225140015751750South(-)/North(+) (350 usft/in)0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 2450 2625 2800 2975 3150 3325West(-)/East(+) (350 usft/in)E-26B Cont wp07 7E-26B Cont wp07 6E-26B Cont wp07 5E-26B Cont wp07 4E-26B Cont wp07 3E-26B Cont wp07 2E-26B Cont wp07 1E-26B Cont wp06 PolygonE-26B Fault Polygon7750825085008 7 5 0 8799E -26A 2 0 0 040006500675070007250 750080008500875090009299E-269000E-26B wp092 7/8" x 4 1/4"9 1 8 4E-26C wp07KOP : Start Dir 25º/100' : 9890' MD, 9076.29'TVD : 100.5° RT TFStart Dir 12º/100' : 10089.76' MD, 9072.41'TVDTotal Depth : 11793' MD, 9184.44' TVDCASING DETAILSTVDTVDSS MDSize Name9184.44 9116.74 11793.00 2-7/8 2 7/8" x 4 1/4"Project: Prudhoe BaySite: EWell: Plan: E-26Wellbore: Plan: E-26CPlan: E-26C wp07WELL DETAILS: Plan: E-26Ground Level: 29.97+N/-S+E/-WNorthing Easting Latitude Longitude0.00 0.005975544.00664479.00 70° 20' 22.1517 N148° 39' 54.8881 WREFERENCE INFORMATIONCo-ordinate (N/E) 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(&ZS B0:'(OOLSVHHUURUWHUPVDUHFRUUHODWHGDFURVVVXUYH\WRROWLHRQSRLQWV6HSDUDWLRQLVWKHDFWXDOGLVWDQFHEHWZHHQHOOLSVRLGV&DOFXODWHGHOOLSVHVLQFRUSRUDWHVXUIDFHHUURUV&OHDUDQFH)DFWRU 'LVWDQFH%HWZHHQ3URILOHV'LVWDQFH%HWZHHQ3URILOHV(OOLSVH6HSDUDWLRQ'LVWDQFH%HWZHHQFHQWUHVLVWKHVWUDLJKWOLQHGLVWDQFHEHWZHHQZHOOERUHFHQWUHV$OOVWDWLRQFRRUGLQDWHVZHUHFDOFXODWHGXVLQJWKH0LQLPXP&XUYDWXUHPHWKRG2FWREHU &203$663DJHRI 0.001.002.003.004.00Separation Factor9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 11500 11600 11700 11800Measured Depth (200 usft/in)E-35BE-05CE-05BE-09CE-26B wp09E-12ANo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: E-26 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 29.97+N/-S +E/-W Northing Easting Latitude Longitude0.000.005975544.00 664479.0070° 20' 22.1517 N148° 39' 54.8881 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: E-26, True NorthVertical (TVD) Reference: KB @ 67.70usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 67.70usft (ORIG KELLY BUSHING)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-10-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool99.98 7899.98 E26 Survey 1 GCT MS (E-26) 3_Gyro-CT_pre-1998_Csg7975.98 9285.00 E-26A Survey #2 MWD (E-26A) 3_MWD9285.00 9890.00 E-26B wp09 (Plan: E-26B) 3_MWD9890.00 11793.00 E-26C wp07 (Plan: E-26C) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 11500 11600 11700 11800Measured Depth (200 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference9890.00 To 11793.00Project: Prudhoe BaySite: EWell: Plan: E-26Wellbore: Plan: E-26CPlan: E-26C wp07Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name9184.44 9116.74 11793.00 2-7/8 2 7/8" x 4 1/4" Well Bighole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips Revised 2/2015 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 No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as 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' sample intervals from below the permafrost or from where samples are first caught and 10' 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 well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such 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 (_______________________________) 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 well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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