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Home My WebLink About220-022From:Guhl, Meredith D (OGC) To:Taylor, Jenna; Conklin, Amy A; Hobbs, Greg S Subject:Expired CRU Permits Date:Wednesday, April 27, 2022 1:48:00 PM Hello, The following Permits to Drill, issued to ConocoPhillips Alaska, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. CRU CD5-11L1, PTD 220-008, Issued 27 January 2020 CRU CD5-11L1-01, PTD 220-009, Issued 27 January 2020 CRU CR4-215L1-01, PTD 220-022, Issued 6 March 2020 If you have any questions, please contact me. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger CTD Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Colville River Field, Nanuq Oil Pool, CD4-215L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 220-022 Surface Location: 2952' FNL, 341' FEL, Sec. 24, T11N, R4E, UM Bottomhole Location: 3709' FNL, 405' FEL, Sec. 23, TI IN, R4E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced lateral well. The permit is for a new wellbore segment of existing well Permit No. 206-157, API No. 50-103- 20539-00-00. Production should continue to be reported as a function of the original API number stated above. 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. 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, I V'-' J e y ice C ' DATED this -9 day of March, 2020. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI: PERMIT TO DRILL HLUERIF0 N MAR 4 2020 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 El Stratigraphic Test ❑ Development - Oil El 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 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 CD4-2151_1-01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14,100' TVD: 6210' Colville River Field / Nanuq Nanuq Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2952' FNL, 341' FEL, Sec. 24, T11N, R4E, UM ADL 380077, 384209, 388902 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2008' FNL, 4381' FEL, Sec. 25, T11N, R4E, UM LONS 97-007 3/13/2020 9. Acres in Propertv: 14. Distance to Nearest Property: Total Depth: 3709' FNL, 405' FEL, Sec. 23, T11 N, R4E, UM 2560 2240' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 57' 15. Distance to Nearest Well Open Surface: x- 377902 y- 5957461 Zone- 4 GL / BF Elevation above MSL (ft): 13' to Same Pool: 127' (CD4-23) 16. Deviated wells: Kickoff depth: 10,150 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3636 Surface: 3014 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 4420' 9580 6220' 14,000' 6210' 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): 14,761' 6205' N/A 14,675' 6212' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" Pre -Installed 114' 114' Surface 2817' 9-5/8" 397 sx AS Lite, 231 sx Class G 2854' 2392' Intermediate 9478' 7" 195 sx LiteCRETE, 321 sx Class G 9514' 6216' Liner 5314' 3-1/2" N/A 14,675' J 6212' Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 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 El 20 AAC 25.050 requirements✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughlin %7 Authorized Name: James Ohlinger Contact Email: R an.MCLaU hlin COP.com Authorized Title: Staff Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: -7/3/�a Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: aao —02; 50- 10 0 15 dQ Date: requirements. 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: Rr Other:�vv �� Yfsr�li�� l3 3�C1d r Samples req'd: Yes ❑ No[� Mud log req'd: Yes❑ No[?/ �SZ�� H2S measures: Yes ❑ NoQDirectional svy req'd: YesNKNo❑ rf�svr2 -7 '!Vab)n�egeption req'd: Yes ❑ No Inclination -only svy req'd: Yes❑ No[� 14 i%Gi /—% G} Yl G' 7`D a O 4.,T C 2 5-, p rj' �(o Post initial injection MIT req'd: Yes ❑ No [E�-- ci 7 at l l o w f� c k�� d �o �� f �o lo-C a ✓ � oiht � for fht � a rf� f" Gcc t'tra � . APPROVED BY 3 Approved by: COMMISSIONER THE COMMISSION Date: f % Form 10-401 evi 2017 (/r//'_ 3�� -0 This per it is valid for 24 mo th fro h t proval per 20 AAC 25.005 g) 3l>�( U I� Submit Form and Attachments in D plicate p2G 5y� �l ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 25, 2020 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permits to drill two laterals out of CD4- 215 (PTD# 206-157) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in April 2020. The objective will be to drill two laterals CRU CD4-2151_1 and CD4-215L1-01 targeting the Nanuq interval. 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 the permit to drill applications are the following documents: — Permit to Drill Application Forms (10-401) for CD4-2151_1 and CD4-2151-1-01 — Detailed Summary of Operations — Directional Plans for CD4-2151_1 and CD4-2151-1-01 — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals `CD4-2151-1 and CD4-2151-1-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(t) 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...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for CD4-2151-1 and CD4-2151-1-01 laterals..................................................................6 Attachment 2: Current Well Schematic for CD4-215.......................................................................................................6 Attachment 3: Proposed Well Schematic for CD4-2151-1 and CD4-2151-1-01 laterals....................................................6 Page 1 of 6 February 25 , 2020 PTD Application.: C134-2151_1 & C134-2151-1-01 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 CD4-2151_1 and CD4-2151-1-01. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the Nanuq package in the Alpine reservoir. See attached 10-401 form for surface and subsurface coordinates of the CD4-2151_1 and CD4-2151-1-01 laterals. 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 3,500 psi. Using the maximum formation pressure in the area of 3636 psi in CD4-214 (i.e. 11.7 ppg EMW), the maximum potential surface pressure in CD4-215, assuming a gas gradient of 0.1 psi/ft, would be 3014 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 CD4-215 was measured to be 1971 psi (6.2 ppg EMW) on 11/13/2019. The maximum downhole pressure expected while drilling based on offset wells and pressure management plans is 3636 psi which equates to 11.2 ppg EMW. �/ Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to CD4-215 have injected gas, so there is a possibility of encountering free gas while drilling the CD4-215 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 CD4-215 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 CD4-215 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 6 February 25, 2020 PTD Applicatio►,. C134-2151-1 & CD4-2151-1-01 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 CD4-2151_1 10,150' 14,000' 6187' 6152' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to CD4-215L1-01 9580' 14,000' 6163' 6153' 2-3/8", 4.7#, L-80, ST-L slotted liner and sealbore deployment sleeve Existing Casing/Liner Information Category pp Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 65.0 H-40 Welded Surface 114' Surface 114' 1640 670 Surface 9-5/8" 40.0 L-80 Buttress Surface 2854' Surface 2392' 3520 2020 Production 7" 26.0 L-80 BTCM Surface 9514' Surface 6214' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE8rdMOD Surface 9380' 1 Surface 6197' 8430 7500 Liner 3-1/2" 9.3 L-80 SLHT 9361' 1 14,675' 1 7501' 6212' 8430 1 7500 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 PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. If higher pressures are encountered the NaBr will be weighted up, or completion fluid will be switched to potassium formate. JManaged Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation 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 tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the CD4-215 laterals we will target a constant BHP of 11.4 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. Page 3 of 6 February 25, 2020 PTD Applicatics... CD4-215L1 & C134-2151-1-01 Pressure at the CD4-215 Window 9600' MD, 6222' TVD Usin MPD Pumps On 1.8 b m Pumps Off Nanug Formation Pressure 6.2 2006 psi 2006 psi Mud Hydrostatic 8.6 2782 psi 2782 psi Annular friction i.e. ECD, 0.08 si/ft 768 psi 0 psi Mud + ECD Combined no chokepressure) 3550 psi Overbalanced - 1544psi) 2782 psi Overbalanced - 776psi) Target BHP at Window 11.4 3688 psi 3688 psi Choke Pressure Required to Maintain Target BHP 138 psi 906 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 CD4-214 is a Nanuq producer equipped with 3-1/2" tubing and 7" produciton casing. The CTD sidetrack will utilize two laterals to target the Nanuq lobes 3 and 4 to the northwest of CD4-215. Nabors CDR3-AC will set a mechanical whipstock inside the 3-1/2" slotted liner at the planned kick off point of 9600' MD. The CD4-215 lateral will exit through the 3-1/2" liner at 9600' MD and be drilled to a TD of 14,000' MD, targeting the Nanuq lobe 3 to the Northwest. It will be completed with 2-3/8" slotted liner from TD up to 10,150' MD with an aluminum billet for kicking off the CD4-2151-1-01 lateral. The CD4-2151-1-01 lateral will drill to a TD of 14,000' MD targeting the Nanuq lobe 4 to the Northwest. It will be completed with 2-3/8" slotted and solid liner from TD up into the 3-1/2" liner at 9580' MD. Page 4 of 6 February 25, 2020 PTD AaDlicatioL,... C134-2151_1 & CD4-2151_1-01 Pre-CTD Work 1. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. CD4-2151_1 Lateral (Nanuq lobe 3 - Northwest) a. Set top of whipstock at 9600' MD. b. Mill 2.80" window at 9600' MD. c. Drill 3" bi-center lateral to TD of 14,000' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 10,150' MD. 3. CD4-2151-1-01 Lateral (Nanuq lobe 4 - Northwest) a. Kickoff of the aluminum billet at 10,150' MD. b. Drill 3" bi-center lateral to TD of 14,100' MD. c. Run 2-3/8" slotted liner and solid liner from TD up to 9580' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. — Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. — The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is 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 CD4-215 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. Page 5 of 6 February 25, 2020 PTD Applicatio... CD4-2151_1 & CD4-2151-1-01 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 Alpine Waste Injection Facility for grind and inject disposal. • Incidental fluids generated from drilling operations will also be injected at the Alpine Waste Injection Facility in disposal well (CD1-01A) or trucked to Kuparuk 1 B disposal facilities if the Alpine facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Alpine 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 Lateral Name Distance CD4-215L1 2240' CD4-215L1-01 2240' - Distance to Nearest Well within Pool Lateral Name Distance Well CD4-215L1 167' CD4-23 CD4-215L1-01 127' CD4-23 16. Attachments Attachment 1: Directional Plans for CD4-215L1 and CD4-215L1-01 laterals Attachment 2. Current Well Schematic for CD4-215 Attachment 3: Proposed Well Schematic for CD4-215L1 and CD4-215L1-01 laterals Page 6 of 6 February 25, 2020 N_ ^^Ut `G 01 C South( -)/North(+) (450 usft/in) v fn � A C n ay N r O ry ConocoPs philli ConocoPhillips Alaska Inc WNS Western North Slope CD4 Nanuq Pad CD4-215 C134-2151-1-01 Plan: CD4-215L1-01 wp01 (Draft A) Standard Planning Report 13 February, 2020 Baker Hughes g ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4-215 Wellbore: CD4-2151-1-01 Design: CD4-2151-1-01 wp01 (Draft A) ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Baker Hughes Well CD4-215 Mean Sea Level CD4-215 : @ 56.55usft (CD4-215 :) True Minimum Curvature Project Western North Slope, 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 Site CD4 Nanuq Pad Site Position: Northing: 5,957,526.10 usft Latitude: 70' 17' 32.966 N From: Map Easting: 378,174.70usft Longitude: 150' 59' 10.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.93 ° Well CD4-215 Well Position +N/-S 0.00 usft Northing: 5,957,460.92 usft Latitude: 70' 17' 32.281 N +E/-W 0.00 usft Easting: 377,902.36 usft Longitude: 150° 59' 18.669 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.80 usft Weilbore CD4-2151-1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BG G M 2018 12/10/2019 15.90 80.71 57,364 Design CD4-2151-1-01 wp01 (Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 10,150.00 Vertical Section: Depth From (TVD) +Nl-S +E/-W Direction (usft) (usft) (usft) (°) - -19.80 0.00 0.00 330.00 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) (°1100usft) (°/100usft) (°/100usft) (°) Target 10,150.00 90.00 325.33 6,186.55 -4,334.89 -4,039.19 0.00 0.00 0.00 0.00 10,300.00 99.08 330.62 6,174.68 -4,208.32 -4,118.41 7.00 6.05 3.53 30.00 10,451.00 89.90 335.89 6,162.86 -4,074.06 -4,186.01 7.00 -6.08 3.49 150.00 10,775.00 89.91 358.57 6,163.40 -3,760.13 -4,257.18 7.00 0.00 7.00 90.00 11,275.00 90.00 333.57 6,163.80 -3,278.69 -4,376.62 5.00 0.02 -5.00 -89.80 11,675.00 90.00 353.57 6,163.79 -2,896.97 -4,489.21 5.00 0.00 5.00 90.00 12,200.00 91.33 327.35 6,157.59 -2,406.56 -4,663.27 5.00 0.25 -4.99 -87.00 12,700.00 89.94 352.31 6,151.98 -1,940.96 -4,834.28 5.00 -0.28 4.99 93.00 13,225.00 89.94 326.06 6,152.55 -1,454.50 -5,019.20 5.00 0.00 -5.00 -90.00 13,600.00 89.95 344.81 6,152.91 -1,114.96 -5,174.40 5.00 0.00 5.00 90.00 14,D00.00 89.95 324.81 6,153.28 -754.83 -5,343.77 5.00 0.00 -5.00 -90.00 2/13/2020 2:35:11PM Page 2 COMPASS 5000,14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well CD4-215 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Mean Sea Level Project: Western North Slope MD Reference: CD4-215 : @ 56.55usft (CD4-215 :) Site: CD4 Nanuq Pad North Reference: True Well: CD4-215 Survey Calculation Method: Minimum Curvature Wellbore: CD4-2151-1-01 Design: CD4-2151-1-01 wp01 (Draft A) 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) (°/100usft) (°) (usft) (usft) 10,150.00 90.00 325.33 6,186.55 -4,334.89 -4,039.19 -1,734.53 0.00 0.00 5,953,192.56 373,793.64 TIP 10,200.00 93.03 327.08 6,185.22 -4,293.36 -4,066.99 -1,684.67 7.00 30.00 5,953,234.53 373,766.52 10,300.00 99.08 330.62 6,174.68 -4,208.32 -4,118.41 -1,585.31 7.00 30.05 5,953,320.39 373,716.49 KOP 10,400.00 93.01 334.12 6,164.15 -4,120.26 -4,164.47 -1,486.01 7.00 150.00 5,953,409.18 373,671.86 10,451.00 89.90 335.89 6,162.86 -4,074.06 -4,186.01 -1,435.23 7.00 150.37 5,953,455.72 373,651.08 Start DLS 7.00 TFO 90.00 10,500.00 89.90 339.32 6,162.94 -4,028.76 -4,204.68 -1,386.67 7.00 90.00 5,953,501.31 373,633.15 10,600.00 89.90 346.32 6,163.11 -3,933.28 -4,234.21 -1,289.22 7.00 89.99 5,953,597.25 373,605.18 10,700.00 89.91 353.32 6,163.28 -3,834.92 -4,251.88 -1,195.20 7.00 89.98 5,953,695.88 373,589.12 10,775.00 89.91 358.57 6,163.40 -3,760.13 -4,257.18 -1,127.78 7.00 89.97 5,953,770.73 373,585.03 Start DLS 6.00 TFO -89.80 10,800.00 89.91 357.32 6,163.44 -3,735.15 -4,258.08 -1,105.70 5.00 -89.80 5,953,795.73 373,584.53 10,900.00 89.93 352.32 6,163.58 -3,635.59 -4,267.11 -1,014.96 5.00 -89.8D 5,953,895.41 373,577.12 11,000.00 89.95 347.32 6,163.68 -3,537.20 -4,284.78 -920.91 5.00 -89.79 5,953,994.07 373,561.05 11,100.00 89.97 342.32 6,163.75 -3,440.72 -4,310.97 -824.27 5.00 -89.79 5,954,090.95 373,536.44 11,200.00 89.99 337.32 6,163.79 -3,346.89 -4,345.46 -725.76 5.00 -89.78 5,954,185.32 373,503.48 11,275.00 90.00 333.57 6,163.80 -3,278.69 -4,376.62 -651.11 5.00 -89.78 5,954,254.02 373,473.43 Start DLS 6.00 TFO 90.00 11,300.00 90.00 334.82 6,163.80 -3,256.18 -4,387.51 -626.18 5.00 90.00 5,954,276.70 373,462.91 11,400.00 90.00 339.82 6,163.80 -3,163.94 -4,426.06 -527.03 5.00 90.00 5,954,369.54 373,425.87 11,500.00 90.00 344.82 6,163.79 -3,068.70 -4,456.42 -429.36 5.00 90.00 5,954,465.26 373,397.06 11,600.00 90.00 349.82 6,163.79 -2,971.17 -4,478.37 -333.92 5.00 90.00 5,954,563.12 373,376.70 11,675.00 90.00 353.57 6,163.79 -2,896.97 -4,489.21 -264.25 5.00 90.00 5,954,637.48 373,367.07 Start DLS 6.00 TFO -87.00 11,700.00 90.07 352.32 6,163.77 -2,872.16 -4,492.28 -241.22 5.00 -87.00 5,954,662.33 373,364.40 11,800.00 90.33 347.33 6,163.43 -2,773.77 -4,509.95 -147.18 5.00 -87.00 5,954,760.99 373,348.34 11,900.00 90.59 342.33 6,162.63 -2,677.28 -4,536.11 -50.54 5.00 -87.02 5,954,857.88 373,323.75 12,000.00 90.84 337.34 6,161.38 -2,583.45 -4,570.57 47.95 5.00 -87.06 5,954,952.25 373,290.82 12,100.00 91.09 332.34 6,159.70 -2,492.98 -4,613.06 147.55 5.00 -87.12 5,955,043.39 373,249.80 12,200.00 91.33 327.35 6,157.59 -2,406.56 -4,663.27 247,49 5.00 -87.20 5,955,130.61 373,201.01 Start DLS 5.00 TFO 93.00 12,300.00 91.06 332.34 6,155.50 -2,320.14 -4,713.47 347.44 5.00 93.00 5,955,217.83 373,152.22 12,400.00 90.79 337.34 6,153.89 -2,229.67 -4,755.97 447.04 5.00 93.10 5,955,308.97 373,111.20 12,500.00 90.51 342.33 6,152.76 -2,135.83 -4,790.44 545.53 5.00 93.18 5,955,403.34 373,078.27 12,600.00 90.22 347.32 6,152.12 -2,039.36 -4,816.61 642.17 5.00 93.24 5,955,500.23 373,053.67 12,700.00 89.94 352.31 6,151.98 -1,940.96 -4,834.28 736.22 5.00 93.27 5,955,598.89 373,037.59 Start DLS 6.00 TFO -90.00 12,800.00 89.94 347.31 6,152.09 -1,842.57 -4,851.97 830.27 5.00 -90.00 5,955,697.54 373,021.51 12,900.00 89.94 342.31 6,152.20 -1,746.09 -4,878.16 926.92 5.00 -89.99 5,955,794.43 372,996.89 13,000.00 89.94 337.31 6,152.31 -1,652.27 -4,912.66 1,025.42 5.00 -89.99 5,955,888.79 372,963.93 13,100.00 89.94 332.31 6,152.42 -1,561.81 -4,955.20 1,125.04 5.00 -89.98 5,955,979.93 372,922.86 13,200.00 89.94 327.31 6,152.52 -1,475.40 -5,005.47 1,225.01 5.00 -89.98 5,956,067.13 372,874.00 13,225.00 89.94 326.06 6,152.55 -1,454.50 -5,019.20 1,249.96 5.00 -89.97 5,956,088.24 372,860.61 Start DLS 6.00 TFO 90.00 13,300.00 89.94 329.81 6,152.62 -1,390.96 -5,059.01 1,324.90 5.00 90.00 5,956,152.42 372,821.85 13,400.00 89.94 334.81 6,152.72 -1,302.44 -5,105.46 1,424.79 5.00 90.00 5,956,241.68 372,776.84 13,500.00 89.94 339.81 6,152.82 -1,210.20 -5,144.02 1,523.94 5.00 89.99 5,956,334.52 372,739.79 13,600.00 89.95 344.81 6,152.91 -1,114.96 -5,174.40 1,621.61 5.00 89.99 5,956,430.23 372,710.97 Start DLS 6.00 TFO -90.00 13,700.00 89.95 339.81 6,153.01 -1,019.72 -5,204.77 1,719.28 5.00 -90.00 5,956,525.95 372,682.15 211312020 2.35.11PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD4 Nanuq Pad Well: CD4-215 Welibore: CD4-2151-1-01 Design: CD4-2151-1-01 wp01 (Draft A) Planned Survey Measured TVD Below Depth Inclination Azimuth System (usft) (°) (1 (usft) 13,800.00 89.95 334.81 6,153.10 13,900.00 89.95 329.81 6,153.19 14,000.00 89.95 324.81 6,153.28 Planned TD at 14000.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well CD4-215 Mean Sea Level CD4-215 : @ 56.55usft (CD4-215 :) True Minimum Curvature Vertical Dogleg Toolface Map Map +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) -927.49 -5,243.33 1,818.44 5.00 -90.00 5,956,618.79 372,645.09 -838.97 -5,289.78 1,918.32 5.00 -89.99 5,956,708.04 372,600.09 -754.83 -5,343.77 2,018.18 5.00 -89.99 5,956,793.04 372,547.48 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,000.00 6,153.28 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 10,150.00 6,186.55 -4,334.89 -4,039.19 TIP 10,300.00 6,174.68 -4,208.32 -4,118.41 KOP 10,451.00 6,162.86 -4,074.06 -4,186.01 Start DLS 7.00 TFO 90.00 10,775.00 6,163.40 -3,760.13 -4,257.18 Start DLS 5.00 TFO -89.80 11,275.00 6,163.80 -3,278.69 -4,376.62 Start DLS 5.00 TFO 90.00 11,675.00 6,163.79 -2,896.97 -4,489.21 Start DLS 5.00 TFO -87.00 12,200.00 6,157.59 -2,406.56 -4,663.27 Start DLS 5.00 TFO 93.00 12,700.00 6,151.98 -1,940.96 -4,834.28 Start DLS 5.00 TFO -90.00 13,225.00 6,152.55 -1,454.50 -5,019.20 Start DLS 5.00 TFO 90.00 13,600.00 6,152.91 -1,114.96 -5,174.40 Start DLS 5.00 TFO-90.00 14,000.00 6,153.28 -754.83 -5,343.77 Planned TD at 14000.00 211312020 2:35:11PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Reference Site: CD4 Nanuq Pad Site Error: 0.00 usft Reference Well: CD4-215 Well Error: 0.00 usft Reference Wellbore CD4-2151-1-01 Reference Design: CD4-2151-1-01 wp01 (Draft A) Local Coordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well CD4-215 CD4-215 : @ 56.55usft (CD4-215 :) CD4-215 : @ 56.55usft (CD4-215 :) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference CD4-2151-1-01 wp01 (Draft A) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,150.00 to 14,000.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 2/10/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description 79.00 898.00 CD4-215 Srvy 1 - CB -GYRO -SS (CD4-215 CB -GYRO -SS Camera based gyro single shot 934.61 9,578.27 CD4-215 Srvy 2 - MWD+IFR-AK-CAZ-SC MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 9,578.27 10,150.00 CD4-2151_1 wp05 (Draft A) (CD4-215L1) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 10,150.00 14,000.00 CD4-2151-1-01 wp01 (Draft A) (CD4-215L1 MWD OWSG OWSG MWD - Standard Summary Site Name Offset Well - Wellbore - Design CD4 Nanuq Pad CD4-05 - CD4-05 - CD4-05 CD4-05 - CD4-05 - CD4-05 CD4-05 - CD4-05 - CD4-05 CD4-07 - CD4-07 - CD4-07 CD4-07 - CD4-07 - CD4-07 CD4-12 - CD4-12 - CD4-12 CD4-12 - CD4-12PB1 - CD4-12PB1 CD4-12 - Nanuq 5 - Nanuq 5 CD4-16 - CD4-16 - CD4-16 CD4-17 - CD4-17 - CD4-17 CD4-208 - CD4-208 - CD4-208 CD4-208 - CD4-208A - CD4-208A CD4-208 - CD4-208AL1 - CD4-208AL1 CD4-208 - CD4-208APB1 - CD4-208APB1 CD4-208 - CD4-208PB1 - CD4-208PB1 CD4-209 - CD4-209 - CD4-209 CD4-210 - CD4-210 - CD4-210 CD4-210 - CD4-210A - CD4-210A CD4-210 - CD4-210APB1 - CD4-210APB1 CD4-210 - CD4-210B - CD4-210B CD4-211 - CD4-211 - CD4-211 CD4-211 - CD4-211 L 1 - CD4-211 L 1 C D4-211 - C D4-211 L 1 -0 1 - C D4-211 L 1-01 CD4-213 - CD4-213 - CD4-213 CD4-213 - CD4-213A - CD4-213A CD4-213 - CD4-21313 - CD4-213B CD4-213 - CD4-21313 - CD4-213B CD4-213 - CD4-2136 - CD4-213B CD4-213 - CD4-213BPB1 - CD4-213BPB1 CD4-213 - CD4-213BPB1 - CD4-213BPB1 CD4-213 - CD4-213BPB1 - CD4-213BPB1 CD4-213 - CD4-213BPB2 - CD4-213BPB2 CD4-213 - CD4-213BPB2 - CD4-213BPB2 Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 13,547.51 8,500.00 1,386.31 1,283.29 13.456 CC 13,553.56 8,625.00 1,392.15 1,278.45 12.244 ES 13,571.69 9,275.00 1,588.30 1,429.18 9.982 SF Out of range Out of range Out of range Out of range Out of range 14,000.00 7,125.00 1,466.54 1,329.76 10.722 CC, ES, SF 13,998.91 7,875.00 1,186.44 1,107.52 15.033 CC, ES, SF 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 12,518.32 8,600.00 771.97 681.24 8.508 CC 12,519.98 8,675.00 775.84 677.85 7.917 ES 12,525.75 8,950.00 848.65 729.79 7.140 SF 12,500.00 8,700.00 617.67 526.70 6.790 CC 12,500.00 8,775.00 622.76 523.03 6.244 ES 12,522.02 8,975.00 678.62 559.88 5.715 SF 12,355.41 8,700.00 580.08 491.89 6.578 CC 12,367.29 8,775.00 584.52 487.56 6.028 ES CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 211012020 1:34:36PM Page 2 COMPASS 5000,14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Reference site: CD4 Nanuq Pad Site Error: 0.00 usft Reference Well. CD4-215 Well Error: 0.00 usft Reference Weltbore CD4-2151-1-01 Reference Design: CD4-2151-1-01 wp01 (DraftA) Summary Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well CD4-215 CD4-215 : @ 56.55usft (CD4-215 :) CD4-215 : @ 56.55usft (CD4-215 :) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) CD4 Nanuq Pad CD4-213 - CD4-213BPB2 - CD4-213BPB2 CD4-214 - CD4-214 - CD4-214 CD4-214 - CD4-214 - CD4-214 CD4-214 - CD4-214 - CD4-214 CD4-214 - CD4-2141-1 - CD4-2141-1 wp02 CD4-214 - CD4-2141-1 - CD4-2141-1 wp02 CD4-214 - CD4-2141-1 - CD4-2141-1 wp02 CD4-215 - CD4-215 - CD4-215 CD4-215 - CD4-215 - CD4-215 CD4-215 - CD4-215 L 1 - C134-215 L 1 wp05 ( Draft A) CD4-215 - CD4-2151-1 - CD4-2151-1 wp05 (Draft A) CD4-23 - CD4-23 - CD4-23 CD4-23 - CD4-23 - CD4-23 CD4-23 - CD4-23PB1 - CD4-23PB1 CD4-23 - CD4-23P B 1- CD4-23 P B 1 CD4-23 - CD4-23PB1 - CD4-23PB1 CD4-23 - CD4-23PB2 - CD4-23PB2 CD4-23 - CD4-23PB2 - CD4-23PB2 CD4-24 - CD4-24 - CD4-24 CD4-24 - CD4-24PB1 - CD4-24PB1 CD4-24 - CD4-24PB2 - CD4-24PB2 CD4-25 - CD4-25 - CD4-25 CD4-25 - CD4-251-1 - CD4-251-1 CD4-25 - CD4-25PB1 - CD4-25PB1 CD4-26 - CD4-26 - CD4-26 CD4-27 - CD4-27 - CD4-27 CD4-27 - CD4-27PB1 - CD4-27PB1 CD4-27 - CD4-27PB2 - CD4-27PB2 CD4-27 - CD4-27PB3 - CD4-27PB3 CD4-291 - CD4-291 - CD4-291 Actual CD4-304 - CD4-304 - CD4-304 CD4-304 - CD4-304PB1 - CD4-304PB1 CD4-306 - CD4-306 - CD4-306 CD4-318 - CD4-318 - CD4-318 CD4-318 - CD4-318A - CD4-318A CD4-318 - CD4-318PB1 - CD4-318PB1 CD4-319 - CD4-319 - CD4-319 CD4-319 - CD4-319 - CD4-319 CD4-320 - CD4-320 - CD4-320 CD4-320 - CD4-320 - CD4-320 CD4-320 - CD4-320 - CD4-320wp08 CD4-320 - CD4-320PB1 - CD4-320PB1 CD4-320 - CD4-320PB1 - CD4-320PB1 CD4-321 - CD4-321 - CD4-321 CD4-322 - CD4-322 - CD4-322 CD4-322 - CD4-322 - CD4-322 Nanuq 3 - Nanuq 3 - Nanuq 3 Nanuq 3 - Nanuq 3 - Nanuq 3 Nanuq 3 - Nanuq 3 - Nanuq 3 Plan: CD4-97 - Plan: CD4-97 - CD4-97wp08 Prelim: CD4-xxx (QAN 16-09) - Plan: CD4-xxx (QAN 16-09 12,400.00 8,950.00 629.32 515.27 5.518 SF 11,100.00 7,925.00 1,512.24 1,433.45 19.192 CC 11,100.00 7,950.00 1,512.72 1,432.83 18.937 ES 11.700.00 7,575.00 1,559.46 1,458.08 15.383 SF 12,029.04 11,400.00 1,319.77 1,158.93 8.205 CC 13,028.71 12,400.00 1,344.57 1,112.60 5.796 ES 13,848.27 13,325.00 1,485.10 1,187.82 4.996 SF 10,930.26 8,900.00 243.40 240.64 88.282 CC, ES 11,604.42 8,175.00 517.53 504.69 40.294 SF 13,967.67 13,975.00 4.20 -144.52 0.028 STOP Drilling, CC, SF 13,990.19 14,000.00 12.79 -192.14 62 STOP Drilling, ES 12,395.40 8,575.00 126.86 36.81 1.409, Take Immediate Action, CC 12,400.00 8,625.00 139.69 27.11 -1,241 Take Immediate Action, ES, 11,546.78 8,525.00 159.70 80.48 2.616 Caution Monitor Closely, CC 11,553.57 8,500.00 161.21 75.92 1.890 Caution Monitor Closely, ES 11,560.59 8,475.00 166.26 76.13 1.845 Caution Monitor Closely, SF 12,395.40 8,575.00 126.86 36.81 1.409 Take Immediate Action, CC 12,400.00 8,625.00 139.69 27.11 1.241 Take Immediate Action, ES, 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 11,922.35 14,950.00 922.83 850.77 12.806 CC, ES 13,993.46 17,000.00 942.17 857.55 11.134 SF Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 13,949.66 7,850.00 1,157.49 924.47 4.967 SF 13,958.87 7,925.00 1,151.99 920.73 4.982 ES 13,965.09 7,975.00 1,151.06 921.48 5.014 CC Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 211012020 1:34:36PM Page 3 COMPASS 5000.14 Build 85H V, ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Reference Site: CD4 Nanuq Pad Site Error: 0.00 usft Reference Well: CD4-215 Well Error: 0.00 usft Reference Wellbore CD4-2151-1-01 Reference Design: CD4-215L1-01 wp01 (Draft A) Summary Site Name Offset Well - Wellbore - Design CD4 Pad Plan: CD4-23 -Plan: CD4-23 - CD4-23wp11 Plan: CD4-23 - Plan: CD4-23 - CD4-23wp11 CD5 Alpine West Pad CD5-28 - CD5-96L1 - CD5-961_1 wp02 CD5-90 - CD5-901_1 - CD5-961_1 wp02 CD5-96 - CD5-961_1 - CD5-961_1 wp02 Nanuk Nanuk 2 - Nanuk 2 - Nanuk 2 Nanuk 2 - Nanuk 2 - Nanuk 2 Nanuk 2 - Nanuk 2 - Nanuk 2 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well CD4-215 CD4-215 : @ 56.55usft (CD4-215 :) CD4-215 : @ 56.55usft (CD4-215 :) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum Reference Offset Distance Measured Measured Between Between Separation Warning Depth Depth Centres Ellipses Factor (usft) (usft) (usft) (usft) 11,553.38 8,500.00 137.25 55.74 1.684 Caution Monitor Closely, CC 11,567.62 8,450.00 143.19 47.87 1.502 Caution Monitor Closely, ES 13,991.88 22,075.00 1,377.32 1,280.32 14.198 CC, ES, SF 13,991.88 22,075.00 1,377.32 1,280.32 14.198 CC, ES, SF 13,991.88 22,075.00 1,377.32 1,280.32 14.198 CC, ES, SF 10,900.00 7,100.00 911.51 829.47 11.111 CC 10,900.00 7,125.00 911.78 829.25 11.048 ES 10,900.00 7,225.00 919.78 835.72 10.942 SF Offset Design CD4 Nanuq Pad - CD4-05 - CD4-05 - CD4-05 Survey Program: 81-CB-GYRO-SS, 938-MWD+IFR-AK-CAZ LC Reference Offset Semi Major Axis Distance Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Between Between Minimum Separation Depth Depth Depth Depth from North +N/S +EAW Centres Ellipses Separation Factor (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) 13,491,92 6,209.36 7,725.00 4,623.23 128.24 77.11 -17.65 -1,187.65 -5,065.39 1,587.76 1,525.85 61.90 25.649 13,495.37 6,209.36 7,750.00 4,634.15 128.38 77.44 -18.26 -1,192.43 -5,087.36 1,575.85 1,513.95 61.90 25.458 13,498.65 6,209.36 7,775.00 4,645.17 128.61 77.75 -18.90 -1,197.21 -5,109.29 1,564.17 1,502.18 61.99 26.232 13,501.74 6,209.37 7,800.00 4,656.27 128.63 78.06 -19.55 -1,202.04 -5,131.16 1,552.70 1,49D.53 62.18 24.973 13,504.67 6,209.37 7.825.00 4,667.46 128.74 78.37 .20.23 -1,206.91 -5,152.99 1,541.47 1,479.01 62.46 24.679 13,607.43 6,209.37 7,850.00 4,678.69 128.84 78.69 -20.92 -1,211.82 -5,174.77 1,530.50 1.467.65 62.85 24.353 13,510.10 6,209.38 7,875.00 4,689.89 128.94 79.01 -21.63 -1,216.72 -5,196.57 1,519.89 1,456.56 63.34 23.997 13,512.68 6,209.38 7,900.00 4,701.D3 129.04 79.33 -22.36 -1,221.63 -5,218.41 1,509.69 1,445.75 63.93 23.613 13,515.18 6,209.38 7,925.00 4,712.10 129.13 79.65 -23.10 -1,226.53 -5,240.28 1,499.89 1,435.26 64.64 23.204 13,517.60 6,209.38 7,950.00 4,723.12 129.22 79.98 -23.86 -1,231.44 -5,262.18 1.490.50 1,425.05 65.45 22.773 13,519.89 6,209.39 7,975.00 4,734.14 129.31 80.31 -24.64 -1,236.40 -5,284.07 1,481.48 1,415.11 66.37 22.322 13,522.06 6,209.39 8,000.00 4,745.15 129.39 80.63 -25.44 -1,241.40 -5,305.95 1,472.82 1,405.43 67.39 21.855 13,524.12 6,209.39 8,025.00 4,756.15 129.47 80.96 -26.25 -1,246.45 -5,327.82 1,464.54 1,396.03 68.51 21.376 13,526.04 6,209.39 8,050.00 4,767.15 129.54 81.28 -27.08 -1,251.57 -5,349.68 1,456.66 1,386.92 69.74 20.888 13,527.81 6,209.39 8,075.00 4,778.10 129.61 81.60 -27.93 -1,256.82 -5,371.53 1,449.20 1,378.14 71.05 20.396 13,529.42 6,209.39 8,100.00 4,789.02 129.67 81.92 -28.80 -1,262.19 -5,393.37 1,442.17 1,369.71 72.46 19.902 13,530.88 6,209.40 8,125.00 4,799.91 129.72 82.24 -29.68 -1,267.69 -5,415.19 1,435.59 1,361.63 73.96 19.411 13,532.26 6,209.40 8,150.00 4,810.78 129.77 82.56 -30.58 -1,273.23 -5,437.01 1,429.42 1,353.89 75.53 18.924 13,533.60 6,209.40 8,175.00 4,821.66 129.82 82.88 -31.49 -1,278.75 -5,458.83 1,423.65 1,346.46 77.19 18.445 13,534.92 6,209.40 8,200.00 4,832.56 129.87 83.20 .32.41 -1,284.26 -5,480.65 1,418.28 1,339.37 78.91 17.974 13,536.21 6,209.40 8,225.00 4,843.47 129.92 83.52 -33.33 -1,289.76 -5,502.46 1,413.32 1,332.63 80.69 17.515 13,537.40 6,209.40 8,250.00 4,854.40 129.97 83.83 -34.27 -1,295.33 -5,524.24 1,408.76 1,326.22 82.54 17.068 13,538.46 6,209.40 8,275.00 4,865.35 130.01 84.15 -35.22 -1,301.02 -5,545.98 1,404.61 1,320.17 84.44 16.635 13,539.41 6,209.40 B,300.00 4,876.33 130.04 84.46 .36.18 -1,306.82 -5,567.68 1,400.86 1,314.48 86.38 16.217 13,540.26 6,209.40 8,325.00 4,887.33 130.07 84.78 -37.15 -1,312.71 -5,589.34 1,397.53 1,309.16 88.37 15.815 13,541.13 6,209.41 8,350.00 4,898.35 130.11 85.10 -38.12 -1,318.54 -5,611.02 1,394.62 1,304.23 90.39 15.429 13,542.04 6,209.41 8,375.00 4,909.38 130.14 85.41 -39.10 -1,324.27 -5,632.71 1,392.13 1,299.69 92.45 15.059 13,543.00 6,209.41 8,400.00 4,920.42 130.18 85.73 -40.08 -1,329.91 -5,654.41 1,390.07 1,295.55 94.53 14.705 13,544.00 6,209.41 8,425.00 4,931.48 130.21 86.06 -41.05 -1,335.44 -5,676.14 1,388.45 1,291.82 96.63 14.369 13,545.09 6,209.41 8,450.00 4,942.52 130.25 86.38 -42.03 -1,340.82 -5,697.92 1,387.28 1,288.53 98.75 14.048 13,546.26 6,209.41 8,475.00 4,953.55 130.30 86.71 -43.00 -1,346.03 -5,719.74 1,386.56 1,285.68 100.88 13.744 Offset Site Em r: 0.00 usft Offset Well Error: 0.00 usft Warning CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 211012020 1:34:36PM Page 4 COMPASS 5000.14 Build 85H �63 (ui/Usn 000 ( N ' MGM COCCf ON COS W O Ct)MN t-: C!CPN a t (n-�r CO LnI- V tiU�Or c0 C c 6 > O V (�O N N I NCO O J N o o 0 0 0 0 0 0 0 0 0 0 0 00 o ao 0 00 00 0 U-C>C>oC)ofC�r:a oC>o M� O COO aO O O>O CT M o Cl 0 0 Cl 0 Cl 0 0 C. 0 m z N 0 0 0 0 0 0 0 0 0 0 0 O tit• ti to t0 u) CCU Cn U> CO @ N N J M CA W N a- I` co O O C.- V O C D N N N N c: C W 6>t1C CO I�COOM�—dM MNCOM 1.- ct p O N Mt to co 0 M '� gvgqqqqq�n��n (n O N CO m O I- Co CD O Co M cOMO COO C[>O CC)O CR Zvw;rommmovvv (TM + MNOtoNOD V Od'� � c V Itq q C h C h C V C V ' p O W CA c0 CO 000000 u'Y CO Cf) CO o0 V OR 'A O Un O N Q oD 1� CO CO lD (D t0 l0 CO CO � H W tT N CO CO CO CO CO CO CO CO CD Cp CO C_ O J OV QMCO CA CO tO COMMOCA CO W 1 n W M M t N to V V M l O M C O N C Cj N y- C V M M M M M M M M M UO tOO00M"I' V Cf> ll') C O O O O O O M O O O O O O O C7> 0 0 0 O O O O O of cp O O O K) CC M a0 o 0 o 0 0 0 0 0 0 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 o=Z; ��oo�oo C O O I n 1- 1-- o O N 0 0 M V' I�� CO fV C--N COO N_ N_ M_ CM V C,) NM V 000OI--cO00e- Z o co -)glnoS oc K oc CD oc C) oc N 0c W oc 3 00 4 WNS PROD CD4-215 ConocoPhillips Alaska, Inc. Wall Cc HANGER, 31 CONDUCTOR 46" Insulated, 37-114 SAFETY VLV, SURFACE, 37-2,854 GAS LIFT, 4355 GAS LIFT, 8,115 PACKER, 8,204 NIPPLE, 8,283 WLEG, 9,351 9,501-9,712 SLOTS,_ _ 10.550-10,733 SLOTS, 10.857-11,039 SLOTS, 11.566-11,627 SLOTS, 12,18412,730 FRAC, 10,550 SLOTS, 12,852-13,395 SLOTS, 13,549-13,638 SLOTS, 14,342-14,403 SLOTS, 14,497-14,673 LINER, 9,361-14,67E TD, 14,761 Well Attributes Max An le & MD TD Wellbore API/UWI _ _ Field Name Wellbore Status Incl (°) _ _ MD IRKS) Act St. (RKB) 501032053900 F;;ld PROD 14,761.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (R) Rig Release Dab SSSV: TRDP Last WO: 43.78 12/25/2006 Annotation Depth (RKB) Entl Date Annotation Last Mod By Entl Date Last Tag: 10,800.0 7/11/2008 Rev Reason: WELL REVIEW osborl 9/5/2013 Casing Strinas Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 46'. 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED Insulated Casing Description String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.8 2,854.2 2,312.2 40.00 L-80 Buttress Casing Description String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.6 9,514.5 6,215.9 26.00 L-80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 3112 2.992 9,361.0 14,675.0 6,212.0 9.30 L-80 SLHT Lin lls Top Depth (ND) Tap Incl Nomi Ton IRltel (RKB) 1°I Item Deseriotinn Comment ID (in TUBING 31/2 2.992 31.4 9,379.E 6.194.8 9.30 L-80 EUE81dMOD VITxNOF-- Com letion Details Top Depth (TVD) Top Incl Nomi... Too MKRl (ftKB) V) Item Descriotion Comment ID (in) TO NORMAL 3.5" TUBING Tao 11KB1I Btm I.KBI Top (ftKB Zone St. (ftKB) (TVD' Zone Date (sins I Tvoe Comment 125" x2 .25" slots Hyperjet Charges, 60 di mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2.25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots mating solid/slotted pipe 125" x2 .25" slots Min Top Max Btm Top Depth Depth Depth Depth (TVD) Pat (ftKB) (ftKB) (ftKB) (RKB) Tvoe Date Comment 10,550.0 14,673.0 6,231.1 6,212.1 FRAC 4/25/2007 FRAC NANUQ FORMATION 310,000# 20/40 CARBOLITE WORKING UP FROM 1 ppa TO 12 ppa ON FORMATION. Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run N... Top IRKS) (ftKB) (') Make Model (in) sew Type Type (in) (psi) Run Date Com... 11 4,354.51 3,420.5 43.11 CAMCO KBMG 1 11 GAS LIFT IDMY BK-5 10.0001 0.01712912008 0 N CO N (D 0 c y � d N U O m m Cn � cV W m N v In o V Y Y p ti m �C, c E ti o> CO NN�\\ as > �M� O E co O in fn 0 X CO CO O Cn ♦— lJ CO N O > nJ E c W m N v e/�o� C7 az0` N J (6 V O In ,, 0 _2 F oOlo X U 0_ m z m e > J � O O' UJ N O J M X F m N z N ai ai > Y0 a (n C) 0 C N N E N E Y (n Id J Y Y 2 C) 2 m ri U c%� U 000 CO0CO0 0 o� Fc.1 °O "v v J co 2 p NN1 ID N co N (D 0 lf7 L N O N 0 O 0 co a nl nl lu i m 0 0 L N Cl c0 O N N O TRANSMITTAL LETTER CHECKLIST WELL NAME: C R U-4- — Z 1 J- L- 1 O �. PTD: o - o a, -a' _�/Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Go v i l 12 R iyP.V— POOL: Na. K u 4 01 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. SO6' — 1,5:7- , API No. 50- 1 o3- W H::M (If last two digits Production should continue to be reported as a function of the original V/ 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 on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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: Non- production or production testing of coal bed methane is not allowed for 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 COLVILLE RIVER, NANUQ OIL - 120175 _ Well Name: COLVILLE RIV NAN-N CD4-2151_1-01 Program DEV — Well bore seg ❑d PTD#: 2200220 Company ConocoPhillips Alaska Inc, _ — _ _ _ Initial Classlfype DEV / PEND _GeoArea 890 Unit 50360 On/Off Shore On —_ Annular Disposal ❑ Administration 11 Permit fee attached NA 2 Lease number appropriate Yes - 3 Unique well name and number Yes 4 Well located in a defined _pool Yes 5 Well located proper distance from drilling unit —boundary Yes 6 Well located proper distance from other wells_ Yes 7 Sufficient acreage available in drilling unit Yes - 8 If deviated, is wellbore plat included Yes Directional plan view and wellbore profile included. 9 Operator only affected party Yes 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 DLB 3/5/2020 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([.1-.A),0.2_.A-D) NA 18 Conductor string_ provided NA Conductor set_for_CD4-215 Engineering 19 Surface casing protects all -known_ USDWs NA_ Surface casing set for CD4-215 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 u_ncemented slotted_ liner_ 23 Casing designs adequate for C,_T, B &_permafr_ost 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 I26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; major risk failure CD4-23 in reservoir 27 If diverter required, does it meet regulations_ NA Appr Date 28 Drilling fluid_ program schematic _& equip list adequate Yes Max formation pressure is 3636 psig(11.2 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 3/6/2020 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to _(put psig in comments) Yes MPSP is 3014_ psig; will test BOPs_to 3500_psig 31 Choke manifold complies w/API_RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes i33 Is presence of H2S gas probable - No 34 Mechanical condition of wells within AOR verified (For_ service well only) NA_ -- --------------------- 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not encountered in offset wells. However, rig will be equipped with operational sensors/alarms. Geology I36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA DLB 3/5/2020 38 Seabed condition survey (if off -shore) NA_ - - - 39 Contact name/phone for weekly_ progress reports_ [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: 9� Date 3`� 1� Commis . er 0� Date 31,p lacy