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Home My WebLink About217-060Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, April 29, 2019 10:08 AM To: Ohlinger, James J Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA) Subject: KRU 3M-27AL4, 1-4-01, 1-4-02, PTDs 217-058, 217-059, 217-060. Permits Expired Hello James, The following Permits to Drill, issued to ConocoPhillips Alaska, have expired under Regulation 20 AAC 25.005 W. The PTDs will be marked expired in the AOGCC database. • KRU 3M-27A L4, PTD 217-058, Issued 25 April 2017 • KRU 3M-27A 1-4-01, PTD 217-059, Issued 25 April 2017 • KRU 3M-27A 1-4-02, PTD 217-060, Issued 25 April 2017 If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. THE STATE GOVERNOR BILL WALKER J. Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 9 Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-27AL4-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-060 Surface Location: 892' FNL, 1574' FEL, Sec. 25, T13N, R8E, UM Bottomhole Location: 4849' FNL, 1495' FEL, Sec. 22, T13N, R8E, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 217-053, API No. 50-029- 22637-01-00. Production should continue to be reported as a function of the original API number stated above. 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, w el T. Seamount, Jr. Commissioner �K DATED this 2S day of April, 2017. HF.ch1vtU STATE OF ALASKA Al .A OIL AND GAS CONSERVATION COMM _)N APR 1 1 2017 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral I ❑✓ Stratigraphic Test ❑ Development - Oil ❑✓ - Service - Winj ❑ Single Zone D Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q - Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc - Bond No. 5952180 KRU 3M-27AL4-02 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14375' - TVD: 6235' Kuparuk River Pool / 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 892' FNL, 1574' FEL, Sec 25, T13N, R8E, UM S ADL 355032 �S a� Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use P mit: 13. Approximate Spud Date: 3604' FNL, 1034' FEL, Sec 22, T13N, R8E, UM ALK 3576 4/24/2017 Total Depth: 9. Acres in Property: 919 14. Distance to Nearest Property: 4849' FNL, 1495' FEL, Sec 22, T13N, R8E, UM 5188— /C . 2�� 3700' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 68' 15. Distance to Nearest Well Open Surface: x- 506294 y- 6016606 Zone- 4 GL Elevation above MSL (ft): 27' to Same Pool: 1508', 3M-23 16. Deviated wells: Kickoff depth: 12875 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94 degrees ' Downhole: 4305 , Surface: 3684 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 1792' 12583' 6114' 14375' 6235' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 13016' 6440' N/A 12926' 6372' 12907' Casing Length Size Cement Volume MD TVD Conductor 121' 16" 200 CIF 121' 121' Surface 5928' 9-5/8" 1300 sx AS III, 690 sx Class G 5996' 3465' Production 12938' 7" 200 sx Class G 13006' 6432' Perforation Depth MD (ft): 12696' - 12708', 12724' - 12744', Perforation Depth TVD (ft): 6198' - 6207', 6219' - 6234', 12764' - 12784' 6249' - 6264' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 reqVa nts❑✓ 21. Verbal Approval: Commission Representative: Date 1 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Keith Herring @ 263-4321 be deviated from without prior written approval. Contact Email Keith. E.Herrinpna.cop.com Printed Name J. Ohlinger Title Staff CTD Engineer Signature Phone 265-1102 Date Commission Use Only Permit to Dr' API Number: Permit Approval See cover letter for other Number: - 0 % Q 50- Date: - 2 2; - 1—C requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: Other: �f Samples req'd: Yes ❑ No [i Mud log req'd: Yes ❑ No [Z I3�P first rJrrs vr� �D �T/ zG��`jS L HzSmeasures: Yes [r� No❑ Directional Yes No El svy req'd: v ✓/ �i) (%�GC Y�rl V�C� ftr �tST Z�rEf�n req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No 64 Post initial injection MIT req'd: Yes ❑ Nov 1w,-;7Lz-d to46loLv tiirr APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 5177 Submit Form and Form 10-401 (Revised 11/2015) hi t a d 2 the from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 7, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: APR 11 Z017 , 0GG ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill eight laterals out of the KRU 3M-27 (PTD# 195-214) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in May 2017. The objective will be to drill the 8 laterals KRU 3M-27A, 3M-27AL1, 3M-27AL2, 3M-27AL2-01, 3M-27AL3, 3M-27AL4, 3M-27AL4-01, and 3M-27AL4-02 targeting the Kuparuk A and C-sands. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 - Detailed Summary of Operations - Directional Plans for 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 - Current wellbore schematic - Proposed CTD schematic The application for sundry approval (10-403) for 31VI-27 was approved on 3/16/2017. If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis................................................................................................:............................ 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................7 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 7 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 7 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7 16. Attachments....................................................................................................................................8 Attachment 1: Directional Plans for 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02......................................8 Attachment 2: Current Well Schematic for 3M-27...........................................................................................................8 Attachment 3: Proposed Well Schematic for 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 ........................8 Page 1 of 8 April 7, 2016 PTD Application: 31111-27A, AL1, AL2, ALk-01, AL3, AL4, AL4-01, AL4-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3M-27A, 3M-27AL1, 3M-27AL2, 3M-27AL2-01, 3M- 27AL3, 3M-27AL4, 3M-27AL4-01, & 3M-27AL4-02. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A and C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3M-27A, 3M-27AL1, 3M-27AL2, 3M-27AL2-01, 3M-27AL3, 3M- 27AL4, 3M-27AL4-01, & 3M-27AL4-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,200 psi. Using the maximum formation pressure in the area of 4,305 psi in 31VI-12 (i.e. 13.4 ppg EMW), the maximum potential surface pressure in 3M-27, assuming a gas gradient of 0.1 psi/ft, would be 3,684 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3M-27 was measured to be 3,591 psi (11.1 ppg EMW) on 9/5/2016. The maximum downhole pressure in the 3M-27 vicinity is to the southeast in the 3M-12 injector at 4,305 psi (13.4 ppg EMW) from August of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 3M-27 have injected gas, so there is a low probability of encountering free gas while drilling the 3M-27 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3M-27 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3M-27 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 8 April 7, 2016 PTD Application: 3M-27A, AL1, AL2, ALk-01, AL3, AL4, AL4-01, AL4-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS 3M-27A 13150' 15200' 6187' 6135' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL1 13100' 15200' 6190' 6105' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL2 14130' 16200' 6127' 6062' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL2-01 12825' 16200' 6203' 6077' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL3 12775' 14375' 6186' 6163' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL4 12825' 15200' 6203' 6135' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL4-01 12875' 16200' 6204' 6062' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-27AL4-02 12583' 14375' 6046' 6167' 2-3/8", 4.7#, L-80, ST-L slotted liner; up into 3-1/2" tubing Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TBurst TVD psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 630 Surface 9-5/8" 40.0 L-80 BTC 0' 5996' 0' 3465' 5750 3090 Production 7" 26.0 L-80 BTC-MOD 0' 13006' 0' 6432' 7240 5410 Tubing 3-1/2" 9.3 L-80 EUE 0' 12598' 0' 6125' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled Page 3 of 8 April 7, 2016 PTD Application: 3M-27A, AL1, AL2, ALk-01, AL3, AL4, AL4-01, AL4-02 tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 31VI-27 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3M-27 Window 02725' MD. 6220' TVD) Using MPD Pumps On 1.5 b m Pumps Off A/C -sand Formation Pressure 11.1 3591 psi 3591psi' Mud Hydrostatic 8.6 2782 psi 2782 psi Annular friction i.e. ECD, 0.08 si/ft 1018 psi 0 psi Mud + ECD Combined no chokepressure) 3800 psi overbalanced —209psi) 2782 psi underbalanced —809psi) Target BHP at Window 11.8 3817 psi 3817 psi Choke Pressure Required to Maintain Target BHP 17 psi 1035 psi 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 for a land based 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3M-27 is a Kuparuk A -sand and C-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize eight laterals to target the A and C sands to the north, west, and south of the 3M-27 parent wellbore. The laterals will add new resources and improve existing recovery. Prior to CTD operations, E-line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 12588' MD will be milled out to a 2.80" ID. The existing A -sand and C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR3-AC will mill a pilot hole to 12755' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 12725' MD. A window will be milled in the 7" casing at 12725' MD to drill and complete the 3M-27 laterals. Page 4 of 8 April 7, 2016 PTD Application: 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, AL4-02 The 3M-27A sidetrack will exit the cement pilot hole at 12725' MD and TD at 15200' MD, targeting the Al sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 13150'MD with an aluminum billet for kicking off the 3M-27AL 1 lateral. The 3M-27AL1 lateral will drill to the north to a TD of 15200' MD targeting the C4 sand. It will be completed with 2-3/8" slotted liner from TD up to 13100' MD with an aluminum billet for kicking off the 3M-27AL2 lateral. The 3M-27AL2 lateral will drill to the west to a TD of 16200' MD targeting the C4 sand. It will be completed with 2-3/8" slotted liner from TD up to 14130' MD with an aluminum billet for kicking off the 3M-27AL2-01 lateral. The 3M-27AL2-01 lateral will drill to the west to a TD of 16200' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12825' MD with an aluminum billet for kicking off the 3M-27AL3 lateral. The 3M-27AL3 lateral will drill to the south to a TD of 14375' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12775' MD with an aluminum billet for kicking off the 3M-27AL4 lateral. The 3M-27AL4 lateral will drill to the north to a TD of 15200' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12825' MD with an aluminum billet for kicking off the 3M-27AL4-01 lateral. The 3M-27AL4-01 lateral will drill to the west to a TD of 16200' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12875' MD with an aluminum billet for kicking off the 3 M-27AL4-02 lateral. The 3M-27AL4-02 lateral will drill to the south to a TD of 14375' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12583' MD. Pre-CTD Work 1. RU Slickline: Obtain SBB P, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3-1/2" tubing tail at 12583' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the A/C -sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR3-AC rig and set BPV. Rilz Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M-27A Sidetrack (Al sand - north) a. Mill 2.80" high -side pilot hole through the cement to 12755' MD. b. Caliper pilot hole. c. Set top of whipstock at 12725' MD. d. Mill 2.80" window at 12725' MD. e. Drill 3" bi-center lateral to TD of 15200' MD. f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 13150' MD. Page 5 of 8 April 7, 2016 PTD Application: 3M-27A, AL1, AL2, ALk.-01, AL3, AL4, AL4-01, AL4-02 3M-27AL1 Lateral (C4 sand - north) a. Kick off of the aluminum billet at 13150' MD. b. Drill 3" bi-center lateral to TD of 15200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 13100' MD. 4. 3M-27AL2 Lateral (C4 sand - west) a. Kickoff of the aluminum billet at 13100' MD. b. Drill 3" bi-center lateral to TD of 16200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 14130' MD. 3M-27AL2-01 Lateral (Al sand - west) a. Kickoff of the aluminum billet at 14130' MD. b. Drill 3" bi-center lateral to TD of 16200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 12825' MD. 6. 3M-27AL3 Lateral (Al sand - south) a. Kickoff of the aluminum billet at 12825' MD. b. Drill 3" bi-center lateral to TD of 14375' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 12775' MD. 7. 3M-27AL4 Lateral (Al sand - north) a. Kick off of the aluminum billet at 12775' MD. b. Drill 3" bi-center lateral to TD of 15200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 12825' MD. 8. 3M-27AL4-01 Lateral (Al sand -west) a. Kick off of the aluminum billet at 12825' MD. b. Drill 3" bi-center lateral to TD of 16200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 12875' MD. 9. 3M-27AL4-02 Lateral (Al sand - south) a. Kickoff of the aluminum billet at 12875' MD. b. Drill 3" bi-center lateral to TD of 14375' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 12583' MD. 10. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install gas lift design. 4. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Page 6 of 8 April 7, 2016 PTD ,application: 3M-27A, AL1, AL2, AL.-01, AL3, AL4, AL4-01, AL4-02 - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running - The 3M-27 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3M-27A 2900' 3M-27AL1 2900' 3M-27AL2 900, 3M-27AL2-01 900, 3M-27AL3 3700' 3M-27AL4 2900' 3M-27AL4-01 900, 3M-27AL4-02 3700' - Distance to Nearest Well within Pool Lateral Name Distance Well 3M-27A 2270' 3M-25 3M-27AL1 2270' 3M-25 Page 7 of 8 April 7, 2016 PTD Application: 3M-27A, AL1, AL2, Alk-01, AL3, AL4, AL4-01, A1-4-02 3M-27AL2 5065' 3M-25 3M-27AL2-01 5065' 31M-25 3M-27AL3 1508' 3M-23 3M-27AL4 2270' 31M-25 3M-27AL4-01 5065' 31M-25 3M-27AL4-02 1508' 3M-23 16. Attachments Attachment 1: Directional Plans for3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 laterals Attachment 2: Current Well Schematic for 3M-27 Attachment 3: Proposed Well Schematic for 3M-27A, AL1, AL2, AL2-01, AL3, AL4, AL4-01, & AL4-02 laterals Page 8 of 8 April 7, 2016 H wog_ we o>� i� LLNm�f C a= �F FAS coo_ Q 0 O C O U (ur/gsn 099) WITION/(-Alnos 9 KUP PROD 3M-27 Lonocornimps i & I Alaska, Inc. Well Attributes IMaxAngle&MD ITD Wellbore APl/UWI Field Name Wellbc ¢ S atus re, 500292263700 KUPARUK RIVER UNIT PROD (°) MD (ftKB) Act 72.79 3,068.90 Bum (ftKB) 13,006.0 Comment H2S (pp.)Date SSSV: NIPPLE 220 10/23/2015 Annotation End Date Last WO: 3/17/2008 KB-Grd (ft) Rig Release Date 1/19/1996 3M-27, 9/6120162:52:47 PM Verlicalscherrua6c actual _................._..._.._._....._........._.._......_... CONDUCTOR; 42.0-121.0 GAS LIFT; 3,543.1 SURFACE; 41.0-5,995.9� GAS LIFT; 6.918.1 GAS LIFT; %761.8 GAS LIFT; 11,666.3 GAS LIFT; 12,378.1 SLEEVE; 12,433.1 SEAL ASSY; 12,482.E PBR; 12,48CII Packer, 12,498.2 NIPPLE; 12,515.1 APERF; 12,696.0-12,708.0- Fish; 12,727.0 IPERF; 12,724.0-12,744.0- APERF; 12,764.0-12,764.0- Fish; 12,864.0 Fish; 12,911.0 PRODUCTION; 38.5-13,008.0 _.._........_. IICasing f 1 Annotation Deplh (ftKB) End Date Last Tag: SLM 12,667.0 9/212016 Annotation Last Motl By End Dale Rev Reason: H2S 8 TAG pproven 9/6/2016 Casing Strin& Description I OD (in) CONDUCTOR 16 ID (in) 15.062 I Top (ftKB) 42.0 Set Depth (ftK9) Set 121.0 Depth (TVD)... 121.0 WULan (1... 62.58 Grade H40 Top Thread WELDED Casing Description OD (in) SURFACE 9 5/8 ID (In) 8.835 Top (ftKB) 41.0 Set Depth IRKS) Set 5.995.9 Depth (TVD)... 3,465.3 WULen (I... 40.00 Grade L-80 Top Thread BTC Casing Description OD (in) PRODUCTION 7 ID (in) 6.276 Top (ftKB) 38.5 Set Depth (ftKB) set 13,006.0 Depth (TvD)... 6,432.3 WULen (I... 26.00 Gmtle L-80 Top Threatl BTC-MOD Tubing Strings Tubing Description Stflng Me... ID (in) Top (ftKB) Set Depth 1ft1 Sef Depth (ND) (... WI (Ib!/t) Grade Top Connection TUBING 31/2 2.992 9.9 12,539.5 6,082.2 9.30 L-80 EUEBrdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (") Item Des Co. Nominal ID (in) 9.9 9.9 0.02 HANGER FMC GEN IV TUBING HANGER 3.500 495.1 494.7 6.65 NIPPLE CAMCO IDS LANDING NIPPLE 2.875 12,433.1 6.005.2 45.12 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 12.482.6 6,040.5 43.55 SEAL ASSY 8040 SEALS LOCATOR W/ 2' SPACE OUT 2.960 12,484.8 6,042.2 43.48 PER BAKER 8040 PBR 4.000 12,498.2 6,051.9 43.05 Packer BAKER FHL PACKER 2.900 12,515.1 6,064.3 42.70 1 NIPPLE I XNIPPLE 2.8 33 12,532.E 6,077.2 42.59 OVERSHOT BAKER PO -BOY OVERSHOTWI 6.00' SWALLOW 3.625 Tubing Description Sfdng (in) I Top (ftKB) IS.t Depth (ft.. Set Depth TVD) (... Wt (IbM) Grade Top Connection TUBING - Original 31/2 2.992 12,533.5 12,597.9 6,125.4 9.30 L-80 ABM EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Intl (°) Item Des Cam Nominal I❑ (in) 12,549.5 6,089.6 42.49 NIPPLE CAMCO W NIPPLE 2.812 12,557.5 6,095.5 42.44 PBR BAKER PER w/ 1O' STROKE 3.000 12,570.6 6,105.2 42.36 PACKER BAKER FHL PACKER 3.000 12,587.9 6,118-0 42.26 NIPPLE CAMCO D NIPPLE 2.750 12,597.2 6,124.8 42.20 SOS/TTL I BAKER SHEAR OUT SUB 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVO) (ftKB) Top"" (") Des Com Run Date ID (in) 12,727.0 6,221.9 41.20 Fish 1 1/2" OV on RK Dropped Downhole 12/26/1997 12/26/1997 12,864.0 6.325.2 40.94 Fish 1" GLV on BK Lost downhole 6/2/1996 6/2/1996 12,911.0 6,360.7 41.07 Fish JUNK Milled up prematurely set packer & 3 1/2" 512/1996 Tailpipe assembly; Pushed JUNK to bottom on 5/2196 Perforations & Slots Top (ftKB) Stm (ftKB) Top (TVD) glen (ft)(B) [TVD) (ftKB) Zone (shots!( Dale Shot Dens t) Type Core 12,696.0 12,708.0 6,198.6 6,207.6 C4, 3M-27 9/6/2008 6.0 APERF 2.5" deg PJ HMX 2506, 60 PHASE 12.724.0 12,744.0 6,219.7 6,234.7 C4, 3M-27 5/12/1996 4.0 IPERF 180 90 hole; deg. phasing; deg F/ lowside of 2 1/8" EnerJet 12,764.0 12,784.0 6,249.8 6,264.9 A-1, 3M-27 7/20/1999 4.0 APERF 180 90 2.5" deg phasing; (+/ deg f/lowside of hole; HSD Mandrel Inserts St at! on N Top (ft(B) Top [TVD) (ftKB) Make OD (in) So, Valve Type Latch Type Port Size (in) TRORun (psi) Run Date Co. 1 3,543.1 2,599.4 CAMCO dKBMG 1 GAS LIFT GLV BK 0.125 1,338.0 4/6/2008 2 6,918.1 3,801.5 CAMCO 1 GAS LIFT GLV SK 0.15E 1,347.0 4/6/2008 3 9,761.8 4,800.1 CAMCO 1 GAS LIFT GLV BK 0.188 1,365.0 4/6/2008 4 11,666.3 5,546.7 CAMCO i GAS LIFT GLV BK 0188 1,344.0 4/6/20085 12,378.1 5,966.9 CAMCO 1 GAS LIFT OV BK 0.250 0.0 4/5/2008 Notes: General & Safety End Date Annotation 5,2512005 NOTE: 3' sleeve patch installed over SURF CSG extemal corrosion 0'-3' 11/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 u7 n cq N II ❑ ❑ U 0) rn � /'7�� N V O N O) O_ C _d B Z C "O 'O co C W cu J W Cn ❑ LO V LO -; N M U of N N M C'J 0 CC E d .s= U 0 F-- U m 0 IL 0 L a_ N M N C, 0 Q. (h N � Q ❑ ❑ II ao v O n o� ❑ N _ q c7 Ci ao ❑ . a C E CO v m ro V C U r 01 O n . y V t L ❑ V Iq M CV N r ❑ O Iq N .N- N❑ r C9 0310 � r`` to t/ to O_ ON l//�� O) Ol iq N V J Zo 'O m Y 47 Q /rN��.�� Y ❑ N U d r O p. V d U O 0) CO O m � Z O C �C) n o m 2 m U v U ado t=i n CL O d LL 0, w N@ Y YY G Y E .V Y N Z cn m m m X m U m m m m p p r m 3p O 0 o L 3 L Cl! -• J(O m 30 V O N O n p N �N S N O. m N, V Jlf)— 8t 3O O i7 N�C � C N@m O Op two MC m0� J N ?i0 dO'. N._. 3 Cl co NCO J = Q Q O Q p,m r�p� m Vm N NV NVm ^ J�O Opp m p c H 0 Fr�all I'1' r'' �' O p V 3N m 11 it YYYYYY � IIYIIY III � ' _ ❑ � ❑ N ❑ I � ❑ n co J a� uo ❑ aov n C n o N Ct 03 r, 0 - M O # LO r V O_ I rC,@ a I I c;;t k O C O) N Y 0co n L o o m m CO .0 co n N N N Q r ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3M Pad 3M-27 3M-27AL4-02 Plan: 3 M-27AL4-02_wp00 Standard Planning Report 03 April, 2017 WE P k I BAKER NIJGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-27 Wel I bore: 3M-27AL4-02 Design: 3M-27AL4-02_wp00 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-27 Mean Sea Level 3M-27 @ 68.00usft (3M-27) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor NAaI BAKER HUGHES Site Kuparuk 3M Pad Site Position: From: Map Northing: Easting: 6,016,202.17 506,126.99usft usft Latitude: Longitude: 70° 27' 19.780 N 149° 56' S9.998 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.05 ° Well 3M-27 Well Position +N/-S 0.00 usft Northing: 6,016,606.24 usft Latitude: 70° 27' 23.753 N +E/-W 0.00 usft Easting: 506,294+30 usft Longitude: 149° 56' 55.073 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3M-27AL4-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°► (nT) BGGM2016 7/1/2017 17.53 81.00 57,543 Design 3M-27AL4-02_wp00 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,875.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 200.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (I (usft) (usft) (usft) (°/1o0ft) (°/100ft) (°/10oft) (°) Target 12,875.00 91.16 294.32 6,204.08 2,574.92 -10,020.85 0.00 0.00 0.00 0.00 13,135.00 93.03 177.20 6,188.87 2,453.24 -10,200.02 45.00 0.72 -45.04 274.00 13,235.00 93.01 170.20 6,183.59 2,354.04 -10,189.07 7.00 -0.02 -7.01 270.00 13,335.00 91.18 163.43 6,179.92 2,256.80 -10,166.29 7.00 -1.83 -6.76 255.00 13,535.00 89.22 177.30 6,179.21 2,060.12 -10,132.90 7.00 -0.98 6.93 98.00 13,760.00 89.25 193.05 6,182.24 1,836.76 -10,153.11 7.00 0.01 7.00 90.00 14,260.00 92.82 227.88 6,172.93 1,412.47 -10,402.55 7.00 0.71 6.97 84.00 14,375.00 93.49 219.84 6,166.58 1,329+75 -10,482.05 7.00 0.58 -6.99 275.00 41312017 3:13:44PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips rigs ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3M-27 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-27 @ 68.O0usft (3M-27) Site: Kuparuk 3M Pad North Reference: True Well: 3M-27 Survey Calculation Method: Minimum Curvature W e l l b o re: 3 M-27A L 4-02 Design: 3M-27AL4-02_wp00 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/lo0ft) (°) (usft) (usft) 12,875.00 91.16 294.32 6,204.08 2,574.92 -10,020.85 1,007.70 0.00 0.00 6,019,172.43 496,272.28 TIP/KOP 12,900.00 91.92 283.09 6,203.40 2,582.92 -10,044.48 1,008.26 45.00 -86.00 6,019,180.41 496,248.65 13,000.00 93.97 238.07 6,197.98 2,567.04 -10,140.47 1,056.02 45.00 -86.30 6,019,164.45 496,152.68 13,100.00 93.70 192.97 6,190.93 2,487.93 -10,196.94 1,149.67 45.00 -88.74 6,019,085.30 496,096.28 13,135.00 93.03 177.20 6,188.87 2,453.24 -10,200.02 1,183.33 45.00 -91.92 6,019,050.61 496,093.23 End 45 dls, Start 7 dls - 13,200.00 93.02 172.65 6,185.43 2,388.60 -10,194.29 1,242.10 7.00 -90.00 6,018,985.99 496.099.02 13,235.00 93.01 170.20 6,183.59 2,354.04 -10,189.07 1,272.79 7.00 -90.24 6,018,951.44 496,104.26 3 13,300.00 91.83 165.80 6,180.84 2,290.53 -10,175.57 1,327.85 7.00 -105.00 6,018,887.95 496,117.82 13,335.00 91.18 163.43 6.179.92 2,256.80 -10,166.29 1,356.37 7.00 -105.19 6.018,854.23 496,127.13 4 13,400.00 90.55 167.94 6,178.94 2,193.84 -10,150.22 1,410.04 7.00 98.00 6,018,791.29 496,143.24 13,500.00 89.56 174.87 6,178.84 2,095.03 -10,135.29 1,497.79 7.00 98.07 6,018,692.50 496.158.26 13,535.00 89.22 177.30 6,179.21 2,060.12 -10,132.90 1,529.78 7.00 98.07 6,018,657.59 496,160.68 5 13,600.00 89.22 181.85 6,180.10 1,995.14 -10,132.41 1,590.67 7.00 90.00 6,018,592.62 496,161.22 13,700.00 89.24 188.85 6,181.45 1,895.65 -10,141.72 1,687.35 7.00 89.94 6,018,493.13 496,151.99 13,760.00 89.25 193.05 6,182.24 1,836.76 -10,153.11 1,746.58 7.00 89.84 6,018,434.23 496.140.65 6 13.800.00 89.54 195.83 6,182.66 1,798.03 -10,163.09 1,786.39 7.00 84.00 6,018,395.50 496,130.72 13,900.00 90.28 202.79 6,182.82 1,703.71 -10,196.14 1,886.32 7.00 83.97 6.018,301.17 496,097.75 14,000.00 91.01 209.76 6.181.69 1,614.10 -10,240.37 1,985.65 7.00 83.96 6,018,211.53 496,053.59 14,100.00 91.73 216.72 6.179.30 1,530.54 -10,295.13 2,082.91 7.00 84.04 6,018,127.93 495.998.91 14,200.00 92.42 223.69 6,175.67 1.454.26 -10,359.60 2,176.63 7.00 84.21 6,018,051.61 495,934.51 14,260.00 92.82 227.88 6,172.93 1,412.47 -10,402.55 2,230.59 7.00 84.46 6,018,009.78 495,891.60 7 14,300.00 93.06 225.08 6,170.87 1,384.97 -10,431.51 2,266.34 7.00 -85.00 6,017,982.26 495,862.66 14,375.00 93.49 219.84 6,166.58 1,329.75 -10,482.05 2,335.52 7.00 -85.14 6,017,927.00 495,812.18 Planned TD at 14375.00 41312017 3:13.44PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips .ft. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-27 W e l l b o re: 3 M-27AL4-02 Design: 3M-27AL4-02_wp00 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-27 Mean Sea Level 3M-27 @ 68.00usft (3M-27) True Minimum Curvature Target Name hittmiss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting Shape (1) (1) (usft) (usft) (usft) (usft) (usft) 3M-27A_Faultl 0.00 0.00 6,158.00 2,553.021,130,395.25 6,020,114.00 plan misses target center by 1140416.10usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 6,158.00 0.00 0.00 6,020,114.00 Point 6.158.00 1.00 1.00 6,020,115.00 3M-27AL3_Fault2 0.00 0.00 6,188.00 629.171,129,993.58 6.018,190.00 plan misses target center by 1140016.09usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 6,188.00 0.00 0.00 6,018,190.00 Point 2 6.188.00 1.00 1.00 6,018.191.00 3M-27AL3_Fault2_M 0.00 0.00 0.00 629.171.129,993.58 6.018,190.00 plan misses target center by 1140032.97usft at 12875.00usft MD (6204.06 TVD, 2574.92 N,-10020.85 E) Rectangle (sides W1,500.00 1-11.00 D0.00) 3M-27AL4-02_T01 0.00 0.00 6,162.00 67.461,129,577.07 6,017,628.00 plan misses target center by 1139600.67usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Point 31VI-27 CTD Polygon Sot 0.00 0.00 0.00 10.631.129,376.00 6.017,571.00 plan misses target center by 1139416.62usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 0.00 0.00 0.00 6,017,571.00 Point 0.00 1,549.65 635.29 6,019,121.03 Point 0.00 1,306.29 1,066.14 6,018,878.06 Point4 0.00 388.33 899.40 6,017,960,05 Point 5 0.00 -90.36 437.97 6,017,481.02 Point 6 0.00 0.00 0.00 6,017,571.00 3M-27 CTD Polygon We 0.00 0.00 0.00 4,589.101,128,180.75 6,022,148.00 plan misses target center by 1138220.28usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 0.00 0.00 0.00 6,022.148.00 Point 0.00 -2,757.14 2,351.05 6,019,393.12 Point 3 0.00 -3,440.92 1.991.47 6,018,709.11 Point 0.00 -2,499.35 1,383.16 6,019,650.07 Point 0.00 -436.73-394.39 6,021,710.98 Point 0.00 0.00 0.00 6,022,148.00 3M-27AL3_Faultl 0.00 0.00 6,183.00 1,095.211,130,000.98 6,018,656.00 plan misses target center by 1140022.78usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 6,183.00 0.00 0.00 6,018.656.00 Point 2 6,183.00 1.00 1.00 6,018,657.00 3M-27A_Fault1_M 0.00 0.00 0.00 2,553.021,130,395.25 6,020,114.00 plan misses target center by 1140432.97usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Rectangle (sides W1,500.00 1-11.00 D0.00) 3M-27 CTD Polygon Not 0.00 0.00 0.00 3,355.381,131,253,01 6,020,917.00 plan misses target center by 1141290.99usft at 12875.00usft MD (6204.08 TVD, 2574.92 N,-10020.85 E) Polygon Point 1 0.00 0.00 0.00 6,020,917.00 Point 0.00 -2,146.46-952.80 6,018,769.95 Point 0.00 -1,769.89-1,622.57 6,019,145.92 Point 0.00 328.43-503.79 6,021,244.97 Point 5 0.00 0.00 0.00 6,020,917.00 3M-27AL3_Faultl_M 0.00 0.00 0.00 1,095.211,130,000.98 6,018,656.00 - plan misses target center by 1140039.66usft at 12875.00usft MD (6204.08 TVD, 2574.92 -------1- i,.:a- -1 ❑nn - - - - nm N,-10020.85 E) Latitude Longitude 1,636,574.00 70' 13' S0.989 N 140' 47' 43.316 W 1, 636, 574.00 1, 636, 575.00 1,636,174.00 70° 13' 32.900 N 140' 48' 3.201 W 1,636,174.00 1,636,175.00 1,636,174.00 70° 13' 32.900 N 140° 48' 3.201 W 1,635,758.00 70° 13' 28.059 N 1400 48' 17.586 W 1,635,557.00 70° 13' 27.802 N 140° 48' 23.598 W 1, 635, 557.00 1,636,190.92 1,636,621.93 1, 636, 455.98 1,635, 995.00 1,635, 557.00 1.634,358.00 70' 14' 14.017 N 140° 48' 37.999 W 1, 634, 358.00 1,636,711.14 1, 636, 352.18 1, 635, 743.13 1,633.964.02 1,634,358.00 1.636,181.00 70° 13' 37.414 N 140' 48' 0.963 W 1,636,181.00 1,636,182.00 1,636,574.00 700 13' 50.989 N 1400 47' 43.316 W 1,637,431.00 700 13' 57.516 N 140° 47' 15.219 W 1, 637, 431.00 1,636,480.11 1,635, 810.09 1,636,926.98 1,637,431.00 1,636,181.00 70' 13' 37.414 N 140' 48' 0.963 W 41312017 3:13:44PM Page 4 COMPASS 5000.1 Build 74 - ConocoPhillips rigs ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3M-27 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-27 @ 68.00usft (3M-27) Site: Kuparuk 3M Pad North Reference: True Well: 3M-27 Survey Calculation Method: Minimum Curvature Wel I bore: 3M-27AL4-02 Design: 3M-27AL4-02_wp00 Casing Points Measured Depth (usft) 14,375.00 Vertical Depth (usft) 6,166.58 2 3/8" Name Casing Hole Diameter Diameter (in) (in) 2.375 3,000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 12,875.00 6,204.08 2,574.92 -10,020.85 TIP/KOP 13,135.00 6,188.87 2,453.24 -10,200.02 End 45 dls, Start 7 dls 13,235.00 6,183.59 2,354.04 -10,189.07 3 13,335.00 6,179.92 2,256.80 -10,166.29 4 13,535.00 6,179.21 2,060.12 -10,132.90 5 13,760.00 6,182.24 1,836.76 -10,15111 6 14,260.00 6,172.93 1,412.47 -10,402.55 7 14,375.00 6,166.58 1,329.75 -10,482.05 Planned TD at 14375.00 41312017 3:13:44PM Page 5 COMPASS 5000.1 Build 74 111-1 Baker Hughes INTEQ F&AM ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-27 Well Error: 0.00 usft Reference Wellbore 3M-27AL4-02 Reference Design: 3M-27AL4-02_wp00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3M-27 3M-27 @ 68.00usft (3M-27) 3M-27 @ 68.00usft (3M-27) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 3M-27AL4-02_wp00 =iltertype: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 25.00usft Error Model: ISCWSA depth Range: 12,875.00 to 14,375.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,630.70 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/30/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 265.00 12,692.45 3M-27 (3M-27) MWD MWD - Standard 12,692.45 12,775.00 3M-27A_wp01 (3M-27A) MWD MWD - Standard 12,775.00 12,825.00 3M-27AL4_wp00 (3M-27AL4) MWD MWD - Standard 12,825.00 12,875.00 3M-27AL4-01_wp00 (3M-27AL4-01) MWD MWD - Standard 12,875.00 14,375.00 3M-27AL4-02_wp00 (3M-27AL4-02) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name -- 14,375.00 6,234.58 —2 3/8" 2-3/8 — 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-09 - 3M-09 - 3M-09 3M-10 - 3M-10 - 3M-10 3M-11 - 3M-11 - 3M-11 3M-12 - 3M-12 - 3M-12 3M-13 - 3M-13 - 3M-13 3M-14 - 3M-14 - 3M-14 3M-14 - 3M-14A- 3M-14A_wp07 (Draft A) 3M-14 - 3M-14AL1 - 3M-14AL1_wp03 3M-14 - 3M-14AL2 - 3M-14AL2_wp06 3M-14 - 3M-14AL3 - 3M-14AL3_wp00 3M-15 - 3M-15 - 3M-15 3M-16 - 3M-16 - 3M-16 3M-17 - 3M-17 - 3M-17 3M-18 - 3M-18 - 3M-18 3M-19 - 3M-19 - 3M-19 3M-20 - 3M-20 - 3M-20 3M-23 - 3M-23 - 3M-23 3M-24 - 3M-24 - 3M-24 3M-24 - 3M-241_1 - 3M-24L1 3M-24 - 3M-241-1-01 - 3M-2411-01 3M-24 - 3M-2411-01 PB1 - 3M-24L1-01 PB1 3M-24 - 3M-24L1-02 - 3M-241-1-02 3M-24 - 31M-2411-03 - 3M-241-1-03 3M-24 - 31M-241-1 P131 - 31M-2411 PB1 3M-24 - 3M-241_1 PB2 - 3M-24L1 PB2 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 313012017 5:11:34PM Page 2 COMPASS 5000.1 Build 74 Baker Hughes INTEQ rigs ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc -Kup2 Local Co-ordinate Reference: Well 3M-27 Project: Kuparuk River Unit ND Reference: 3M-27 @ 68.00usft (3M-27) Reference Site: Kuparuk 3M Pad MD Reference: 3M-27 @ 68.00usft (3M-27) Site Error: 0.00 usft North Reference: True Reference Well: 3M-27 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3M-27AL4-02 Database: OAKEDMP2 Reference Design: 3M-27AL4-02_wp00 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 3M Pad 3M-24 - 31M-2411 P133 - 31M-241-1 P133 Out of range 3M-25 - 3M-25 - 3M-25 Out of range 3M-25A- 3M-25A- 3M-25A Out of range 3M-26 - 3M-26 - 3M-26 Out of range 3M-27 - 3M-27 - 3M-27 12,885.59 12,950.00 118.47 13.44 115.07 Pass - Major Risk 3M-27 - 3M-27A - 3M-27A_wp01 12,875.00 12,875.00 0.00 2.31 -1.88 FAIL - Minor 1/10 3M-27 - 3M-27AL1 - 3M-27AL1_wp01 12,875.00 12,875.00 0.00 2.31 -1.87 FAIL - Minor 1/10 3M-27 - 3M-27AL2 - 3M-27AL2_wp02 12,875.00 12,875.00 0.00 2.31 -1.87 FAIL - Minor 1/10 3M-27 - 3M-27AL2-01 - 3M-27AL2-01_wp01 12,875.00 12,875.00 0.00 2.31 -1.87 FAIL- Minor 1/10 3M-27 - 3M-27AL3 - 3M-27AL3_wp02 13,821.18 13,725.00 5.46 1.42 4.04 Pass - Minor 1/10 31M-27 - 3M-27AL4 - 3M-27AL4_wp00 12,875.00 12,875.00 0.00 1.09 -0.22 FAIL - Minor 1/10 3M-27 - 3M-27AL4-01 - 3M-27AL4-01_wp00 12,875.00 12,875.00 0.00 0.28 -0.22 FAIL - Minor 1110 Offset Design Kuparuk 3M Pad - 3M-27 - 3M-27 - 3M-27 Offset Site Error: 0.00 usft Survey Program: 265-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 12,885,59 6,271.83 12,950,00 6,390.10 1.34 2,60 112.57 2,574.06 -10,035s4 2-11/16 118,47 13.44 115,07 Pass - Major Risk, CC, ES, SF 12,901.18 6,271.36 12,975.00 6408,94 146 2.85 105.47 2,577.36 -10,051.73 2-11/16 137,84 14,70 134.15 Pass - Major Risk 12,916.55 6,270.78 13,000.00 642T78 1,58 3.10 97.70 2,580.67 -10,067s3 2-11/16 157.24 15.79 153.35 Pass - Major Risk 12,926.06 6,270,36 13,01600 6,439.84 166 3,26 92.59 2,582,78 -10,078A4 2-11/16 169,69 16.38 165, 72 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 313012017 5:11:34PM Page 3 COMPASS 5000.1 Build 74 W ew to Lllz we �b9a � IA � S 0 E 0 \ / cl) + 3 ( Ams)m&oI ma ow :2 TRANSMITTAL LETTER CHECKLIST WELL NAME: kAL __�M 4AA q —OZ PTD: a I �_ blot 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 The permit is for a new wellbore segment of existing well Permit LATERAL No. Z- OS3 , API No. 50-C -�26 31 -01 - (Jp . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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 (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2170600 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 3M-27AL4-02 Program DEV Well bore seg ❑d DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025523, Surf Loc; ADL0025522, Portion of Well; ADL0355032, Top Prod Intery & TD. 3 Unique well name and number Yes KRU 3M-27AL4-02 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432D has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes PKB 4/14/2017 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),0.2.A-D) NA 18 Conductor string provided NA Conductor set in KRU 3M-27 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 3M-27 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 4305 psig(13.4 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 4/21/2017 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3684 psig;w ill test BOPS to 4200 psig 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 112S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 3M-Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 13.4 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 4/14/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date Lk'