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219-013
Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Wednesday, March 10, 2021 9:14 AM To: McLaughlin, Ryan Cc: Loepp, Victoria T (CED) Subject: KRU 1.1 Laterals: Expired Permits Hi Ryan, The following three permits to drill have expired under regulation 20 AAC 25.005 (g). The permits have been marked expired in their well history file and in the AOGCC database. • KRU 1J-10L1-01 (issued to CPAI February 5th 2019) • KRU 1J-101-1-02 (issued to CPAI February 5th 2019) • KRU 1J-101-1-03 (issued to CPAI February 5th 2019) Please let me know if you have any questions. Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hulh.vvinston@alaska.Fov 907-793-1241 THE STATE 9���NNWIAR GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 J-1 OL 1 -0 1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-013 Surface Location: 1996' FSL, 2536' FEL, SEC. 35, T11N, R1OE, UM Bottornhole Location: 1946' FNL, 500' FEL, SEC. 34, T11N, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 201-071, API No. 50-029- 23010-00-00. 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, Z-/ - Daniel T. Seamount, Jr. Commissioner DATED this J— day of February, 2019. STATE OF ALASKA ALi . _.:A OIL AND GAS CONSERVATION COMMI.._._jN PERMIT TO DRILL RECENEU JAN 2 5 2019 20 AAC 25.005 1 a. Type of Work: Drill ❑ Lateral [21 Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil 0 Service - Winj ❑ Single Zone 0 Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if osed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket E] Single Well ❑ Bond No. 5952180 xykka 11. Well Name and Number: KRU 1J-10L1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: -VVD,, 6 Z3Ar 0Vo /q MD: 15,200' TVD/55. 6120' 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 1996' FSL, 2536' FEL, Sec 35, T11 N, R10E, UM Top of Productive Hvizo 1 f Total t e� N� �pp� (, 'j' GM ID 4b. Location of ell ( toe se P ane C46 oordi ates D 27): Surface: x- 558673 y- 5945808 Zone- 4 7. Property Designation: APL zs 661 ADL 25660 PeH+4+z9- 8. DNR Approval Number: 83-137 13. Approximate Spud Date: 2/13/2019 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,913' 10. KB Elevation above MSL (ft): 114' GL / BF Elevation above MSL (ft): 79' 15. Distance to Nearest Well Open Ito Same Pool: 1845', 1 L-29 16. Deviated wells: Kickoff depth: 10,420 ' feet Maximum Hole Angle: 91 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 2960 Surface: 2361 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 2900' 12,300' 6045' 15,200 6120' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 10,845' Total Depth TVD (ft): 6326' Plugs (measured): N/A Effect. Depth MD (ft): 10,843' Effect. Depth TVD (ft): 6324' Junk (measured): 10,400' Casing Length Size Cement Volume MD TVD Conductor/Structural 85' 16" 460 sx AS 1 115' 115' Surface 6911' 9-5/8" 700 sx AS Lite & 450 sx LiteCrete 6938' 3991' Production 10,199, 7" 170 sx G 10,231' 5944' Liner 876' 4-1/2" 150 sx GasBlok 10,843' 6325' Perforation Depth MD (ft): 10,446' - 10,466', 10,658' - 10,678' Perforation Depth TVD (ft): 6073' - 6085', 6205' - 6218' Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program e Seabed Report e Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis e 20 AAC 25.050 requirementse 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 Authorized Name: James Ohlinger Contact Email: Ryan. MCLaUhlin c0 .com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date: 11alvI7 Commission Use Only Permit to Drill Number: 2, 11-0 13 150- API Number: Q 2 -- O _ 61 —pp Permit Approval Date: Z,5 f See cover letter for other 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: Other: Q�� ��� f ��U O /� Si5 Samples req'd: Yes ❑ NoRr Mud log req'd: Yes❑ No[V U measures: Yes [yr No❑ Directional svy req'd: Yes VNo❑ 4-k-L {�1 t/l a N � V� v3 1Ll 6� �� S ri 7 L � �-�/ �I Spa ception Feq'd: Yes ❑ No [� Inclination -only svy req'd: Yes ❑ No [v]' Q`S _4 Post initial injection MIT req'd: Yes ❑ No l" 5 �fWV2 c57k-j �oyY17f � 1 � Pe1��-t �i � /) f ja�r�� APPROVED BY��' % p Approved by: COMMISSIONER THE COMMISSION Date: l /I Submit Form and Form t 0-401 Revised 5/2017 This permit is valid for 24 months ro the date of approval per 20 AAC 25.005(g) Atta ments in plicate q C _ � N A - ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 23, 2019 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 permits to drill four laterals out of the KRU 1 J-10 (PTD# 201-071) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin on February 6, 2019. The objective will be to drill four laterals KRU 1J- 10L1, 1J-101_1-01, 1J-101_1-02 and 1J-101_1-03 targeting the Kuparuk C-sand 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 this application are the following documents: — Permit to Drill Application Forms (10-401) for 1J-10L1, 1J-101_1-01, 1J-101_1-02 and 1J-101_1-03 — Detailed Summary of Operations — Directional Plans for 1J-10L1, 1J-101_1-01, 1J-101_1-02 and 1J-101_1-03 — 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 1 J-10L1 s 1 J-10L1-019 1 J-I OL1-023 & 1 J©1 OLI -03 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...................................................................................................................................................................6 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 1J-10L1, 1J-101-1-01, 1J-10L1-02, & 1J-101-1-03 laterals.......................................6 Attachment 2: Current Well Schematic for 1 J-10............................................................................................................6 Attachment 3: Proposed Well Schematic for 1J-101-1, 1J-10L1-01, 1J-101-1-02, & 1J-10L1-03 laterals .........................6 Page 1 of 6 January 15, 2019 PTD Application: 1J-101_1, 1J-101_1-01, 1J-101_1-02, & 1J-10L1-03 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 1J-10L1, 1J-101-1-01, 1J-101-1-02, and 1J-10L1-03. 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 C4 sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1J-101-1, lJ-101-1-01, lJ-101-1-02, and lJ-101-1-03 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 3500 psi. Using the maximum formation pressure in the area of 2914 psi in 1 L-29 (i.e. 9.2 ppg EMW), the maximum potential surface pressure in 1J-10, assuming a gas gradient of 0.1 psi/ft, would be 2315 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 1J-10 was measured to be 2880 psi (9.2 ppg EMW) on 1/20/2019. The , maximum downhole pressure in the 1 J-10 vicinity is the 1 L-29 at 2914 psi (9.2 ppg EMW) measured on 2/19/2017. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1 J-10 have injected gas, so there is a possibility of encountering free gas while drilling the 1J-10 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 1J-10 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 1 J-10 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 January 15, 2019 al Ovig - 1 1 ` 1ii[ iiiiii Ill lliniliiili IJ i 1 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 1J-10L1 10,200' 10,500' 5811' 5,982' ORCA Liner Drilling BHA 1J-10L1-01 12,300' 15,200' 6045' 6120' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1J-10L1-02 12,150' 14,775' 6041' 6028' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1J-101_1-03 10,400' 14,100' 5,927' 6088' 2-3/8", 4.7#, L-80, ST-L slotted liner; with shorty deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf)MD Grade Connection Top Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 20" 91.5 H-40 Welded 0' 120' 0' 120' 1530 520 Surface 9-5/8" 40.0 L-80 BTC 0' 6945' 0' 3995' 5750 3090 Production 7" 26.0 L-80 BTC-MOD 0' 10,321' 0' 5944' 7240 5410 Liner 4-1/2" 12.6 L-80 NSCT 9967' 10,843' 5787' 6325' 8430 7500 Tubing 4-1/2" 12.6 L-80 IBT 0' 9992' 0' 5802' 8430 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 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice CtiPp 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 1 J-10 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 Page 3 of 6 January 15, 2019 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 1J-10 Window (10,310' MD, 5991' TVD) Usinq MPD Pumps On 1.8 b m Pumps Off C-sand Formation Pressure 9.2 2866 psi 2866 psi Mud Hydrostatic 8.6 2679 psi 2679 psi Annular friction i.e. ECD, 0.08 si/ft 825 psi 0 psi Mud + ECD Combined no chokepressure) 3504 psi Overbalanced —638psi) 2679 psi Underblanced --187psi) Target BHP at Window 11.8 3676 psi 3676 psi Choke Pressure Required to Maintain Target BHP 172 psi 997 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 A- M PP KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The project targets stranded C-Sand resource to the south and east of 1J-10 into an area along the C-Sand margin south of existing production and injection. This project will involve drilling four CTD laterals from the 1J-10 parent wellbore. The first lateral will kickoff from a whipstock set at 10,310' and will drill out 200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The subsequent three laterals will target the Kuparuk C4 sand package with access gained from the 1J-IOLI lateral. Page 4 of 6 January 15, 2019 PTD Application: 1J-101_1, 1J-10L1-01, 1J-101_1-02, & 1J-10L1-03 Pre-CTD Work 1. RU Slickline: Drift tubing with dummy whipstock, obtain SBHP, C/O gas lift design 2. RU E-line: Caliper, set whipstock 3. 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. 1J-IOLI Lateral (Straddle the Kalubik w/Liner Drilling BHA) a. Mill 3.80" window at 10,310' MD. b. Drill 3-3/4" lateral with ORCA liner drilling BHA to TD of 10,500' MD. c. Hydraulically release off 3-1/2" liner drilling BHA leaving TOL at 10,200' MD 3. 1 J- I OL 1 -0 1 Lateral (C4 sand - southeast) a. Set top of whipstock in 3-1/2" drilled in liner at 10,420' MD b. Mill 2.80" window at 10,420' MD c. Drill 3" bi-center lateral to TD of 15,200' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,300' MD. 4. 1J-IOLl-02 Lateral (C4 sand- south) a. Kickoff of the aluminum billet at 12,300' MD. b. Drill 3" bi-center lateral to TD of 14,775' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,150' MD. 5. 1J-IOLl-03 Lateral (C4 sand - east) a. Kick off of the aluminum billet at 12,150' MD. b. Drill 3" bi-center lateral to TD of 14,100' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,400' MD. 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 7. Obtain SBHP. 8. Return well 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. - 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 Page 5 of 6 January15, 2019 PTD Application: U-101-1, U-101m1-01, U-101-1-02, & U-101-1-03 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 un-deployment, the steps listed above are observed, only in reverse. Liner Running - The 1J-10 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 1J-101_1 11,020' 1J-10L1-01 16,913' 1J-10L1-02 7620' 1J-10L1-03 17,081' - Distance to Nearest Well within Pool Lateral Name Distance Well 1J-10L1 2502' KUP 34-11-10 1 1J-10L1-01 1845' 1L-29 1J-1011-1-02 2706' 1 E-117 1J-101_1-03 2694' 1J-168 16. Attachments Attachment 1: Directional Plans for 1J-10L1, 1J-10L1-01, 1J-10L1-02, & 1J-10L1-03laterals Attachment 2: Current Well Schematic for 1J-10 Attachment 3: Proposed Well Schematic for 1J-10L1, 1J-10L1-01, 1J-10L1-02, & 1J-10L1-03laterals Page 6 of 6 January 15, 2019 ConocoPh i m s p ®ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad 1 J-10 1J-1®L1 Plan; 1J-10L1_wp01 17 December, 2018 BER T% " GHES GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1J-10 Wellbore: 1 J-10L1 Design: 1 J-10L1_wp01 ConocoPhillips Planning Report �(ER UGHES a GE company Local Co-ordinate Reference: Well 1J-10 TVD Reference: Mean Sea Level MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) North Reference: True Survey Calculation Method: 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 Site Kuparuk 1J Pad Site Position: Northing: 5,945,919.64 usft Latitude: 70° 15' 46.258 N From: Map Easting: 558,789.95 usft Longitude: 149' 31' 29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.45 ° Well 1J-10 Well Position +NI-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70' 15' 45.169 N +E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149' 31' 32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-101-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design 1J-101-1_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,166.00 Vertical Section: Depth From (TVD) +Nl-S +E/-W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 120.00 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) (°/100usft) (°I100usft) (°/100usft) (°) Target 10,166.00 52.95 295.12 5,790.91 3,587.77 -6,706.45 0.00 0.00 0.00 0.00 10,310.00 53.94 293.80 5,876.68 3,635.66 -6,811.74 1.01 0.69 -0.92 -47.36 10,335.00 56.55 292.00 5,890.93 3,643.65 -6,830.66 12.00 10.45 -7.19 330.00 10,500.00 56.55 292.00 5,981.87 3,695.23 -6,958.31 0.00 0.00 0.00 0.00 12/17/2018 10:37.55AM Page 2 COMPASS 5000.14 Build 85D ,Y, ConocoPhillips ConocoPhillips Planning Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Company: _ConocoPhillips Export Company TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: 1J-10 Survey Calculation Method: Wellbore: 1J-101-1 Design: 1 J-10 1-1_wp01 � iEf� 01 f- UGHES a GEconnpany Well 1J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (lJ-10:114.25) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (I (usft) (usft) (usft) (usft) ('1100usft) (°) (usft) (usft) 10,166.00 52.95 295.12 5,790.91 3,587.77 -6,706.45 -7,601.84 0.00 0.00 5,949,343.13 551,939.76 TIP 10,200.00 53.18 294.81 5,811.34 3,599.24 -6,731.09 -7,628.92 1.01 -47.36 5,949,354.40 551,915.04 10,300.00 53.87 293.89 5,870.79 3,632.39 -6,804.35 -7,708.94 1.01 -47.17 5,949,386.98 551,841.53 10,310.00 53.94 293.80 5,876.68 3,635.66 -6,811.74 -7,716.97 1.01 -46.63 5,949,390.19 551,834.11 KOP 10,335.00 56.55 292.00 5,890.93 3,643.65 -6,830.66 -7,737.35 12.00 -30.00 5,949,398.03 551,815.13 End 12 dls, Start tangent 10,400.00 56.55 292.00 5,926.75 3,663.97 -6,880.95 -7,791.06 0.00 0.00 5,949,417.95 551,764.70 10,500.00 56.55 292.00 5,981.87 3,695.23 -6,956.31 -7,873.68 0.00 0.00 5,949,448.60 551,687.10 Planned TD at 10500.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,500.00 5,981.87 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N1-S +E/-W (usft) (usft) (usft) (usft) Comment 10,166.00 5,790.91 3,587.77 -6,706.45 TIP 10.310.00 5,876.68 3,635.66 -6,811.74 KOP 10,335.00 5,890.93 3,643.65 -6,830.66 End 12 dls, Start tangent 10,500.00 5,981.87 3,695.23 -6,958.31 Planned TD at 10500.00 12/17/2018 10:37.55AM Page 3 COMPASS 5000.14 Build 85D CounucaphiMps �'Ajaska) MCI. -Kupl Kuparuk River Unit Kuparuk IJ Pad li-10 IJ-10LI IJ-IOLI—wpOl 07 December, 2018 PER BTGHES ER 0 GE company �. ConocoPhillips BAT ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-101-1 Reference Design: 1 J-10L1_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1J-10 1J-10:114.25 @ 114.25usft (lJ-10:114.25) 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1 J-101-1 wp01 =ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,238.58 usft Error Surface: Pedal Curve Survey Tool Program Date 12/7/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J-10(1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,500.00 1J-101-1_wp01 (1J-101-1) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9 5/8" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 10,500.00 6,096.12 2 3/8" 2.375 3.000 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 1J Pad 1 J-03 - 1J-03 - 1J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J-03 - 1J-031-1 - 1J-031-1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-03 - 1J-031-2 - 1 J-031-2 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03-1J-03L2PB1 - 1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-09 -1J-09 - 1J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09-1J-09A-iJ-09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09 - 1J-09ALl - 1 J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 11-10 - 1J-10 - 11-10 10,499.33 10,500.00 14.99 13.99 5.31 Pass - Major Risk 1J-10- 1J-1OL1-01 - 1J-101-1-01_wp02 Out of range 1J-10- 1J-10L1-02 - 1J-10L1-02_wp01 Out of range 1J-10- 1J-1OL1-03 - 1J-10L1-03_wp01 Out of range 1J-105 - 1J-105 - 1 J-105 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105- 1J-105L1 - 1J-105L1 305.08 300.00 218.10 4.82 213.29 Pass- Major Risk 1J-105 - 1J-105L2 - 1 J-1051-2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105P81-1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-107-1J-107-1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107- 1J-10711 - 1 J-107L1 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-109 - 11-109 - 1 J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109- 1J-109PB1 - 1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass- Major Risk 1J-115 - iJ-115 - 1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151-1 - 1 J-115L1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-11511PB1-1J-115L1PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-1151-1P132-1J-11511PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151-2 - 1J-115L2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-1151-2PB1-1J-1151-2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151-2PB2 - 1J-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/7/2018 9:56:40AM I I Page 2 COMPASS 5000.14 Build 85D i,. ConocoPhillips BA (ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit ND Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:11425) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-101-1 Database: EDT 14 Alaska Production Reference Design: 1J-10L1_wp01 Offset TVD 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 1J Pad 1J-115-1J-115P131-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB2 - 1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB3 - 1 J-115P83 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB4-1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk iJ-118-1J-118 - 1J-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118L1-1J-1181_1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - 1J-1181_2 - 1 J-1181_2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118P131-1J-11813131 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB2 - 1 J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-120-1J-120 - 1J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-120Ll - 1 J-120L1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - iJ-1201-1 P131 - 1J-120L1 PBi 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk iJ-120-1J-120L1 P132 - 1J-120L1 P132 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - iJ-120L1 P133 - 1 J-120L1 P133 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 -1 J-120Ll PB4 - 1 J-120L1 PB4 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L2 - 1 J-1201-2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L2PB1-1J-120L2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-152 - iJ-152 - iJ-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-1521_1-1J-1521_1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1 J-152-1J-152L2 - 1 J-1521_2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152L2PB1-1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152- 1J-152PB1 - 1J-152PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 -1 J-152PB2 - 1 J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-154 - 1 J-154 - 1J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154-1J-154L1 - 1 J-1541-1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154-1J-154L2 - 1 J-1541_2 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-156-1J-156-1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-iJ-1561_1-1J-156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-1561-1PB1-1J-156L1PB1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-1561_2-1J-1561_2 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1 J-158 -1 J-158 - 1 J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-158-1J-1581-1-1J-158L1 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1 J-159 - 1 J-159 - 1 J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk iJ-159-1J-159L1-iJ-1591-1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L1PB1-1J-1591-1PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L1 P82 - 1J-159L1 P132 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk iJ-159-1J-1591_2-1J-1591_2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk iJ-159- 1J-159PB1 - 1J-159P131 405.33 400.00 38.11 6.69 31.42 Pass- Major Risk 1 J-160 -1 J-160 - 1 J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160 - 1J-160L1 - 1 J-1601-1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-iJ-1601-1P131-1J-1601-1P81 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk iJ-160-1J-1601-2-1J-1601-2 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1 J-162 -1 J-162 - 1 J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 -1 J-162L1 - 1 J-162L1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - 1 J-162L1 PBi - 1J-162L1 PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162- 1J-162PB1 - 1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass- Major Risk 1J-162-1J-162PB2-1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-164-1J-164-iJ-164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164 - iJ-164L1 - 1 J-1641_1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164-1J-164L2 - 1J-1641_2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164-1J-164L2PB1-1J-164L2PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1 J-166 - 1 J-166 - 1 J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk iJ-166 - 1J-1661-1 - 1 J-1661-1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12172018 9:56:40AM Page 3 COMPASS 5000.14 Build 85D i r `. ConocoPhillips BAER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error. 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-10L1 Database: EDT 14 Alaska Production Reference Design: 1J-10L1_wp01 Offset TVD 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 1J Pad 1J-166-1J-166L1PB1-1J-166L1PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1 J-166 -1 J-1661-2 - 1 J-1661_2 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166L2PB1-1J-166L2PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-168 - 1J-168 - 1 J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168- 1J-168L1 - 1J-168L1 404.72 400.00 161.98 6.61 155.38 Pass- Major Risk 1J-168-1JA681_2-1J-1681_2 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-170 - 1J-170 - 1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J-170 - iJ-17OL1 - 1 J-170L1 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J-170 - 1J-1701-2 - 1J-1701-2 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170- 1J-170PB1 - iJ-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass- Major Risk 1J-170-iJ-170PB2-iJ-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 - Prelim: 1 J- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1 J-104 L1 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1 J-104 (empty) - Prelim: 1J-104 L2 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB1x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 offset Site Error. 0.00 usft Survey Program: 201-MWD+IFR-AK-SCC 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 +NIS +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) lush) lush) (1 (usft) (usft) (in) (usft) (usft) lush) 114.25 114.25 116.12 116.12 0.00 0.00 46.71 110.69 117.51 8.875 161.44 0.74 160.70 Pass - Major Risk, CC, ES, SF 197.92 197.92 200.00 199.98 0.06 0.05 46.87 111.45 118.89 8.875 163.01 1.83 161.18 Pass- Major Risk 297.75 297.75 300.00 299.90 0.15 0.17 47.31 113.30 122.46 8.875 167.03 3.41 163.63 Pass - Major Risk 397.01 397.00 400.00 399.80 0.27 0.28 47.93 115.05 126.60 8.875 171.49 4.97 166.52 Pass - Major Risk 493.34 493.32 500.00 499.54 0.38 0.40 49.14 117.62 133.26 8.875 179.64 6.53 173.12 Pass - Major Risk 587.98 587.87 600.00 598.96 0.49 0.53 51.31 120.27 143.56 8.875 192.72 8.10 184.64 Pass - Major Risk 677.68 677.31 700.00 697.93 0.60 0.67 53.92 123.90 157.36 8.875 212.30 9.64 202.72 Pass- Major Risk 752.37 751.30 800.00 796.49 0.69 0.81 57.67 124.33 174.25 8.875 238.69 10.99 227.80 Pass - Major Risk 836.40 833.59 900.00 894.76 0.82 0.95 61.01 127.00 192.55 8.875 273.85 12.51 261.59 Pass - Major Risk 921.90 916.44 1,000.00 992.43 0.95 1.12 63.78 132.65 213.20 8.875 316.43 14.15 302.78 Pass - Major Risk 1,002.62 994.25 1,100.00 1,088.93 1.08 1.34 66.04 141.43 237.88 8.875 365.16 15.84 350.18 Pass - Major Risk 1.072.17 1.060.68 1.200.00 1,183.97 1.21 1.59 67.68 153.99 266.27 8.875 420.60 17.51 404.45 Pass - Major Risk 1.128.96 1,114.17 1.300.00 1.276.57 1.32 1.90 68.70 171.29 299.72 8.875 484.87 19.14 467.71 Pass - Major Risk 1,186.86 1,168.03 1,400.00 1,365.40 1.45 2.28 69.33 193.00 340.12 8.875 557.89 21.02 539.71 Pass - Major Risk 1,236.53 1,213.77 1,500.00 1.451.11 1.57 2.72 69.75 218.16 386.04 8.875 636.46 22.91 617.42 Pass - Major Risk 1,280.95 1,254.20 1,600.00 1.533.47 1.68 3.22 70.28 245.70 434.57 8.875 719.64 24.83 699.84 Pass - Major Risk 1,316.75 1,286.41 1.700.00 1.611.71 1.76 3.77 70.68 275.94 488.99 8.875 807.16 26.73 786.71 Pass - Major Risk 1,350.74 1,316.67 1,800.00 1,686.35 1.86 4.37 70.91 308.71 546.89 8.875 897.66 28.75 876.61 Pass - Major Risk 1,377.15 1,339.96 1,900.00 1.756.58 1.93 5.02 71.00 343.98 608.70 8.875 990.96 30.74 969.42 Pass - Major Risk 1,410.41 1,369.01 2,000.00 1,822.44 2.02 5.72 71.04 381.24 674.06 8.875 1,086.49 32.93 1,064.35 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/7/2018 9:56:40AM Page 4 COMPASS 5000.14 Build 85D y ConocoPhiilips BA_ �CER ConocoPhlllips Travelling Cylinder Report 11 IGHES BAT GE company Company: ConocoPhiilips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Welibore 1J-101-1 Reference Design: 1J-10L1_Wp01 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1J-10 1J-10:114.25 @ 114.25usft (lJ-10:114.25) 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum 3ffset Design Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 Offset Site Error: 0.00 usi Survey Program: 201-MWD+IFR-AK-SCC Rule Assigned: Major Risk Offset Well Error: 0.00 usl 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 +N1S +E1-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (in) (usft) (usft) (usft) 1,417.06 1,374.77 2,100.00 1,883.19 2.03 6.45 70.93 420.25 743.21 8.875 1,183.65 34.82 1,161.34 Pass -Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/7/2018 9:56:40AM Page 5 COMPASS 5000.14 Build 85D HFU W. LU 21 F LuL9.� Q �l ry 0 23; e E 0 3°N ;ts, d� A N y C) Y O V 0 c o----------- a - 0 0 c c 5 - a' W o o a c Y1 .a 0 c -I �o v ^ c - 0 0 0 0 0 0 0 0 0 0 0 O O 2400 2700 3000 3300 3600 3900 3200 i V50C c 180C G r UOC + 40C a 70C 'u a 00C 300 600 900 200 500 B00 N a co J CV ch c o y o m o � o �`p U o vi v c, c c _ O c _ Q F- Y W fL CD v vr�v�m �'oorn�m In c0 I� (h j O Tz Cl) co.0 1� m al az N O cD O' O � co J , co O 1� 0 0 L6 I- `r 23 r Zn rnoroo m0000 o�o��o V • I � CO M LU cfl�oco o� + M�aoaMO� C c0 (O CO COp N M J Q �1,- W C0 CnnOu�M f� cD co cV 00 Z t� ui ai u'i + W L] c0 LO coo coo M M M M J W N UJrnornm p)c0 loco o. > rn r rn o0 c o F— .0 N It:! CD z CC) _ N IR C,OO c LO M N N LO N N N N U LL] --;r N COS Q1N OO LO M LO �O +O 0 0 0 0 0 O O O O [ O O N O M M �tJ r N M V Z O + -24C -255 -270 285 0 300 o -315 o -330, -345� -360( -375( 390( 405( -420C -435C 450C o 4650 O -4800 rl O_ O -4950 O -5100 5250 -5400 5550 5700 5850 6000 -6150 6300 6450 6600 6750 wl o -6900 0 -7050 -7200 -7350 7500 -7650 O -7800 � O : C O -7950 ry O..i O m N J -8100 c 9 � C 0 8250 a � -8400 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I ConocoPhillips Export Company Kuparuk River Unit Kuparuk IJ '.;• Plan: 1J-10L1-01 wp02 • •. 0 • • �, 17 December, 2018 BA ER UGHES a GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1J-10 Wellbore: 1J-10L1-01 Design: 1 J-10 L1-01_wp02 ConocoPhilGps SWER Planning Report UGHES a GE company Local Co-ordinate Reference: Well 1J-10 TVD Reference: Mean Sea Level MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) North Reference: True Survey Calculation Method: 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 Site Kuparuk 1J Pad Site Position: Northing: 5,945,919.64usft Latitude: 70' 15' 46.258 N From: Map Easting: 558,789.95 usft Longitude: 1490 31' 29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 ° Well 1 J-10 Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70' 15' 45.169 N +E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149' 31' 32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-10L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design 1J-101-1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,420.00 Vertical Section: Depth From (TVD) +N/-S +Ef-W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 120.00 1211712018 10:42:18AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillipsER ConocoPhillips Planning Report I-�UGHIES a GE company Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: U-10 Wellbore: U-1OL1-01 Design: 1J-101-1-01 wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +Nl-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°I100usft) (°/100usft) (°I10ousft) (°) Target 10,420.00 56.55 292.00 5,937.78 3,670.22 -6,896.42 0.00 0.00 0.00 0.00 10,441.00 59.11 290.29 5,948.96 3,676.63 -6,913.00 14.00 12.18 -8.15 330.00 10,517.97 90.00 273.78 5,969.34 3,691.06 -6,984.57 45.00 40.13 -21.45 330.00 10,800.00 90.00 146.87 5,969.34 3,494.42 -7,099.58 45.00 0.00 -45.00 270.00 11,125.00 90.00 124.12 5,969.34 3,264.16 -6,873.25 7.00 0.00 -7.00 270.00 11,330.00 77.61 116.83 5,991.46 3,160.95 -6,698.13 7.00 -6.05 -3.56 210.00 11,530.00 77.98 102.51 6,033.96 3,095.37 -6,514.58 7.00 0.19 -7.16 270.00 11,735.00 90.47 109.63 6,054.58 3,038.94 -6,319.14 7.00 6.09 3.47 30.00 12,035.00 91.15 130.62 6,050.29 2,889.25 -6,061.12 7.00 0.23 7.00 88.00 12,300.00 91.09 112.06 6,045.04 2,752.05 -5,835.82 7.00 -0.02 -7.00 270.00 12,700.00 83.54 139.07 6,064.11 2,522.19 -5,513.88 7.00 -1.89 6.75 106,00 13,050.00 89.04 115.14 6,087.08 2,313.28 -5,237.34 7.00 1.57 -6.84 282.00 13,300.00 89.69 132.63 6,089.88 2,174.45 -5,030.62 7.00 0.26 7.00 88.00 13,700.00 90.19 104.63 6,090.30 1,984.68 -4,683.02 7.00 0.13 -7.00 271.00 14,050.00 85.23 128.65 6,104.48 1,829.16 -4,372.76 7.00 -1.42 6.86 102,00 14,450.00 90.45 101.11 6,119.85 1,662.80 -4,013.70 7.00 1.30 -6.88 280.00 14,850,00 89.69 129.10 6,119.35 1,494.75 -3,655.09 7.00 -0.19 7.00 91.50 15,200.00 90.13 104.61 6,119.89 1,337.84 -3,345.21 7.00 0.13 -7.00 271.00 12/17/2018 10:42:18AM Page 3 COMPASS 5000.14 Build 85D 10,. ConocoPhillips Ckmocomillips Planning Report T�UIEGRHES GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-10L1-01 Design: 1 J-10L1-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S ¢E/-W Section Rate Azimuth Northing Easting (usft) (1) (1) (usft) (usft) (usft) (usft) (°/100usft) (1) (usft) (usft) 10,420.00 56.55 292.00 5,937.78 3,670.22 -6,896.42 -7,807.58 0.00 0.00 5,949,424.08 551,749.18 TIPIKOP 10,441.00 59.11 290.29 5,948.96 3,676.63 -6,913.00 -7,825.14 14.00 -30.00 5,949,430.36 551,732.55 End 14 dis, Start 45 dis 10,500.00 82.70 277.27 5,968.20 3,689.34 -6,966.73 -7,878.03 45.00 -30.00 5,949,442.65 551,678.72 10,517.97 90.00 273.78 5,969.34 3,691.06 -6,984.57 -7,894.34 45.00 -25.63 5,949,444.23 551,660.88 3 10,600.00 90.00 236.87 5,969.34 3,670.63 -7,062.56 -7,951.67 45.00 -90.00 5,949,423.20 551,583.06 10,700.00 90.00 191.87 5,969.34 3,590.20 -7,117.56 -7,959.09 45.00 -90.00 5,949,342.34 551,528.68 10,800.00 90.00 146.87 5,969.34 3,494.42 -7,099.58 -7,895.63 45.00 -90.00 5,949,246.72 551,547.41 End 45 dls, Start 7 dls 10,900.00 90.00 139.87 5,969.34 3,414.22 -7,039.95 -7,803.89 7.00 -90.00 5,949,167.00 551,607.66 11,000.00 90.00 132.87 5,969.34 3,341.89 -6,970.99 -7,708.00 7.00 -90.00 5,949,095.21 551,677.17 11,100.00 90.00 125.87 5,969.34 3,278.50 -6,893.73 -7,609.39 7.00 -90.00 5,949,032.43 551,754.92 11,125.00 90.00 124.12 5,969.34 3,264.16 -6,873.25 -7,584.49 7.00 -90.00 5,949,018.26 551,775.51 5 11,200.00 85.46 121.49 5,972.32 3,223.58 -6,810.28 -7,509.66 7.00 -150.00 5,948,978.17 551,838.78 11,300.00 79.41 117.92 5,985.48 3,174.47 -6,724.24 -7,410.60 7.00 -149.90 5,948,929.74 551,925.20 11,330.00 77.61 116.83 5,991.46 3,160.95 -6,698.13 -7,381.23 7.00 -149.43 5,948,916.43 551,951.40 6 11,400.00 77.65 111.81 6,006.46 3,132.81 -6,635.85 -7,313.22 7.00 -90.00 5,948,888.77 552,013.90 11,500.00 77.88 104.65 6,027.69 3,102.26 -6,543.09 -7,217.61 7.00 -88.92 5,948,858.94 552,106.88 11,530.00 77.98 102.51 6,033.96 3,095.37 -6,514.58 -7,189.47 7.00 -87.41 5,948,852.28 552,135.45 7 11,600.00 82.23 104.98 6,045.99 3,078.98 -6,447.62 -7,123.29 7.00 30.00 5,948,836.42 552,202.53 11,700.00 88.33 108.43 6,054.21 3,050.35 -6,352.22 -7,026.36 7.00 29.58 5,948,808.53 552,298.13 11,735.00 90.47 109.63 6,054.58 3,038.94 -6,319.14 -6,992.00 7.00 29.29 5,948,797.38 552,331.30 8 11,800.00 90.63 114.17 6,053.96 3,014.70 -6,258.85 -6,927.67 7.00 88.00 5,948,773.62 552,391.77 11,900.00 90.86 121.17 6,052.66 2,968.30 -6,170.35 -6,827.83 7.00 88.04 5,948,727.91 552,480.62 12,000.00 91.08 128.17 6,050.97 2,911.46 -6,088.16 -6,728.23 7.00 88.13 5,948,671.71 552,563.24 12,035.00 91.15 130.62 6,050.29 2,889.25 -6,061.12 -6,693.71 7.00 88.25 5,948,649.72 552,590.45 9 12,100.00 91.15 126.07 6,048.98 2,848.95 -6,010.16 -6,629.43 7.00 -90.00 5,948,609.82 552,641.72 12,200.00 91.13 119.06 6,046.99 2,795.17 -5,925.96 -6,529.61 7.00 -90.09 5,948,556.70 552,726.33 12,300.00 91.09 112.06 6,045.04 2,752.05 -5,835.82 -6,429.99 7.00 -90.23 5,948,514.29 552,816.80 10 12,400.00 89.16 118.79 6,044.82 2,709.14 -5,745.56 -6,330.37 7.00 106.00 5,948,472.09 552,907.38 12,500.00 87.24 125.53 6,047.96 2,655.98 -5,661.00 -6,230.56 7.00 106.01 5,948,419.59 552,992.34 12,600.00 85.36 132.28 6,054.43 2,593.35 -5,583.38 -6,132.03 7.00 105.80 5,948,357.58 553,070.44 12,700.00 83.54 139.07 6,064.11 2,522.19 -5,513.88 -6,036.26 7.00 105.37 5,948,286.97 553,140.48 11 12,800.00 85.04 132.20 6,074.08 2,451.11 -5,444.35 -5,940.50 7.00 -78.00 5,948,216.44 553,210.56 12,900.00 86.61 125.36 6,081.37 2,388.68 -5,366.65 -5,841.99 7.00 -77.32 5,948,154.62 553,288.74 13,000.00 88.22 118.54 6,085.89 2,335.85 -5,281.94 -5,742.22 7.00 -76.82 5,948,102.46 553,373.85 13,050.00 89.04 115.14 6,087.08 2,313.28 -5,237.34 -5,692.31 7.00 -76.51 5,948,080.24 553,418.61 12 13,100.00 89.17 118.64 6,087.87 2,290.68 -5,192.76 -5,642.40 7.00 88.00 5,948,057.99 553,463.37 13,200.00 89.42 125.63 6,089.10 2,237.52 -5,108.14 -5,542.54 7.00 87.95 5,948,005.50 553,548.39 13,300.00 89.69 132.63 6,089.88 2,174.45 -5,030.62 -5,443.87 7.00 87.86 5,947,943.04 553,626.39 13 13,400.00 89.81 125.63 6,090.32 2,111.38 -4,953.10 -5,345.20 7.00 -89.00 5,947,880.58 553,704.39 12/17/2018 10:42:18AM Page 4 COMPASS 5000.14 Build 85D ✓ ConocoPhillips BA ER ConocoPhillips Planning Report I UGHES a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk I Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1J-101-1-01 Design: 1J-10L1-01 Wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (1 (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 13,500.00 89.94 118.63 6,090.54 2,058.23 -4,868.47 -5,245.33 7.00 -88.97 5,947,828.09 553,789.43 13,600.00 90.07 111.63 6,090.53 2,015.78 -4,778.00 -5,145.76 7.00 -88.95 5,947,786.36 553,880.22 13,700.00 90.19 104.63 6,090.30 1,984.68 -4,683.02 -5,047.95 7.00 -88.95 5,947,756.00 553,975.43 14 13,800.00 88.74 111.48 6,091.24 1,953.70 -4,588.01 -4,950.18 7.00 102.00 5,947,725.77 554,070.67 13,900.00 87.30 118.34 6,094.69 1,911.64 -4,497.42 -4,850.70 7.00 101.94 5,947,684.41 554,161.57 14,000.00 85.91 125.21 6,100.62 1,859.11 -4,412.61 -4,750.99 7.00 101.70 5,947,632.56 554,246.78 14,050.00 85.23 128.65 6,104.48 1,829.16 -4,372.76 -4,701.51 7.00 101.29 5,947,602.92 554,286.86 1s 14,100.00 85.85 125.20 6,108.37 1,799.22 -4,332.92 -4,652.03 7.00 -80.00 5,947,573.29 554,326.93 14,200.00 87.12 118.30 6,114.51 1,746.74 -4,248.10 -4,552.33 7.00 -79.73 5,947,521.48 554,412.15 14,300.00 88.44 111.42 6,118.39 1,704.75 -4,157.49 -4,452.87 7.00 -79.31 5,947,480.21 554,503.08 14,400.00 89.78 104.55 6,119.95 1,673.90 -4,062.44 -4,355.13 7.00 -79.04 5,947,450.10 554,598.35 14,450.00 90.45 101.11 6,119.85 1,662.80 -4,013.70 -4,307.36 7.00 -78.93 5,947,439.38 554,647.17 16 14,500.00 90.36 104.61 6,119,50 1,651.67 -3,964.96 -4,259.59 7.00 91.50 5,947,428.63 554,695.99 14,600.00 90.17 111.61 6,119.04 1,620.60 -3,869.98 -4,161.80 7.00 91.52 5,947,398.31 554,791.20 14,700.00 89.98 118.61 6,118.92 1,578.20 -3,779.48 -4,062.23 7.00 91.56 5,947,356.61 554,882.02 14,800.00 89.79 125.61 6,119.13 1,525.08 -3,694.83 -3,962.36 7.00 91.57 5,947,304.16 554,967.07 14,850.00 89.69 129.10 6,119.35 1,494.75 -3,655.09 -3,912.78 7.00 91.55 5,947,274.14 555,007.04 17 14,900.00 89.75 125.60 6,119.60 1,464.42 -3,615.35 -3,863.20 7.00 -89.00 5,947,244.12 555,047.01 15,000.00 89.88 118.61 6,119.92 1,411.30 -3,530.70 -3,763.33 7.00 -88.98 5,947,191.67 555,132.07 15,100.00 90.01 111.61 6,120.02 1,368.90 -3,440.20 -3,663.75 7.00 -88.96 5,947,149.98 555,222.88 15,200.00 90.13 104.61 6,119.89 1,337.84 -3,345.21 -3,565.96 7.00 -88.95 5,947,119.66 555,318.10 Planned TD at 15200.00 'asing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,200.00 6,119.89 23/8" 2.375 3.000 1211712018 10:42:18AM Page 5 COMPASS 5000.14 Build 85D ConocoPhilllps ConocoPhillips Planning Report IlA t�UGHES tE t a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (lJ-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-10L1-01 Design: 1 J-10L1-01_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/-W (usft) (usft) (usft) (usft) Comment 10,420.00 5,937.78 3,670.22 -6,896.42 TIP/KOP 10,441.00 5,948.96 3,676.63 -6,913.00 End 14 dls, Start 45 dis 10,517.97 5,969.34 3,691.06 -6,984.57 3 10,800.00 5,969.34 3,494.42 -7,099.58 End 45 dls, Start 7 dls 11,125.00 5,969.34 3,264.16 -6,873.25 5 11,330.00 5,991.46 3,160.95 -6,698.13 6 11,530.00 6,033.96 3,095.37 -6,514.58 7 11,735.00 6,054.58 3,038.94 -6,319.14 8 12,035.00 6,050.29 2,889.25 -6,061.12 9 12,300.00 6,045.04 2,752.05 -5,835.82 10 12,700.00 6,064.11 2,522.19 -5,513.88 11 13,050.00 6,087.08 2,313.28 -5,237.34 12 13,300.00 6,089.88 2,174.45 -5,030.62 13 13,700.00 6,090.30 1,984.68 -4,683.02 14 14,050.00 6,104.48 1,829.16 -4,372.76 15 14,450.00 6,119.85 1,662.80 -4,013.70 16 14,850.00 6,119.35 1,494.75 -3,655.09 17 15,200.00 6,119.89 1,337.84 -3,345.21 Planned TD at 15200.00 1211712018 10:42:18AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) 5nc� -Kupl Kuparuk Raver Unit Kuparuk 1J pad 1 J-10 1J-10L1-01 1 J-10L1-01_wp02 Travelling Cylinder Report 10 December, 2018 BER BA 0 GE company ,,. ConocoPhillips BA_ j(ER ConocoPhillips Travelling Cylinder Report IGHES BAT GEmmpany Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-10L1-01 Reference Design: 1 J-10L1-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 J-10 1J-10:114.25 @ 114.25usft (1J-10:114.25) 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum teference 1J-10L1-01_wp02 �ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North Zesults Limited by: Maximum center -center distance of 1,708.58 usft Error Surface: Pedal Curve Survey Tool Program Date 12110/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J-10(1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,420.00 1J-10L1_wp01 (1J-101-1) MWD MWD- Standard 10,420.00 15,200.00 1J-10L1-01_wp02(1J-101-1-01) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9 5/8" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 15,200.00 6,234.14 2 3/8" 2.375 3.000 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 1 E Pad 1 E-35 - Plan 1 E-35A - 1 E-35A (wp02) 14,800.00 14,900.00 980.15 524.29 458.57 Pass - Major Risk Kuparuk 1JPad 1 J-03 - 1J-03 - 1 J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J-03 - 1J-03L1 - 1J-03L1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03 - 1J-03L2 - 1J-031_2 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03 - 1J-03L2PB1 - 1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-09 - 11-09 - 1 J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09 - 1J-09A - 1 J-09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09 - 1J-09AL1 - 1J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-10 - 1J-10 - 1J-10 10,488.86 10,500.00 29.34 13.37 20.96 Pass - Major Risk 1J-10 - 1J-10L1 - 1 J-101_1 wp01 Out of range 1J-10-1J-101-1-02-1J-101-1-02_wp01 11,100.00 11,100.00 0.00 2.43 -0.42 FAIL - Minor 1 /10 1J-10-1J-1011-03-1J-101-1-03_wp01 11,100.00 11,100.00 0.00 2.43 -0.42 FAIL- Minor 1110 1 J-105 - 1 J-105 - 1 J-105 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105 - 1J-10511 - 1J-105L1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105 - 1J-10512 - 1 J-1051-2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105- 1J-105PB1 - 1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1 J-107 - 1 J-107 - 1 J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107- 1J-1071-1 - 1J-1071-1 305.01 300.00 190.36 4.92 185.44 Pass- Major Risk 11-109 - 11-109 - 1J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109 - 1J-109PB1 - 1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-115 - 1J-115 - 1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115L1 - 1J-115L1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151_1 PB1 - 1J-115L1 PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L1 P132 - 1 J-115L1 PB2 403.76 400.00 159A 5 6.67 152.48 Pass - Major Risk CG - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:21:10PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips (ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (lJ-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: iJ-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-10L1-01 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-01 wp02 Offset TVD 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 lJPad iJ-115-iJ-1151_2-1J-115L2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-11 5 - 1J-11 5L2PB1 - 1 J-11 5L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115L2PB2 - 1 J-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB1 - 1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB2 - 1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-l15PB3 - 1J-115PB3 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB4 - 1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-118-1J-118 - 1J-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118L1-1J-118L1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118- 1J-1181_2- 1J-1181_2 304.63 300.00 189.29 4.81 184.48 Pass- Major Risk 1J-118-1J-118PB1 - 1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB2 - i J-118P132 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-120- 1J-120- 1J-120 304.57 300.00 216.86 4.81 212.05 Pass- Major Risk 1J-120 - iJ-1201-1 - 1 J-120L1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-12OLlPB1-iJ-1201-1P131 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120LIPB2-1J-120LIP132 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-120L1 PB3 - 1 J-1201-1 PB3 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-1201_1P134-1J-1201-1P134 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L2 - 1J-1201_2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-iJ-120L2PB1-1J-120L2PB1 304.57 300.00 216.86 4.81 212,05 Pass - Major Risk 1J-152 - iJ-152 - iJ-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152L1 - 1J-152L1 405.78 400.00 200.32 6.58 193.74 Pass- Major Risk 1J-152-1J-1521_2-iJ-1521_2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152- 1J-152L2PB1 - 1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass- Major Risk 1J-152-1J-152PB1-iJ-152P131 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB2 - 1 J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-154-1J-154 - 1J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154-iJA54L1 - iJ-154L1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154 - 1J-1541-2 - 1J-1541_2 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-156-1J-156 - 1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-156L1-1J-1561-1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-iJ-156L1PB1-1J-156L1PB1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-1561_2-1J-1561_2 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-158-1J-158 - 1J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-158-1J-1581-1-1J-158L1 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-159-1J-159-1J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-159L1 - 1 J-1591-1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L1 PB1 - 1 J-159L1 P131 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L1 13132 - 1J-1591-1 P132 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-1591-2-1J-1591_2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk iJ-159 - iJ-159PB1 - 1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-160 - iJ-160 - 1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-160L1 - 1J-160L1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-16OLIPB1-1J-160L1PB1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-160L2-1J-160L2 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-162-1J-162 - lJ-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162- 1J-162L1 - 1J-1621-1 491.49 500.00 40.65 8.37 32.28 Pass- Major Risk 1J-162-1JA62LIPB1-iJ-162LiPB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-lJ-162PB1-iJ-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162P132 - 1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-164 - 1J-164 - 1J-164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164-iJ-164L1-1J-164L1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164 -1 J-1641_2 - 1 J-1641-2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12110/2018 4:21:10PM Page 3 COMPASS 5000.14 Build 85D 10-1 ConocoPhillips BA (ER ConocoPhillips Travelling Cylinder Report i�UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk I Pad MD Reference: 1J-10:114.25 @ 114.25usft (lJ-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-101-1-01 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-01_wp02 Offset TVD 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 1J Pad 1J-164- 1J-164L2PB1 - 1J-164L2PB1 796.36 800.00 77.47 13.02 64.51 Pass- Major Risk 1J-166 - 1J-166 - 1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166L1-1J-1661-1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166LIPB1-1J-166LIP131 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - 1J-16612 - 1J-166L2 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - 1J-166L2PB1 - 1J-166L2PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1 J-168 - 1J-168 - 1 J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 - 1J-168L1 - 1J-1681-1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 - 1J-1681_2 - 1 J-16812 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-170 - 1J-170 - 1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J-170-1J-170L1-1J-17OLl 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J-170 - iJ-170L2 - 1J-1701-2 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170 - 1J-170PB1 - 1J-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk 1J-170 - 1J-170PB2 - 1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1 J-104 - Prelim: 1J- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1 J-104 (empty) - Prelim: 1 J-104 L2 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB1x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 E Pad - 1 E-35 - Plan 1 E-35A - 1 E-35A (wp02) Offset site Error: 0,00 usft Survey Program: 199-GYD-CT-CMS, 6963-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Onset 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 +NIS +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) M (usft) (usft) (in) (usft) (usft) (usft) 13,900.00 6,208.94 13,700.00 5,798.68 55.02 110.45 42.28 3,338.25 -3,668.78 5.000 1,699.37 438.66 1,266.27 Pass - Major Risk 13,950.00 6,211.60 13,800.00 5,825.46 55.52 111.94 45.20 3,253.12 -3,623.67 5.000 1,644.38 452.60 1,203.16 Pass - Major Risk 13,950-00 6,211.60 13,900.00 5,852.24 55.52 113.44 44.84 3,167.98 -3,578.56 5.000 1,592.39 456.38 1,139.51 Pass - Major Risk 14,520.69 6,233.63 14,000.00 5,879.02 61.71 114.94 29.31 3,082.85 -3,533.45 3.000 1,535.28 417.35 1,127.32 Pass - Major Risk 14,550.00 6,233.48 14,100.00 5,905.80 62.05 116.44 30.95 2,997.71 -3,488.33 3.000 1,462.60 430.15 1,043.86 Pass - Major Risk 14,570.71 6,233.39 14,200.00 5,932.58 62.29 117.95 31.92 2,912.58 -3,443.22 3.000 1,392.03 440.00 960.62 Pass - Major Risk 14,600.00 6,233.29 14,300.00 5,959.36 62.64 119.45 33.43 2,827.45 -3,398.11 3.000 1,323.86 452.37 880.39 Pass - Major Risk 14,627.13 6.233.23 14,400.00 5,986.14 62.97 120.96 34.70 2,742.31 -3,353.00 3.000 1.258.30 463.82 801.86 Pass - Major Risk 14,650.00 6,233.19 14,500.00 6,012.92 63.24 122.46 35.59 2,657.18 -3,307.89 3.000 1,195.70 473.82 725.15 Pass - Major Risk 14,700.00 6,233.17 14,600.00 6,039.71 63.85 123.97 38.27 2.572.04 -3,262.78 3.000 1,136.24 490.68 655.04 Pass - Major Risk 14,725.15 6,233.19 14,700.00 6,066.49 64.15 125.48 39.09 2,486.91 -3,217.67 3.000 1,080.17 500.53 584.43 Pass - Major Risk 14,750.00 6,233.23 14,800.00 6,093.27 64.46 127.00 39.78 2,401.77 -3,172.56 3.000 1,028.20 510.04 517.95 Pass - Major Risk 14,800.00 6,233.38 14,900.00 6,120.05 65.06 128.51 42.08 2,316.64 -3,127.45 3.000 980.15 524.29 458.57 Pass- Major Risk, CC, ES, SF CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1211012018 4:21:10PM I . 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eO C N C O c:! d: t- -� m M m N O r N� C O r p � a p I ZoW V �t a MCV C-4C')� V G5N Rr � W } I� r m m C O C O m M o C n N ti m N (O O M <OCOCO V N0mC-,LnCl) C mv� Q M M M M M M M C' M N N C V N N Jc n m m m t O m O d- r m m O m C n L O 0 W � n cI M M 1' ,I: m CA N O r O m M� m M m cmQl cco mmmm M V OLA I-mO'tmmm o M�cnmw ") Lo-.4- o o o m m m c"o 0 0 m m 0 0 0 0 0 .- ` cc; Ln mLn Ln Ln �cpm mco c0mmmca co co cn O o Z L "N O m m I- N c.)r M N tO n d' M M Lt'> r O r L17 a O N 1� m r m C.O O O O r CO CO cO V3 C V O M C O V CO N O O C V m L n N 1- m - m �% Omf Nr `""" 00 yr �r aM-O CV pN0 N N N r r U a] 1- LOm `cf m O)M t[>mM C Lnr 000Om V' O Ln O cx � N 7 CO •- ilOj rn rn rn n rn W T m m � LOO ti OOi m aMO amo 60i amo +0 p o o I� o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 1+• O L 0 cD Lfj to C� 0 0 0 0 0 CyO O NQ ONMMMMOOLOOOLL7 u] CAO ct LomrM K)1�OM r-O MI�O'rmN 0 0 0 o r r � Y �o rrr�- Zo��NMvtnml`mmo�NMVLn corm rr.-t2 rrr + 0 a r b 90 10-I 01-fl--------- ------------------ O SOS 10-1'f 1-f l -- ---------- -- ---- ----- ' -'------ a 0 - - c � o _ 0 -5 407. 10-1'1 l-fl-- --------- --------- - - -5 -5 _ -6 - ---'----- '....---- - 6 6 6 -6 6' WI O 0 Z l0-1 ol-fl _- _ -- o -71 -7: -7, O - N -7, -7f H ---- O W r �• o -75 _ a N , J -81 o ti d -82 � -84 0 0 0 0 o voi o � o 0 00 0 9-400 2550 2700 2850 3000 3150 1300 1450 600 750 900 050 200 350 50o 550 300 d50 O 100 0 so 0 0 100 ;so O '00 y In 50 U i00 so 00 50 00 50 00 50 )o so )o 50 )0 f0 )o i0 10 —ConocoPhillips Export Kuparuk River Unit Kuparuk 1J Pad 1 J-10 Plan: 1J-101-1-02 wp01 17 December, 2018 BER BA 00 GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-10 Wellbore: 1 J-10L1-02 Design: 1 J-10L1-02_wp01 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: B4GHES ER BA GE company Well 1J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) 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 Site Kuparuk 1J Pad Site Position: Northing: 5,945,919.64 usft Latitude: 70° 15' 46.258 N From: Map Easting: 558,789.95 usft Longitude: 149° 31' 29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 Well 1J-10 Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15' 45.169 N +E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149° 31' 32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-10L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (°) W) BGGM2018 2/1/2019 16.77 80.84 57,424 Design iJ-10L1-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,300.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 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) (°/100usft) (°/loousft) (°/100usft) (°) Target 12,300.00 88.48 142.97 6,045.13 2,762.32 -5,844.45 0.00 0.00 0.00 0.00 12,425.00 80.92 147.39 6,056.67 2,660.26 -5,773.42 7.00 -6.05 3.53 150.00 12,575.00 90.03 152.61 6,068.50 2,530.92 -5,698.80 7.00 6.08 3.49 30.00 12,900.00 91.96 175.29 6,062.76 2,220.69 -5,609.53 7.00 0.59 6.98 85.00 13,225.00 91.81 198.05 6,051.92 1,900.18 -5,647.00 7.00 -0.05 7.00 90.00 13,500.00 91.71 178.79 6,043.39 1,629.56 -5,687.06 7.00 -0.04 -7.00 270.00 13,775.00 90.63 198.01 6,037.73 1,358.84 -5,727.05 7.00 -0.39 6.99 93.00 14,175.00 90.55 170.01 6,033.54 963.80 -5,754.76 7.00 -0.02 -7.00 270.00 14,375.00 90.54 184.01 6,031.63 764.58 -5,744.36 7.00 -0.01 7.00 90.00 14,775.00 90.47 156.01 6,028.04 374.57 -5,675.68 7.00 -0.02 -7.00 270.00 12/17/2018 10:44:13AM Page 2 COMPASS 5000.14 Build 85D ✓ ConocoPhillips BA EI? ConoeoPhillips Planning Report F�UGHES a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: iJ-1OL1-02 Design: 1J-101-1-02 wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (a) (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 12,300.00 88.48 142.97 6,045.13 2,762.32 -5,844.45 -2,762.32 0.00 0.00 5,948,524.49 552,808.08 11P/KOP 12,400.00 82.43 146.49 6,053.05 2,680.99 -5,786.92 -2,680.99 7.00 150.00 5,948,443.62 552,866.25 12,425.00 80.92 147.39 6,056.67 2,660.26 -5,773.42 -2,660.26 7.00 149.72 5,948,423.00 552,879.90 Start 7 dls 12,500.00 85.47 150.02 6,065.56 2,596.64 -5,734.76 -2,596.64 7.00 30.00 5,948,359.69 552,919.06 12,575.00 90.03 152.61 6,068.50 2,530.92 -5,698.80 -2,530.92 7.00 29.69 5,948,294.26 552,955.52 3 12,600.00 90.19 154.36 6,068.45 2,508.55 -5,687.64 -2,508.55 7.00 85.00 5,948,271.98 552,966.85 12,700.00 90.79 161.33 6,067.60 2,415.99 -5,649.95 -2,415.99 7.00 85.00 5,948,179.73 553,005.26 12,800.00 91.39 168.31 6,065.69 2,319.56 -5,623.78 -2,319.56 7.00 85.06 5,948,083.51 553,032.17 12,900.00 91.96 175.29 6,062.76 2,220.69 -5,609.53 -2,220.69 7.00 85.20 5,947,984.76 553,047.20 4 13,000.00 91.95 182.29 6,059.34 2,120.83 -5,607.42 -2,120.83 7.00 90.00 5,947,884.93 553.050.08 13,100.00 91.91 189.29 6,055.98 2,021.46 -5,617.50 -2,021.46 7.00 90.24 5,947,785.49 553,040.78 13,200.00 91.83 196.30 6,052.71 1,924.05 -5,639.62 -1,924.05 7.00 90.48 5,947,687.93 553,019.42 13,225.00 91.81 198.05 6,051.92 1,900.18 -5,647.00 -1,900.18 7.00 90.70 5,947,664.00 553,012.23 5 13,300.00 91.80 192.80 6,049.55 1,827.94 -5,666.93 -1,827.94 7.00 -90.00 5,947,591.62 552,992.86 13,400.00 91.77 185.79 6,046.43 1,729.37 -5,683.06 -1,729.37 7.00 -90.17 5,947,492.93 552,977.50 13,500.00 91.71 178.79 6,043.39 1,629.56 -5,687.06 -1,629.56 7.00 -90.38 5,947,393.10 552,974.29 5 13,600.00 91.33 185.78 6,040.73 1,529.73 -5,691.04 -1,529.73 7.00 93.00 5,947,293.26 552,971.08 13,700.00 90.93 192.77 6,038.75 1,431.12 -5,707.15 -1,431.12 7.00 93.19 5,947,194.53 552,955.74 13,775.00 90.63 198.01 6,037.73 1,358.84 -5,727.05 -1,358.84 7.00 93.32 5,947,122.11 552,936.41 7 13,800.00 90.63 196.26 6,037.46 1,334.96 -5,734.41 -1,334.96 7.00 -90.00 5,947,098.17 552,929.23 13,900.00 90.62 189.26 6,036.37 1,237.49 -5,756.49 -1,237.49 7.00 -90.02 5,947,000.54 552,907.91 14,000.00 90.60 182.26 6,035.31 1,138.07 -5,766.53 -1,138.07 7.00 -90.10 5,946,901.05 552,898.66 14,100.00 90.58 175.26 6,034.28 1,038.16 -5,764.37 -1,038.16 7.00 -90.17 5,946,801.17 552,901.59 14,175.00 90.55 170.01 6,033.54 963.80 -5,754.76 -963.80 7.00 -90.24 5,946,726.90 552,911.78 8 14,200.00 90.55 171.76 6,033.30 939.12 -5,750.80 -939.12 7.00 90.00 5,946,702.26 552,915.93 14,300.00 90.55 178.76 6,032.34 839.53 -5,742.55 -839.53 7.00 90.02 5,946,602.74 552,924,96 14,375.00 90.54 184.01 6,031.63 764.58 -5,744.36 -764.58 7.00 90.08 5,946,527.79 552,923.73 9 14,400.00 90.54 182.26 6,031.40 739.62 -5,745.73 -739.62 7.00 -90.00 5,946,502.82 552,922.55 14,500.00 90.53 175.26 6,030.47 639.71 -5,743.57 -639.71 7.00 -90.02 5,946,402.94 552,925.49 14,600.00 90.52 168.26 6,029.55 540.81 -5,729.25 -540.81 7.00 -90.08 5,946,304.16 552,940.58 14,700.00 90.49 161.26 6,028.67 444.39 -5,702.99 444.39 7.00 -90.15 5,946,207.96 552,967.59 14,775.00 90.47 156.01 6,028.04 374.57 -5,675.68 -374.57 7.00 -90.21 5,946,138.36 552,995.44 Planned TD at 14775.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,775.00 6,028.04 2 3/8" 2.375 3.000 1211712018 10.44:13AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA R ConocoPhillips Planning Report 1 UGHES a GE company Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: iJ-10 Welibore: 1 J-10L1-02 Design: 1 J-10L1-02_wp01 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 12,300.00 6,045.13 12,425.00 6,056.67 12,575.00 6,068.50 12,900.00 6,062.76 13,225.00 6,051.92 13,500.00 6,043.39 13,775.00 6,037.73 14,175.00 6,033.54 14,375.00 6,031.63 14,775.00 6,028.04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Local Coordinates +N/-S +E/-W (usft) (usft) 2,762.32 -5,844.45 2,660.26 -5,773.42 2,530.92 -5,698.80 2,220.69 -5,609.53 1,900.18 -5,647.00 1,629.56 -5,687.06 1,358.84 -5,727.05 963.80 -5,754.76 764.58 -5,744.36 374.57 -5,675.68 Comment TIP/KO P Start 7 dls 3 4 5 6 7 8 9 Planned TD at 14775.00 Well 1J-10 Mean Sea Level 1 J-10:114.25 @ 114.25usft (1 J-10:114.25) True Minimum Curvature 12/17/2018 10:44:13AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips onocoPhilli s � Masks) Jnc. ®Kup1 Kuparuk River Unit Kuparuk 1J Pad 1J®10 IJm10LI-02 1 J-10L1-02_wp01 10 December, 2018 BER T' " GHES GE company ,,. ConocoPhillips I3A_ j<ER ConocoPhillips Travelling Cylinder Report i�UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-10L1-02 Reference Design: 1 J-10L1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 J-10 1J-10:114.25 @ 114.25usft (lJ-10:114.25) 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1J-10L1-02_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,666.08 usft Error Surface: Pedal Curve Survey Tool Program Date 12/10/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J-10 (1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,420.00 1J-101_1_wp01 (1J-101_1) MWD MWD- Standard 10,420.00 12,300.00 1J-10L1-01_wp01 (1J-101-1-01) MWD MWD- Standard 12,300.00 14,775.00 1J-10L1-02_wp01 (1J-101-1-02) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9 518" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 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 1J Pad 1J-03 - 1J-03 - iJ-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J-03 - 1J-03L1 - 1J-03L1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk iJ-03 - 1J-03L2 - 1J-031-2 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-03 - 1J-03L2PB1 - 1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 11-09 - 11-09 - 11-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09-1J-09A-1J-09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09 - 1J-09ALl - 1J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 11-10 - 11-10 - 11-10 10,488.86 10,500.00 29.34 13.60 20.73 Pass - Major Risk 1J-10 - 1J-10L1 - 1J-10L1_wp01 Out of range 1J-10- 1J-1OL1-01 - 1J-10L1-01_wp02 12,313.37 12,300.00 0.93 2.64 -1.78 FAIL - Minor 1/10 1J-10 - 1J-1OLl-03 - 1J-10L1-03_wp01 12,469.66 12,500.00 106.86 2.03 104.92 Pass - Minor 1/10 1 J-105-1J-105 - 1 J-105 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-1051-1-1J-1051-1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1 J-105 - 1 J-105L2 - 1 J-1051_2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105PB1-1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1 J-107-1J-107 - 1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107-1J-107L1-1J-107L1 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 11-109 - 1J-109 - 1J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109 - 1J-109PB1 - 1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-115-1J-115 - 1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151_1 - 1J-115L1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-1151-1PB1-1J-115L1PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115L1 PB2 - 1J-115L1 PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-1151_2 - 1J-115L2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L2PB1 - 1J-115L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergent point. SF - min separation factor, ES - min ellipse separation 1211012018 4:32:27PM Page 2 COMPASS 5000.14 Build 85D IV, ConocoPhillips Ad<ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (lJ-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore lJ-101-1-02 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-02_wp01 Offset TVD 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 1J Pad 1J-115 - 1J-115L2PB2 - 1J-115L2P62 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB1-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB2 - 1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB3 - iJ-115PB3 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB4 - 1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 11-118 - 11-118 - iJ-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - 1J-1181_1 - 1J-1181_1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - 1J-1181-2 - 1 J-1181-2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - 1J-118PB1 - 1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - iJ-118P62 - 1J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1 J-120 - 1 J-120 - 1 J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L1 - 1J-12OL1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - iJ-120L1 P131 - 1J-12OL1 P131 304.57 300.00 216,86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-12OL1 PB2 - 1 J-120Ll PB2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L1 PB3 - 1 J-120L1 P133 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-120Ll PB4 - 1J-1201-1 PB4 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-1201-2 - 1 J-1201_2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-120L2PB1 - 1J-120L2P81 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-152-1J-152 - 1 J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - iJ-152L1 - 1 J-152L1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-1521_2 - 1J-1521_2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152L2P61 - 1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-152P61 - 1J-152PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-152PB2 - 1 J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-154 - 1J-154 - 1 J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1 J-154 - 1J-1541-1 - 1 J-1541-1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154 - 1J-1541_2 - 1 J-1541_2 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-156 - 1J-156 - 1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-156L1 - 1 J-156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-1561-1PB1-1J-1561-1PB1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156 - 1J-1561-2 - 1 J-1561_2 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-158 - 1J-158 - iJ-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1 J-158 - 1J-158L1 - 1 J-1581-1 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1 J-159 - iJ-159 - 1 J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-1591-1 - 1 J-1591-1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-159L1 PBi - 1J-159L1 PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-1591-1 PB2 - 1J-1591_1 PB2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - iJ-1591-2 - 1J-1591_2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-159PB1 - 1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-160 - 1J-160 - 1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1 J-160 - 1J-160L1 - 1 J-160L1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160 - 1J-160L1 PB1 - 1 J-160L1 PB1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160 - 1J-1601-2 - 1J-1601-2 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-162 - 1J-162 - 1J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - 1J-162L1 - 1 J-1621-1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - 1J-162L1 P81 - 1 J-162L1 P81 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - 1J-162PB1 - 1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - iJ-162PB2 - 1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1 J-164 - iJ-164 - 1J-164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164 - 1J-164L1 - 1J-1641-1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164 - 1J-1641_2-1J-164L2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164 - 1J-164L2PB1 - 1J-164L2PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1 J-166 - 1 J-166 - 1 J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk cG - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:32:27PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA4<ER ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-101-1-02 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-02_wp01 Offset TVD 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 1J Pad 1J-166-1J-166L1-1J-1661-1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - iJ-166L1 PB1 - 1J-166L1 PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1 J-166-1J-166L2 - 1 J-166L2 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166L2PB1 - 1J-166L2PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-168 - 1 J-168 - 1 J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 - 1J-168L1 - iJ-168L1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2 - 1J-1 681-2 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 - 1J-168L2PB1 - 1 J-1681-2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-1 70 - 1J-170 - 1 J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J-170-1J-170L1-1J-1701-1 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J-170 - 1J-1701-2 - 1J-1701_2 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170 - 1J-170PB1 - 1 J-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk iJ-170 - 1J-170PB2 - 1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 - Prelim: 1J- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1 J-104 (empty) - Prelim: 1J-1 04 L2 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1JA09PB1x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 Offset Site Error: 0.00 usft Survey Program: 201-MW0+IFR-AK-SCC 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 +NIS +El-W Hole Sae Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) lush) (usft) (m) (usft) (usft) (usft) 114.25 114.25 116.12 116.12 0.00 0.00 46.71 110.69 117.51 8.875 161.44 0.74 160.70 Pass - Major Risk, CC, ES, SF 197.92 197.92 200.00 199.98 0.05 0.05 46.87 111.45 118.89 8.875 163.01 1.83 161.18 Pass - Major Risk 297.75 297.75 300.00 299.90 0.15 0.17 47.31 113.30 122.46 8.875 167.03 3.41 163.63 Pass - Major Risk 397.01 397.00 400.00 399.80 0.27 0.28 47.93 115.05 126.60 8.875 171.49 4.97 166.52 Pass - Major Risk 493.34 493.32 500.00 499.54 0.38 0.40 49.14 117.62 133.26 8.875 179.64 6.53 173.12 Pass - Major Risk 587.98 587.87 600.00 598.96 0.49 0.53 51.31 120.27 143.56 8.875 192.72 8.10 184.64 Pass- Major Risk 677.68 677.31 700.00 697.93 0.60 0.67 53.92 123.90 157.36 8.875 212.30 9.64 202.72 Pass - Major Risk 752.37 751.30 900.00 796.49 0.69 0.81 57.67 124.33 174.25 8.875 238.69 10.99 227.80 Pass - Major Risk 836.40 833.59 900.00 894.76 0.82 0.95 61.01 127.00 192.55 8.875 273.85 12.51 261.59 Pass - Major Risk 921.90 916.44 1,000.00 992.43 0.95 1.12 63.78 132.65 213.20 8.875 316.43 14.15 302.78 Pass - Major Risk 1,002.62 994.25 1,100.00 1,088.93 1.08 1.34 66.04 141.43 237.88 8.875 365.16 15.84 350.18 Pass - Major Risk 1,072.17 1,060.68 1,200.00 1,183.97 1.21 1.59 67.68 153.99 266.27 8.875 420.60 17.51 404.45 Pass - Major Risk 1,128.96 1,114.17 1,300.00 1,276.57 1.32 1.90 68.70 171.29 299.72 8.875 484.87 19.14 467.71 Pass - Major Risk 1,186.86 1,168.03 1,400.00 1,365.40 1.45 2.28 69.33 193.00 340.12 8.875 557.89 21.02 539.71 Pass - Major Risk 1,236.53 1,213.77 1,500.00 1,451.11 1.57 2.72 69.75 218.16 385.04 8.875 636.46 22.91 617.42 Pass - Major Risk 1,280.95 1,254.20 1,600.00 1,533.47 1.68 3.22 70.28 245.70 434.57 8.875 719.64 24.83 699.84 Pass - Major Risk 1,316.75 1,286.41 1,700.00 1,611.71 1.76 3.77 70.68 275.94 488.99 8.875 807.16 2633 786.71 Pass - Major Risk 1,350.74 1,316.67 1,800.00 168635 1,86 4.37 70.91 308.71 546.89 8.875 897.66 28.75 876.61 Pass - Major Risk 1,377.15 1,339.96 1,900.00 1.756.58 1.93 5.02 71.00 343.98 608.70 8.875 990.96 30.74 969.42 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/10/2018 4:32:27PM Page 4 COMPASS 5000.14 Build 85D t t HE o FJo�� � � E 0 = o E 8 8 8 T3 � ¢zi¢_ o z z9Za19 �o zg N- N a i.� s �a u 0 r_ L_J 0 0 0 0 `o 0 9 V b rn n/ C a t+ •-. « -sn. N o El �I 0 0 o c o o- 0 w a o; O 2400 2700 3000 3300 3600 3900 4200 G 450C 480C C C S10C + 540C [{a C 570C v a Sooc 5300 5600 i90o 7200 1500 '800 m� N �-'t J M - M O O CL —Na cis 0r- a o s at QH(nM d O �- 19 Rcc a) M Cl! T (O - � m O W"00 a,00>aD c) -zt d' cO O M N c N '0 I� 1� O t0 N O) (O M ('T I' M N N N N O Z CD � ' JL'i a) o00 00 00 0 00 t� o 00 0 00 00 6 0 6 u'i 0 0 e7 0 6 0 L'Lo N O] N O N 7 r' ono 000000000 a� o 0 0 00 0 0 0 0 0 Q o i r- rr- ti ON O MOto K] tO OaYJ u.l' i '2 oin vtri Ill N } �' n a) o V coS O N V' 1 �. w 1- 2co O to i� ti c0 C M tc� Lo , to , «J �A to cn co J(6 I- (n N CO N O W co V O cO I- Q W co Ln ' MNOCO� tf)aO tO tot!) Z N 0 0 0 0 O> t0 f•J a V L 13 � } t-- tD M N CDN to to O O O) I S M N N N N O v _ I LU C n M 1 O to N O M O' M g Clime cO Lq n T M f-, to coO O) C C-0 at0 t0 a0 "�MI- t t o O O t O > c M M M N F 0 0 0 0 0 0 0 0 0 0 ` tb O c0 to [o t0 O <a tD fo t0 O o ZLo to t2 °.2!�2 U N N M 10 V 1- C `0) O O) t>7 n t0 to uc poo W Mm rn }0 p O o 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 CD i Lo o tti o tri �tri ari O N Cl N O I I z M'ct to MN tf>r-�-Mfg r .,zr C/) C1 ' p Z O U�NMCY ti'J (O 1�•aD O)O O vi n ty O ' � O w :o AZ ZO l'IOI- L----_- ----------- _--_-- "J a a 0 zoti z rlol n ----- ---------- - - _1 _1 _1 _1 _I _2 _2 _2 _2 - - - _2TnTj7n. -- ------ -2, zi to -� 2 a O -2. -21 .21 wi -21 0 N 31 3. o m J -33 o~ �a to 34 d -34 35 85 170 255 340 425 510 595 580 765 t50 )35 020 105 190 275 360 445 530 y 615 pop O 700 O� 0 785 370 3~ 0 )55 )40 -c� 25 !10 :95 80 65 50 35 20 05 90 75 60 45 30 15 )0 35 70 ConocoPs philli _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad 1 J-10 1J-10L1-03 Plan: 1J-10L1-03 wp01 Standard Planning Report 17 December, 2018 BAKER UGHES a GE company ConocoPhillips Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-10 Wellbore: 1 J-10L1-03 Design: 1J-101-1-03 wp01 ConocoPhillips BAI<ER Planning Report UGHES a GE company Local Co-ordinate Reference: Well 1 J-10 TVD Reference: Mean Sea Level MD Reference: 1J-10:114.25 @ 114.25usft (1 J-1 0: 114.25) North Reference: True Survey Calculation Method: 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 Site Kuparuk 1J Pad Site Position: Northing: 5,945.919.64 usft Latitude: 70° 15' 46.258 N From: Map Easting: 558,789.95 usft Longitude: 149' 31' 29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.45 ° Well 1J-10 Well Position +N/S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15' 45.169 N +El-W 0.00 usft Easting: 558,673.32 usft Longitude: 149' 31' 32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-101-1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) V) (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design lJ-101-1-03 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 12.150.00 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (1) V) (usft) (usft) (usft) (°/100usft) (°I100usft) (°/100usft) (1) Target 12,150.00 88.46 132.46 6,041.11 2,873.09 -5,945.19 0.00 0.00 0.00 0.00 12,250.00 94.52 128.96 6,038.51 2,807.93 -5,869.47 7.00 6.06 -3.50 330.00 12,500.00 83.25 115.55 6,043.40 2,675.00 -5,658.94 7.00 -4.51 -5.37 230.00 12,800.00 84.41 94.46 6,076.01 2,598.30 -5,372.49 7.00 0.39 -7.03 272.00 13,200.00 89.72 66.92 6,096.86 2,662.53 -4,982.26 7.00 1.33 -6.88 280.00 13,600.00 89.76 94.92 6,098.71 2,725.05 -4,591.20 7.00 0.01 7.00 90.00 13,850.00 91.27 77.48 6,096.45 2,741.54 -4,342.73 7.00 0.61 -6.97 275.00 14,100.00 92.71 94.93 6,087.70 2,758.02 -4,094.40 7.00 0.58 6.98 85.00 1211712018 10:45:29AM Page 2 . COMPASS 5000.14 Build 85D C®ta®c®Phillips BA (ER ConocoPhiiiips Planning Report BA a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk I Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellhore: 1J-10L1-03 Design: 1J-10L1-03 wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (a) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 12,150.00 88.46 132.46 6,041.11 2,873.09 -5,945.19 -5,945.19 0.00 0.00 5,948,634.47 552,706.49 TIP/KOP 12,200.00 91.49 130.71 6,041.13 2,839.91 -5,907.80 -5,907.80 7.00 -30.00 5,948,601.58 552,744.14 12,250.00 94.52 128.96 6,038.51 2,807.93 -5,869.47 -5,869.47 7.00 -30.00 5,948,569.90 552,782.71 Start 7 dls 12,300.00 92.26 126.28 6,035.56 2,777.47 -5,829.94 -5,829.94 7.00 -130.00 5,948,539.75 552,822.48 12.400.00 87.75 120.93 6,035.55 2,722.16 -5,746.70 -5,746.70 7.00 -130.16 5,948,485.10 552,906.13 12,500.00 83.25 115.55 6,043.40 2,675.00 -5,658.94 -5,658.94 7.00 -130.16 5,948,438.64 552,994.25 3 12,600.00 83.54 108.51 6,054.92 2,637.77 -5,566.91 -5,566.91 7.00 -88.00 5,948,402.13 553,086.56 12,700.00 83.93 101.48 6,065.84 2,612.08 -5,470.95 -5,470.95 7.00 -87.19 5,948,377.18 553,182.71 12,800.00 84.41 94.46 6,076.01 2,598.30 -5,372.49 -5,372.49 7.00 -86.42 5,948,364.18 553,281.26 4 12,900.00 85.67 87.54 6,084.66 2,596.57 -5,272.95 -5,272.95 7.00 -80.00 5,948,363.22 553,380.81 13,000.00 86.98 80.65 6,091.08 2,606.83 -5,173.74 -5,173.74 7.00 -79.40 5,948,374.25 553,479.92 13,100.00 88.34 73.78 6,095.17 2,628.93 -5,076.36 -5,076.36 7.00 -78.96 5,948,397A0 553,577.11 13,200.00 89.72 66.92 6,096.86 2,662.53 -4,982.26 -4,982.26 7.00 -78.68 5,948,431.44 553,670.94 5 13,300.00 89.73 73.92 6,097.34 2,696.03 -4,888.10 -4,888.10 7.00 90.00 5,948,465.66 553,764.83 13,400.00 89.73 80.92 6,097.81 2,717.80 -4,790.57 -4,790.57 7.00 89.97 5,948,488.19 553,862.18 13,500.00 89.74 87.92 6,098.27 2,727.52 -4,691.11 -4,691.11 7,00 89.93 5,948,498.68 553,961.56 13,600.00 89.76 94.92 6,098.71 2,725.05 -4,591.20 -4,591.20 7.00 89.90 5,948,496.99 554,061.47 5 13,700.00 90.37 87.94 6,098.60 2,722.55 4.491.29 -4,491.29 7.00 -85.00 5,948,495.27 554,161.38 13,800.00 90.97 80.97 6,097.43 2,732.20 -4,391.83 -4,391.83 7.00 -85.01 5,948,505.70 554,260.76 13,850.00 91.27 77.48 6,096.45 2,741.54 -4,342.73 -4,342.73 7.00 -85.09 5,948,515.42 554,309.78 7 13,900.00 91.57 80.97 6,095.21 2,750.89 -4,293.63 -4,293.63 7.00 85.00 5,948,525.15 554,358.80 14,000.00 92.16 87.95 6,091.95 2,760.53 -4,194.21 -4,194.21 7.00 85.09 5,948,535.56 554,458.13 14,100.00 92.71 94.93 6,087.70 2,758.02 -4,094.40 -4,094.40 7.00 85.31 5,948,533.83 554,557.95 Planned TD at 14100.00 -asing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,100.00 6,087.70 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 12,150.00 6,041.11 2,873.09 -5,945.19 TIP/KOP 12,250.00 6,038.51 2,807.93 -5,869.47 Start 7 dls 12,500.00 6,043.40 2,675.00 -5,658.94 3 12,800.00 6,076.01 2,598.30 -5,372.49 4 13,200.00 6,096.86 2,662.53 -4,982.26 5 13,600.00 6,098.71 2,725.05 -4,591.20 6 13,850.00 6,096.45 2,741.54 -4,342.73 7 14,100.00 6,087.70 2,758.02 -4,094.40 Planned TD at 14100.00 12/17/2018 10:45:29AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1J Pad lJ®10 UL;-f: IJ-IOLI-03—wpOl 10 December, 2018 BER TGH0 ES GE company s� ConocoPhillips BAT ConocoPhillips Travelling Cylinder Report UGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Well bore 1J-10L1-03 Reference Design: 1J-10L1-03_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1J-10 1J-10:114.25 @ 114.25usft (1J-10:114.25) 1J-10:114.25 @ 114.25usft (lJ-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1J-10L1-03_wp01 =ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,598.58 usft Error Surface: Pedal Curve Survey Tool Program Date 12/10/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J-10(1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,420.00 1J-10L1_wp01 (1J-10L1) MWD MWD- Standard 10,420.00 12,150.00 1J-10L1-01_wp01 (1J-101-1-01) MWD MWD- Standard 12,150.00 14,100.00 1J-101-1-03_wp01 (lJ-10L1-03) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9 5/8" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 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 1E Pad 1E-35- Plan 1E-35A-1E-35A(wp02) 14,100.00 12,900.00 1,404.59 311.20 1,124.72 Pass - Major Risk Kuparuk I Pad 1 J-03 - 1J-03 - 1J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J-03 - 1J-03L1 - 1J-03L1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03 - 1J-03L2 - 1 J-031_2 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03 - 1J-03L2PB1 - 1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-09 - 11-09 - 1J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1 J-09 - 1J-09A - 1 J-09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1 J-09 - iJ-09AL1 - 1 J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-10 - 11-10 - 1J-10 10,488.86 10,500.00 29.34 13.60 20.73 Pass - Major Risk 1J-10 - 1J-10L1 - 1J-10L1_wp01 Out of range 1J-10-1J-1011-01-1J-10L1-01_wp02 11,100.00 11,100.00 0.00 2.65 -0.45 FAIL - Minor 1/10 1J-10 - 1J-1 OLl-02 - 1 J-1 0L1-02_wp01 12,470.52 12,500.00 106.97 2.12 104.89 Pass - Minor 1/10 1 J-105 - 1 J-105 - 1 J-105 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105 - 1J-105L1 - 1 J-1051-1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105L2 - 1 J-1051_2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105PB1-iJ-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1 J-107 - 1 J-107 - 1 J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107 - 1 J-107L1 - 1 J-1071_1 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 11-109 - 1J-109 - 1 J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-1 09 - 1J-1 09PB1 - 1J-1 09PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1 J-115 - 1 J-115 - 1 J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1 J-115 - 1 J-115L1 - 1 J-115L1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - iJ-115L1 PB1 - 1J-11511 PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115L1 PB2 - 1J-115L1 PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1211012018 4:38:58PM Page 2 COMPASS 5000.14 Build 85D - ConocoPhillips BAITER Conoc6Philfips Travelling Cylinder Report UGHES a GEmmpany Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: iJ-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: iJ-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-10L1-03 Database: EDT 14 Alaska Production Reference Design: 1J-101_1-03_wp01 Offset TVD 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 1J Pad iJ-115 - 1J-115L2 - 1 J-115L2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115L2PB1 - 1J-115L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 -1 J-115L2PB2 - 1J-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB1 - 1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk iJ-115-1J-115PB2 - 1 J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115P133 - 1 J-115P133 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1J-115PB4 - 1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1 J-118 -1 J-118 - 1 J-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 -1 J-1181_1 - 1 J-1181_1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - 1J-1181_2 - 1 J-1181_2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118 - iJ-118PB1 - 1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass- Major Risk 1J-118 -1 J-118PB2 - 1J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-120 -1 J-120 - 1 J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-1201-1-1J-1201-1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-120L1 PB1 - 1 J-1201-1 P131 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L1 PB2 - 1 J-120Ll PB2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 -1 J-120L1 13133 - 1J-120L1 P133 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-1201_1 PB4 - 1J-12OLl P134 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - 1J-1201-2 - 1 J-1201-2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-1201-213131-1J-120L2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1 J-152 -1 J-152 - 1 J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-1521-1 - 1 J-1521-1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-1521-2 - 1J-1521_2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-iJ-1521-213131-1J-152L2P61 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB1-1J-152PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152 - 1J-152PB2 - 1J-152P62 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-154 - iJ-154 - 1 J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154 - 1J-154L1 - 1J-1541-1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1 J-154 -1 J-1541-2 - 1 J-1541_2 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-156-1J-156 - 1 J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156-1J-1561-1-1J-156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156 - 1J-1561-1 P131 - 1J-1561-1 P131 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-156 - iJ-156L2 - 1 J-1561_2 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1 J-158 -1 J-158 - 1 J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-158-1J-1581-1-1J-158L1 392,81 400.00 60.36 6.31 54.05 Pass - Major Risk 1 J-159 -1 J-159 - 1 J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - 1J-1591-1 - 1 J-1591-1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159 - iJ-1591-1 P131 - 1J-159L1 PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L1 P132 - 1 J-1591-1 P132 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159L2 - 1J-1.59L2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-15913131-1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-160 - iJ-160 - 1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160 - iJ-160L1 - 1 J-160L1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160 -1 J-1601-1 PB1 - 1 J-160LI P131 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-160L2 - 1J-1601-2 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-162-1J-162 - iJ-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - iJ-162L1 - 1J-1621-1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk iJ-162 - iJ-162L1 PBi - 1J-162L1 1381 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB1-1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB2 - 1 J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1 J-164 -1 J-164 - 1 J-164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164-1J-164L1 - 1 J-1641-1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1 J-164 - 1 J-164L2 - 1 J-1641_2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/10/2018 4:38:58PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BAT ConocoPhillips Travelling Cylinder Report IGHES a GE company Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (lJ-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1 J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1 J-10L1-03 Database: EDT 14 Alaska Production Reference Design: 1J-101-1-03_w1001 Offset TVD 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 1J Pad 1J-164-1J-164L2PB1 - 1J-1641_2PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1 J-166 - 1 J-166 - 1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - 1J-166L1 - 1J-1661-1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166L1 PB1 - 1J-1661_1 PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - 1J-16612 - 1J-166L2 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166 - 1J-166L2PI31 - 1J-166L2PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-168 - 1J-168 - 1J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-1681-1-1J-1681_1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 - 1J-1681-2 - 1 J-1681-2 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1 J-170 - 1J-170 - 1 J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J-170-1J-170L1 - 1J-170L1 5.566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J-170-iJ-1701-2-1J-1701_2 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170-1J-170PB1-1J-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk 1J-170 - 1J-170PB2 - 1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1 J-104 - Prelim: 1 J- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1 J-104 (empty) - Prelim: 1 J-104 L1 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 L2 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB1x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 E Pad - 1 E-35 - Plan 1 E-35A - 1 E-35A (wp02) Offset Site Error: 0.00 usft Survey Program: 199-GYD-CT-CMS, 6963-MWD Rule Assigned: Major Risk Offset Well Error. 0.00 usft Reference Onset 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 +NIS +Er-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) lush) (°) (usft) (usft) (in) (usft) (usft) (usft) 14,050.00 6,204.19 12,700.00 5,530.87 47.35 95.62 26.57 4,189.59 -4,119.88 7.750 1,578.47 290.32 1,310.12 Pass - Major Risk 14,074.47 6,203.12 12,800.00 5,557.65 47.51 97.09 28.71 4,104.46 -4,074.77 7.750 1,490.99 300.58 1,217.02 Pass - Major Risk 14,100.00 6,201.95 12,900.00 5,584.43 47.68 98.57 30.95 4,019.32 -4,029.66 7.750 1,404.59 311.20 1,124.72 Pass - Major Risk, CC, ES, SF CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/10/2018 4:38:58PM Page 4 COMPASS 5000.14 Build 85D r yHy,7 C 0 O O o -0 J � O � J � 0m d � o W m 2� m o ca cF m m J w °- z� Nmam ~z 1G'to- 3m �0 E M C � M a J >a o or 2' j m`moo� n m a 0 00 o_ "o a 0 om F a �= o o At- F O F 0 a --- F of v O 'N O m1 0 0' 0 o o �+ - a o; O O O O O O O O O O O O O O O O III/USn OQE) (+)u:poN/(-)ulnoS �400 2700 3000 3300 3600 3900 1200 L me V 180C C ❑OC + ;40C a 70C V d. 00C 0 300 600 900 200 500 800 a � N m, c i c y M rn 0 0 0 v m lo a a m O o Y a c d- m c CL V V 0)1 R OCD O CJO � N �O) Cl! Nr•ct [n �(J O)00 NN�NC' O CO c D M m M O to t ;J to u� V V -o Z o 0 0 0 0 0 0 0 0 ' J U O p 0 0 0 0 0 0 LL 0 0 0 C V O O p LL j ~ CM+)NNNONM � Ln 0 o ti G]Op000000 p o n r. � r- r• � r- rrnmOMo .- O N N 1- V' L1J 4') O oo N N N V + �t o � �rn T J N M CO ti W O) M Cl O M u V C-4 Q W O Ol O Man 0 Z 0 ZM r•NaO W Lo +o a lo —coD stir- N N N N N N N N Jcl).-.-o r-cD c-i0o W ���nvoml�vr- m2 co L 07 ]vM� r. a�rnrnao f- p O O p 0 0 0 0 o oo Z LO. N to Co C D N N a D M 0) O) -3: O) LO LO N W2 V O r• Ct V (D NCD c-C14 r•� C a 0 N r• r• O O o0 -�tM oOo aOD O)N W p m O 1+ 0 000 00000 0 0 0 0 oocS00000 Ct) 0 0 0 0 0 N u'J c0 Nw W N N N N c 2 M M V' Z O 0 o - 0 O 0 " av m 4 c a _q -... r 4 -4 b 4 -4 4' -4� ...., v, -4i zUIFIV-Ll -IL -5( -51 -5: o -d -5: -56 10i £0-I 01-f l -_------- ---------_ .- .57 a -58 a0 N -59 -60 -61 -62 63 o -64i .651 -661 _ a 671 O -68( -69( o -70( J -71( 72C -73C 00 0 b of v� 00 0 W of v1 0 a v� 0 0 0 O O N b b b 0 OM b 0 'OV O b b 0 b �o zoo 300 400 500 500 700 300 )OO )00 00 00 00 00 00 00 00 00 DO >~ DO Do O )0 CD )o C` )o 0 U )0 CA IO U .: )0 10 10 0 0 0 0 0 0 0 D D D ) ! } § CL � &a »0 0 E 0 / KUP PROD 1J-10 conoCONhimPS ribs Well Attributes Max Angle & MD TD r lasi<a, I(1G J6.) Weell t Field Name Well6ore Status 500292301000 KUPARUK RIVER UNIT PROD ncl (") MD (RKB) Act 67.58 3,101.64 Btm (ftK6) 10,845.0 •• •I Comment H25 (ppm) Date SSSV:NIPPLE 40 9/10/2016 Annotation End Date Last WO: 2/8/2008 KB-Grd (ft) Rig Release Date 35.74 5/24/2001 1J-1 o, 3,SUM710:46:16 AM VerBral schematic (aclua8 Annotation Depth (kK8) End Date Annotation Last Mod By End Date Last Tag: IRKS 3/27/2017 Rev Reason: TAG, GLV C/O, H2S ppr0ven 1 3/3112017 HANGER; 29.6 Casing tangs Casing Description OD (in) ID (In) Tap (kKB) Set Depth (ftKB) Set Depth (TVO)... WVLen (I... Grade Top Thread CONDUCTOR 20 19.124 35.0 120.0 120.0 91.50 FI-40 WELDED Casing Description OD (in) ID (in) Top (RKB) Set Depth (kKB) Set Depth (TVD)... WOLen (I... Grade Top Thread ...... ....... .... ................ .............. .__.. ... ....... SURFACE 9 5/8 8.835 34.5 6.945.3 3,995.4 40.00 L-80 BTC Casing Description OD (in) ID (in) Top (RKB) Set Depth (kKB) Set Depth (TVD)... WtfLen (I... Grade Top Thread PRODUCTION 7 6.276 31.7 10,230.8 5,944.4 26.00 L-80 BTC-MOD Casing Description OD (in) ID (in) Top (RKB) Set Depth (kKB) Set Depth IWO)— WVLen (L.. Grade Top Thread 7LINER 41/2 3.958 9,967.2 10,843.0 6,324.7 12.60 L-80 NSCT LinerDetails CONDUCTOR; 35.0-120. Top (RKB) Top (TVD) (RKB) I Top Inc[ (°) It.. Des Com Nominal ID (in) 9,967.2 5,787.0 53.74 TIE BACK BAKER PACKER & TIE -BACK SLEEVE 4.438 9,985.2 5,797.6 53.67 PACKER BAKER ZXP LINER TOP PACKER 4.438 NIPPLE; 508.0 9,989.2 5,800.0 53.66 HANGER BAKER LINER HANGER 4.500 10.327.7 6,001.7 53.86 NIPPLE CAMCO'D'NIPPLE- DRILLED OUT TO 3.87" 3.830 DURING ATTEMPT TO PULL FISH 2/8/2008 WORKOVER 10,520.7 6,118.5 51.81 NIPPLE OTIS'XN' NIPPLE W/ No Go, 3.812" PKG BORE, 3.725 GAS LIFT; 3,7238 3.725" profile Tubing Strings Tubing Description String Ma.,. ID (in) Top (RKB) Set Dep[h (ft.. Set Depth (TVD) (... Wt 0b/ft) Grade Top Connection TUBING 41/2 3.958 29.6 9,991.7 5,801.5 12.60 L-80 IBT GAS LIFT; 6,311.7 Completion Details Top IRKS) Top (TVD) (ftKB) Top Incl (") Item Des Co. Nominal ID (in) 29.6 29.6 0.01 HANGER FMC GEN V TUBING HANGER 4.500 508.0 508.0 1.97 NIPPLE CAMCO DB-6 NIPPLE W/ 3.875 TOP NO GO PROFILE 3.875 9,933.4 5,767.0 53.86 NIPPLE CAMCO DB NIPPLE w/ 3.812 PROFILE- DRILLED OUT 3.830 TO 3.87 DURING ATTEMPT TO PULL FISH 2/8/2008 WORKOVER SURFACE; 34.56,945.3- 9,978-7 5,793.8 53.70 LOCATOR BAKER GBH-22 LOCATOR 3.958 9,979.91 5,794.5 53.69 1 SEAL ASSY I BAKER SEAL ASSEMBLY W MULESHOE 3.958 GAS LIFT; 8,068.2 Other In Bole (Wilre►ine retrievable plugs, valves, pumps, fish, etc..) - Top(TVD) Top Intl Top(ftKB) (ftK6) (°) Des Com Run Date ID(in) 10,400.0 6,044.8 52.94 FISH PERF GUN PERF GUN DROPPED 7/24/01, TOP 3/17l2008 10,532', LENGTH 34.4% MAX OD 3.63"; WORKED TO RETRIEVE THRU 8129/01. WELL SHUT IN & GAS LIFT; 9.132 6-1 FREEZE PROTECTED. 36" BAT SUB LEFT ON TOP OF E-LINE TOOL 10/25/2004: Fish Pulled up tol 0,312'CTMD 617/2005: Tagged Fish @ 10339' RKB 1/19/2008 Tagged Fish @ 10301' SLM 2/8/2008 WORKOVER TO PULL FISH - ONLY GAS LIFT; 9,862.2 PUSHED IT DOWNHOLE FROM 10312' TO 10400' Perforations & Slots Shot Den NIPPLE;9,933.4 Top (RKB) St. (RKB) Top(TVD) (RKB) St. (TVD) (RKB) Zone (shotsif Date U Type Com 10,446.0 10,466.0 6.072.7 6,084.9 C-3, 1J-10 7/19/2001 6.0 APERF 3 3/8" PSD PJ chgs, 60 deg ph 10,658.0 10,678.0 6,205.0 6,217.8 A-5, 1 J-10 6/12/2001 6.0 IPERF 2.5" HSD BH & DP Stimulations & Treatments Proppant Designed lb) Proppant In Formation (Ib) Date LOCATOR; 9,978.7 6/16(2001 Stimulations,& Treatments SEAL ASSY; 9,979.9 Vol Clean Pump Ste # Top (RKB) Btm (kKB) Oate Stim/Treat Fluid (bbl) Vol Slurry (bb0 1 10,658.0 10,678.0 6/16/2001 Mandrel Inserts St ati N Top (RKB) Top (TVD) (RKB) Make Model OD (in) Se, Valve Type Latch Type PortSize (in) TRO Run (psi) Run Date Com 1 3,723.8 2,558.4 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,149.0 3/29/2017 4:30 PRODUCTION; 31.7-10,230.8 2 6,311.7 3,723.0 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/29/2017 7:30 3 8,068.2 4,627.0 CAMCO KBG-2 1 GAS LIFT DMY SK 0.000 0.0 3/29/2017 5:00 4 9,132.E 5,283.0 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 112""' 4:15 5 9,882.2 5,736.8 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 D.0 2!9/2014 7:00 Notes. General & Safety End Date Annotation 2/8/2008 NOTE: WORKOVER DONE TO PULL FISH, MILLED NIPPLES; UNSUCCESSFUL, PUSHED FISH FISH; 10.400.0 DOWNHOLE 9/29/2010 NOTE: View Schematic w/Alaska Schematic9.0 APFRF; 10.446.0-10.466 0 IPERF; 10.658.0-10,678.0 FRAC; 10,658.0A LINER; 9,967.2-10,843.0 r: U t7 E d C U cn U m N 0 Q 0 d O p 0 �i O Ud o�d p � 0 �N m o h `o a pa Diu ono < $O� O OQ C J � J o0 as C E r- m ai U 0 N n M ,� cL D) (•i a y rn m — N C ii O m @ m _ d n M U) Of ! `t ci a � 01 U Op� Y 0 CN N y Qom' O E a � J m d G Cli W W_ C (a N �. ttl a N d y p, Q CDto C j. N m FO- m N~ Cf F. m U U () N °� C m N J= m O. a .Oa. a1 3 O a0 d E E m `�' a L) (L d) ? p a N y J V o rn at C j m U m U (D m X C vcnaN -, 0 (V (V N Y Y Y Y Y E = y Cl N co �r V' V al a7 m ai m mLOmmm a1 U N LL O O Z C t 3 n M J ci Q1N C] p p `N� O I,• .00 -gip (3 q o b o0 co cG pp (O ppO�� y � V O co Gc y coJ coO O m n N m y m 0 Y L 00 N�"' Cal m N CO -Ity 7 /a\ n V ca ¢ O 2 to p aV U o Ci N O N_ N V From: McLaughlin Ryan To: der, David L (DOA) Cc: Loepo, Victoria T (DOA) Subject: RE: [EXTERNAL] Digital Survey Files for Four 13-10 Laterals Date: Thursday, January 31, 2019 4:48:46 PM Hello Dave, Here is the corrected government section data: KRU 1J-101-1: Top of Productive Interval: 4931' FNL, 4064' FEL, Sec 27, T11N, R10E, UM Total .Depth: 4871' FNL, 4211' FEL, Sec 27, T11N, R10E, UM KRU 1J-101-1-01: Top of Productive Interval: 4896' FNL, 4149' FEL, Sec 27, T11N, R10E, UM Total Depth: 1946' FNL, 600' FEL, Sec 34, T11N, R10E, UM KRU 1J-101-1-02: Top of Productive Interval: 523' FNL, 3098' FEL, Sec 34, T11N, R10E, UM Total Depth: 2911' FNL, 2931' FEL, Sec 34, T11N, R10E, UM KRU 1J-10L1-03: Top of Productive Interval: 412' FNL, 3198' FEL, Sec 34, T11N, R10E, UM Total Depth: 526' FNL, 1348' FEL, Sec 34, T11N, R10E, UM Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office:907-26S-6218 Cell:907-444-7886 700 G St, ATO 670, Anchorage, AK 99S01 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Thursday, January 31, 2019 4:08 PM To: McLaughlin, Ryan <Ryan.McLaughlin @conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals Ryan, In looking through the PTD's, I noticed that all four have the same Top of Productive Horizon and Total Depth in the legal description in Part 4A on Form 10-401. Please send over the corrected government section data, and I will make the adjustments on the forms. I assume that the legal description is correct for the first lateral: KRU 1J-10L1 but not for the -01, -02, and -03 laterals? Thank you, Dave Boyer AOGCC From: McLaughlin, Ryan <Ryan.McLaughlin _conocophillips.com> Sent: Thursday, January 31, 2019 11:53 AM To: Boyer, David L (DOA) <david.boyer2Palaska.gov> Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals Hello Dave, I've attached .txt files for the 1J-10 laterals. Your assumption about our drill order is correct, we are currently planning on drilling 1J-10 before 3M-26. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office:907-265-6218 Cell:907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Boyer, David L (DOA) <david.boyer2Palaska.gov> Sent: Thursday, January 31, 2019 10:13 AM To: McLaughlin, Ryan <Ryan.McLaughlinPconoco hilli sp_com> Subject: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals Hi Ryan, I just began reviewing the 4 PTD's for the KRU 1J-10 laterals today. Can you please e-mail over digital surveys for the four laterals in Excel or ASCII format so we can load them into Geographics Wellbase program? Also, it would save splicing time if the survey files also include those from the original mother -bore above the—10,310' KOP's. We also received two PTD's applications from Keith Herring for 2 KRU 3-26 laterals also to be drilled with CDR3-AC rig with the same 02/13/19 spud date.. We are assuming your 1J-10 laterals will be drilled first since the PTD files arrived several days earlier? Thank you, Dave Boyer Senior Geologist AOGCC TRANSMITTAL LETTER CHECKLIST WELL NAME: KRU�— I TT 1 I C) L. 1- oq PTD: �, 19 - 013 Development Service Exploratory Stratigraphic Test Non -Conventional FIELD: KIT �u� 1 Ver' POOL: wuparak P, j ve ,�- O l 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. API No. 50-0 Zq - -j, 3 D 1 O - DO- Off. (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 on permit). 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 V/ (Company Name) inthe attached application, the following well logs are also required for this well: Well Logging Requirements V 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 ---------Well Name: KUPARUK RIV UNIT 1J-10L1-01 —_-Program DEV Well bore seg �/❑ PTD#: 2190130 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes I3 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 No Plat not included. Directional plan and cross-section viewes were 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 DLB 2/4/2019 13 Can permit be approved before 15-day wait Yes 14 Well located within area andstrataauthorized by Injection Order # (put_ 10# in comments) (For NA 15 All wells within 1/4_mil_e 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 _for -KRU 1J-10_ Engineering 19 Surface casing protects all known USDWs N-A Surface casing set in KRU 1J-10 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 uncemented 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 126 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures I27 If_diverter required, does it meet_ regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 2914 psig(9.2 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD VTL 2/5/2019 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is2315 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 33 Is presence of 112S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) - - NA i35 Permit can be issued w/o hydrogen_ sulfide measures No Wells on 1J-Pad are H2S-bearing. 112S measures required. - Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA DLB 2/4/2019 138 Seabed condition survey (if off -shore) NA I39 Contact name/phone for weekly progress reports_ [exploratory onlyl NA Geologic Engineering Public Commissioner: Date: Commissioner. -Date Commissioner Date 2-C �7
