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Home My WebLink About217-024Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, March 29, 2019 1:33 PM To: Eller, J Gary Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA) Subject: KRU 3E-201_1, 1-1-01, 1-1-02, 1-1-03, PTDs 217-022, 217-023, 217-024, 217-025: Expired Hello Gary, The following Permits to Drill, issued to ConocoPhillips Alaska, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. • KRU 3E-20 L1, PTD 217-022, Issued 14 March 2017 • KRU 3E-20 1-1-01, PTD 217-023, Issued 14 March 2017 • KRU 3E-20 1-1-02, PTD 217-024, Issued 14 March 2017 • KRU 3E-20 1-1-03, PTD 217-025, Issued 14 March 2017 If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. THE STATE F, ME I wra GOVERNOR BILL WALKER G. Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 E-20L 1-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-024 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Surface Location: 4869' FNL, 224' FEL, SEC. 16, Tl 1N, R10E, UM Bottomhole Location: 910' FNL, 1119' FEL, SEC. 22, T11N, RIDE, UM Dear Mr. Eller: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 183-005, API No. 50-029- 20895-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this _Oday of March, 2017. STATE OF ALASKA ALA' OIL AND GAS CONSERVATION COMMIS, N RECEIVED FEB 21 2017 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral . ❑✓ Stratigraphic Test ❑ Development - Oil 0 % Service - Winj ❑ Single Zone 0 ' Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ • Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 - KRU 1E-201-1-02 0 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11300' TVD: 6187' Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 4869' FNL, 224' FEL, Sec 16, T11 N, R10E, UM 7. Property Designation (Lease Number): ADL 25651 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3730' FNL, 1183' FEL, Sec 15, T11 N, R10E, UM ALK 469 3/6/2017 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 910' FNL, 11 19'FEL, Sec 22, T11 N, R10E, UM 2560 17280' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 106' . 15. Distance to Nearest Well Open Surface: x- 550300 y- 5960000 Zone- 4 GL Elevation above MSL (ft): 67' Ito Same Pool: 306, 1E-03 16. Deviated wells: Kickoff depth: 8725' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103 degrees . Downhole: 3034 - Surface: 2412 ` 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" 4.6# L-80 ST-L 3283' 8017' 6262' 11300' 6187' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8650' 6756' N/A 8538' 6668' 7980' Casing Length Size Cement Volume MD TVD Conductor 76' 16" 290 sx AS II 110, 110, Surface 2347' 10-3/4" 1300 sx AS III & 235 sx AS 1 2380' 2172' Production 8591' 7" 1050 sx Class G 8622' 6734' Perforation Depth MD (ft): 7945' - 8094', 8349' - 8362', Perforation Depth TVD (ft): 6210' - 6325', 652V - 6532', 8382' - 8410' 6547' - 6569' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ ❑✓ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 0 C 25.050 requirements04 21. Verbal Approval: Commission Representative: 2/16/2017 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Keith Herring @ 263-4321 be deviated from without prior written approval. Contact Email Keith. E.Herrinq(@cop.com Printed Name G. Eller Title CTD Team Lead Signature Phone 263-4172 Date Z 2� Commission Use Only Permit to Drill API Number: Number: p2 —Q p2 50-� —a,O S— 6 — Q (7 Permit Approval Date: (� 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 meth an , gas hydrates, or gas contained in shales: 56 Other: 36 Q f-YS f � 3 ,Jr—G O 1,05 � Samples req'd: Yes � No []� Mud log req'd: Yes ❑ No /tr1 rl v�G ✓ p �—� ✓'( 1-y J��/ fs f � 2 S Ij-k�. asures: Yes No❑ Directional svy req'd: Yes [� No El tl q r/ Gr Yt G t t0 Z 0 A i-Lf 75- , b/ SCb )Spacing excep7ion req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No 6 G r a !may Cd �v a J J O w f 17 e k 1 GJk o f2 ' � 1 f ",t0 b -C Post initial injection MIT req'd: Yes ❑ No M Q k-1 t p n i ✓z cl Ion 9 1�Lt C y r C Vl cE Y�i J- / APPROVED BY Approved by:C4 COMMISSIONER THE COMMISSION Date:5 k[f3tlsN Submit Form and Form 10-401 (Revised 11/2015) O Lonths from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ConocoPh i l l i s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 16, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVE® FEB 21 2017 AOGCC ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad -lateral out of the KRU 1 E-20 (PTD# 183-005) using the coiled tubing drilling rig, Nabors CDR3-AC. The scope of the window exit for KRU 1 E-20 has been modified from a cement pilot -hole casing exit to utilizing a 3-1/2" x 7" high expansion wedge exit. For this reason, please cancel the previously issued sundry (316-630). 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. The CTD objective will be to drill four laterals (1E-201-1, 1E-201-1-01, 1E-201-1-02, & 1E-20L1-03), targeting the Kuparuk C-sand intervals. The work is scheduled to begin March 2017. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 1E-201-1, 1E-20L1-01, 1E-20L1-02 & 1E-20L1-03 — Detailed Summary of Operations — Directional Plans for 1E-201-1, 1E-201-1-01, 1E-201-1-02 & 1E-201-1-03 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals NABOBS SKA 1 E-20L11 1 E-201-1-015 1 E-201-1-02 & 1 E-20L1-03 CM, Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o 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.................................................................................................................................... 7 Attachment 1: Directional Plans for 1E-20L1, 1E-201-1-01, 1E-201-1-02 & 1E-20L1-03..................................................7 Attachment 2: Current Well Schematic for 1 E-20............................................................................................................7 Attachment 3: Proposed Well Schematic for 1 E-20L1, 1 E-20L1-01, 1 E-20L1-02 & 1 E-20L1-03....................................7 Page 1 of 7 February 16, 2016 PTD Application: 1E-201-1, 1E-201_1-01, 1E-201_1-02 & 1E-201_1-03 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1E-201-1, 1E-201-1-01, 1E-201-1-02 & 1E-201-1-03. All laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1E-201-1, 1E-201-1-01, 1E-201-1-02 & 1E-201-1-03. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,034 psi in 1 D-03 (i.e. 9.4 ppg EMW), the maximum potential surface pressure in 1 E-20, assuming a gas gradient of 0.1 psi/ft, would be 2,412 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 1 E-20 was measured to be 2,728 psi (8.4 ppg EMW) on 7/4/2016. The maximum downhole pressure in the 1 E-20 vicinity is to the west in the 1 D-03 injector at 3,034 psi (9.4 ppg EMW) from March of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 1 E pad have injected gas, so there is a chance of encountering free gas while drilling the 1 E-20 laterals. If significant 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 1 E-20 laterals will be losses to the formation. Managed pressure drilling (MPD) target pressure will be reduced in order to manage losses to the formation. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 E-20 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 7 February 16, 2016 PTD Application: 1 E-201-1, 1 E-201_1-01, 1 E-201_1-02 & 1 E-201_1-03 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 1E-20L1 9350' 11300' 6079' 6094' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1E-20L1-01 8725' 11300' 6188' 6037' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1E-20L1-02 8017' 11300' 6156' 6081' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1E-20L1-03 7785' 11300' 5980' 6148' 2-3/8", 4.7#, L-80, ST-L slotted liner; up into 3-1/2" tubing Existing Casing/Liner Information Category OD Weight (ppo Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 65.0 H-40 Welded 34' 110, 34' 110, 1640 670 Surface 10-3/4" 45.5 K-55 BTC 33' 2380' 33' 2172' 3580 2090 Production 7" 26.0 K-55 BTC 31' 8622' 31' 6734' 4980 4320 Tubing 3-1/2" 9.3 J-55 BTC-MOD 28' 7807' 28' 6103' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg),IThis mud weight will hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 8.6 ppg FloVis completion fluid to provide formation over -balance and wellbore stability while running completions. If higher than expected pressure is encountered while drilling the laterals, then an overbalanced completion fluid will be utilized to provide formation over -balance. The last lateral will be displaced to a 10.0 ppg NaCl completion fluid to allow a swell packer to be run into this hole section. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled 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 E-20 laterals we will target a constant BHP of 8.6 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 Page 3 of 7 February 16, 2016 PTD Application: 1E-20L1, 1E-201_1-01, 1E-201_1-02 & 1E-201_1-03 increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1 E-20 Window (7967' MD, 6227' TVD) Using MPD Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure (8.4 pp) 2728 psi 2728psi' Mud Hydrostatic (8.6 pp) 2784 psi 2784 psi Annular friction (i.e. ECD, 0.08 psi/ft) 637 psi 0 psi Mud + ECD Combined (no choke pressure) 3421 psi (overbalanced —693psi) 2784 psi (overbalanced —56psi) Target BHP at Window (8.6 ) 2784 psi 2784 psi Choke Pressure Required to Maintain Target BHP 0 psi 0 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AA 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AA 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA 25.005(c)(13)) Summary of Operations Background Well KRU 1E-20 is a Kuparuk A -sand and C-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the C sands to the south of the 1E-20. The laterals will add new resources and improve existing recovery. A mechanical whip -stock will be set inside the 7" production casing at the planned kick off point of 7967' NID. The 1E-20L1 lateral will exit the 7" production casing at 7967' N1) and TD at 11300' NID, targeting the C sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 9350' NID with an aluminum billet for kicking off the 1E-20L1-01 lateral. The 1E-20L1-01 lateral will drill to the south to TD at 11300' NID targeting the C sand. It will be completed with 2-3/8" slotted liner from TD up to 8725' NID with an aluminum billet for kicking off the 1 E-20L 1-02 lateral. The 1E-20L1-02 lateral will drill to the south to TD at 11300' N1) targeting the C sand. It will be completed with 2-3/8" slotted liner from TD up to 8017' NID with an aluminum billet for kicking off the 1 E-20L1-03 lateral. Page 4 of 7 February 16, 2016 PTD Application: 1E-20L1, 1E-20L1-01, 1E-201_1-02 & 1E-201_1-03 The 1E-20L1-03 lateral will drill to the south to TD at 11300' MD targeting the C sand. It will be completed with 2-3/8" slotted liner from TD up to 7785' MD. The liner will include a swell packer, blank 2-3/8" liner, and a sealbore deployment sleeve to allow for future isolation of the 1E-20 motherbore, but it is not proposed at this time. Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-Line: Mill out "D" nipple to 2.80" ID. 3. Prep site for Nabors CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 1E-20L1 Lateral (C sand - south) a. Set top of whipstock at 7967' MD. b. Mill 2.80" window at 7967' MD. c. Drill 3" bi-center lateral to TD of 11300' MD. d. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9350' MD. 1 E-20L 1 -0 1 Lateral (C sand - south) a. Kickoff of the aluminum billet at 9350' MD. b. Drill 3" bi-center lateral to TD of 11300' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8725' MD.. 1E-20L1-02 Lateral (C sand - south) a. Kick off of the aluminum billet at 8725' MD. b. Drill 3" bi-center lateral to TD of 11300' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8017' MD. 1E-20L1-03 Lateral (C sand - south) a. Kickoff of the aluminum billet at 8017' MD. b. Drill 3" bi-center lateral to TD of 11300' MD. c. Run 2-3/8" slotted liner from TD up to 7785' MD. Liner will include a swell packer, blank 2- 3/8" liner, and a sealbore deployment sleeve. 6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Pull BPV. 2. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Page 5 of 7 February 16, 2016 PTD Application: 1E-201_1, 1E-20L1-01, 1E-201_1-02 & 1E-20L1-03 — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 E-20 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 (1R-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 1 E-20L1 17300' 1 E-20L1-01 17315' 1 E-20L1-02 17280' 1 E-20L1-03 17280' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 E-20L1 324' 1 E-03 1 E-20L1-01 265' 1 E-03 1 E-20L1-02 305' 1 E-03 1E-2011-1-03 332' 1E-03 Page 6 of 7 February 16, 2016 PTD Application: 1E-201-1, 1E-201-1-01, 1E-201-1-02 & 1E-201-1-03 16. Attachments Attachment 1: Directional Plans for 1 E-20L 1, 1 E-20L 1-01, 1 E-20L 1-02 & 1 E-20L 1-03 laterals Attachment 2: Current Well Schematic for 1E-20 Attachment 3: Proposed Well Schematic for 1E-20L1, 1E-20L1-01, 1E-20L1-02 & 1E-20L1-03laterals Page 7 of 7 February 16, 2016 m N o m m m Opit o m m rl .- cn m b _ South( -)/North(+) (200 usft/in) m �.. IT— OI •; O m N O 0 q 0 0 O 00 0 O O O O O 0 0 q Q O 0 0 0 b o - 6 - Dm c 600 m w -i. _. ..... .. 6555 Lp. U m m o - —r Q :. 0 : - : � � -- � pry _ _ y • o O 3 b rn m• 00 o raA Sao m r O — N: P S. Lca m sr' m b N 1 E-20 �. KUP ConocoPhillips Well Attributes Alaska Inc ll Wellbore API/UWI Fieldh CONDUCTOR, 3CI10 GAS SURFACE, 33.2.380 GAS LIFT, 3,448 GAS LIFT, 4,314 GAS LIFT GAS LIFT, 6,453 GAS LIFT, 7.114 GAS UFT, 7715 PBR, 7,765 PACKER, 7,778 NIPPLE, 7,795 SOS, 7,8D6 IPERF, 7145-8,094 61M PACKER, 8,13C SBE, 8,133 NIPPLE, 8,148 IPERF, 8.349.8,362 t" 500292089500 JKUPARUK RIVER UNIT IPROD 1 48.52 1 L Comment H2S (ppm) Date Annotation End Date KB-C SSSV: LOCKED OUT 80 9/26/2011 Last W0: 723/1990 Annotation Depth (ftKS) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,948.0 12/20/2010 Rev Reason: WELL REVIEW osborl 5/31/2012 Casing Strings Casing Description String 0... Siring ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 34.0 110.0 110.0 65.00 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd SURFACE 103/4 9.950 33.0 2.380.0 2,172.4 45.50 K-55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.2 8,621.7 6,733.7 26,00 K-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING WO 3 1/2 2.992 27.6 7,807.0 6,102.9 9.20 J-55 BTC-MOD Completion Details Top Depth (ND) Top Incl I ryoml... Top IRKS) (ftKB) (°) Item Description Comment ID pn) TUBE ONLY) .......�y..........r...... .......y ..... .......y ... ... ...r r�.,...,..�...�Y.,,�,.....�...�r.ul,.,.r....�.,,,,y ...... TUBING 31/2 2.992 8,098.0 8,160.0 6,375.8 9.30 J-55 BTCMOD ABANDONED Completion Details Tap Depth (ND) Top Incl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 8,098.0 6,328.0 39.57 BLAST JT SHATTERED 1' OF BLAST JOINT LEFT ON TOP OF ABANDONED 2.992 TUBING COMPLETION Top (ND) Btm (TV T D) Dens Top (ftKB) Stm(ftKB) (ftKB) I (ftKBI Zone Date (ah- Type I Comment 7,945.0 8,094.0 6,210.2 6,324.9 C-4, C-3, C-2, 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" asg guns 1E-20 8,349.0 8,362.0 6,521.6 6,531.6 A-5, 1E-20 TW983 4.0 IPERF 90 deg. Ph; DA 4" Csg guns 8,382.0 8,410.0 6,547.1 6,568.7 A-4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns General & (TV Ind OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Dale Com... 1 2,209.7 2,047.4 43.65 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,244.0 5/12/2008 PRODUCTION, A 31,622-\_ TD, 8,650 :.i U) U CD N O CL O a. 0 N W r Lo O N ❑ 01 Q O C d c E e- ❑ C ❑ N ❑ '� _C co 2 E co ❑ L a r-: o ❑ N O MOR v � N ❑ N 00 lA ❑ '� O 0 ❑ BO LJ N r- ❑^ al N ❑ _ h �\ ❑ O ao rn u dC� V a a fn N v d (n 4! ❑ a (V ❑ a) cn U)E W d _ In O c^ U M C Q m £ ti a ;a ❑ eo ❑ Q1 m c dU a m ~ M d' > <n W `1a) M V H � UIO m a) ❑ I- U co ❑ f0 o `° oo 0- o @� CL dU o rn N U) W N M O m O m In M M U ai U n A M U U) LL U) U N N N N Q) Y Qf Y N a) Y Q1 Y a) Y N N r f6 14 � MM M _ _ Ln cQ Lo C it p m 0 O� V, 11 I I I, I I I I fV p I I I I o 3 o rn 11 ii ' i 3�� 11 0 0 00 1 1 N I I 1 I I I J m @1 0 p I, I I I I ri [1] I I m p a p I I 11 I I I I 3 I I 11 11 gy pr- 4000 1� 11 I II v 11 � .-I F- 6i �, II I, II 1, ,I m Y p U CO O o i (n a 5 @) 0 o C" m J J 07 O 1 p N W o p F- a) O .r_ In Ln Q Lo Y iv � 00 N 00 i- ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1 E Pad 1 E-20 1 E-20L1-02 Plan: 1E-20L1-02 wpO2 Standard Planning Report 09 February, 2017 Ff P P"-- 'A as BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: 1 E-20 Wellbore: 1 E-2011-02 Design: 1E-20L1-02_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 E-20 Mean Sea Level 1 E-20 @ 105.70usft (1 E-20) 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 ri.I BAKER HUGHES Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24 usft Latitude: 70° 18' 3.022 N From: Map Easting: 549,889.51 usft Longitude: 149° 35' 45.358 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 1 E-20 Well Position +Nl-S 0.00 usft Northing: 5,960,000.68 usft Latitude: 70° 18' 5.359 N +E/-W 0.00 usft Easting: 550,300.56 usft Longitude: 149° 35' 33.326 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0,00 usft Wellbore 1 E-20L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BGGM2016 5/1/2017 17.66 80.93 57,541 Design 1E-2011-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,725.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (1) 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) (1 (1) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,725.00 98.84 222.05 6,187.86 1,139.29 4,317.66 0.00 0.00 0.00 0.00 8,795.00 102.58 218.82 6,174.85 1,086.96 4,273.05 7.00 5.34 -4.61 320.00 8,895.00 101.27 211.80 6,154.17 1,007.17 4,216.55 7.00 -1.30 -7.03 260.00 9,000.00 97.00 205.73 6,137.48 916.34 4,166.73 7.00 -4.07 -5.77 235.00 9,200.00 94.39 191.91 6,117.53 728.44 4,102.73 7.00 -1.30 -6.91 260.00 9,600.00 94.82 163.82 6,084.76 334.04 4,117.40 7.00 0.11 -7.02 272.00 9,800.00 89.94 150.68 6,076.42 150.23 4,194.52 7.00 -2.44 -6.57 250.00 10,150.00 85.82 174.85 6,089.55 -181.25 4,297.44 7.00 -1.18 6.91 100.00 10,300.00 87.70 185.20 6,098.05 -330.80 4,297.36 7.00 1.25 6.90 80.00 10,450.00 89.55 174.86 6,101.65 -480.55 4,297.28 7.00 1.23 -6.89 280.00 10,600.00 94.79 165.75 6,095.97 -628.09 4,322.47 7.00 3.49 -6.07 300.00 10,775.00 98.85 177.39 6,075.13 -799.63 4,347.97 7.00 2.32 6.65 70.00 10,925.00 91.37 169.98 6,061.76 -947.91 4,364.43 7.00 -4.99 -4.94 225.00 11,125.00 85.47 182.69 6,067.29 -1,146.93 4,377.20 7.00 -2.95 6.35 115.00 11,300.00 85.57 170.40 6,081.01 -1,320.74 4,387.69 7.00 0.06 -7.02 270.00 2/9/2017 3:13:53PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips NA.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 E-20 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-20 @ 105.70usft (1 E-20) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-20 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-201-1-02 Design: 1E-20L1-02_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) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 8,725.00 98.84 222.05 6,187.86 1,139.29 4,317.66 -1,139.29 0.00 0.00 5,961,168.73 554,610.07 TIPIKOP 8,795.00 102.58 218.82 6,174.85 1,086.96 4,273.05 -1,086.96 7.00 -40.00 5,961,116.12 554,565.82 Start 7 dls 8,800.00 102.52 218.47 6,173.77 1,083.15 4,270.00 -1,083.15 7.00 -100.00 5,961,112.28 554,562.80 8,895.00 101.27 211.80 6,154.17 1,007.17 4.216.55 -1,007.17 7.00 -100.08 5,961,035.95 554,509.86 3 8,900.00 101.07 211.50 6,153.20 1,002.99 4,213.97 -1,002.99 7.00 -125.00 5,961,031.76 554,507.32 9,000.00 97.00 205.73 6,137.48 916.34 4,166.73 -916.34 7.00 -125.06 5,960,944.80 554,460.65 4 9,100.00 95.74 198.81 6,126.37 824.43 4.129.09 -824.43 7.00 -100.00 5,960,852.65 554,423.64 9,200.00 94.39 191.91 6,117.53 728.44 4,102.73 -728.44 7.00 -100.77 5,960,756.49 554,397.93 5 9,300.00 94.60 184.89 6,109.67 629.88 4,088.18 -629.88 7.00 -88.00 5,960,657.85 554,384.03 9,400.00 94.75 177.87 6,101.51 530.30 4,085.77 -530.30 7.00 -88.55 5,960,558.27 554,382.30 9,500.00 94.82 170.85 6,093.17 431.20 4,095.57 -431.20 7.00 -89.12 5,960,459.24 554,392.75 9,600.00 94.82 163.82 6,084.76 334.04 4,117.40 -334.04 7.00 -89.71 5,960,362.24 554,415.23 6 9,700.00 92.40 157.24 6,078.46 240.00 4,150.65 -240.00 7.00 -110.00 5,960,268.44 554,449.11 9,800.00 89.94 150.68 6,076.42 150.23 4,194.52 -150.23 7.00 -110.41 5.960,178,97 554,493.57 7 9,900.00 88.73 157.58 6,077.57 60.32 4,238.12 -60.32 7.00 100.00 5,960,089.36 554,537.77 10,000.00 87.54 164.48 6,080.83 -34.14 4,270.60 34.14 7.00 99.92 5,959,995.13 554.570.88 10,100.00 86.38 171.39 6.086.14 -131.73 4,291.47 131.73 7.00 99.70 5,959,897.69 554,592.40 10,150.00 85.82 174.85 6,089.55 -181.25 4,297.44 181.25 7.00 99.33 5,959,848.22 554,598.70 8 10,200.00 86.43 178.31 6,092.92 -231.04 4,300.42 231.04 7.00 80.00 5,959,798.45 554,602.01 10,300.00 87.70 185.20 6,098.05 -330.80 4,297.36 330.80 7.00 79.77 5,959,698.69 554,599.62 9 10,400.00 88.93 178.31 6,100.99 -430.65 4,294.30 430.65 7.00 -80.00 5,959,596.83 554,597.23 10,450.00 89.55 174.86 6,101.65 -480.55 4,297.28 480.55 7.00 -79.80 5,959,548.96 554,600.55 10 10,500.00 91.30 171.83 6,101.28 -530.20 4,303.08 530.20 7.00 -60.00 5,959,499.35 554,606.67 10,600.00 94.79 165.75 6,095.97 -628.09 4,322.47 628.09 7.00 -60.02 5,959,401.60 554,626.72 11 10,700.00 97.14 172.38 6,085.56 -725.68 4,341.34 725.68 7.00 70.00 5,959,304.15 554,646.24 10,775.00 98.85 177.39 6,075.13 -799.63 4,347.97 799.63 7.00 70.69 5,959,230.25 554,653.36 12 10,800.00 97.61 176.14 6,071.55 -824.33 4,349.36 824.33 7.00 -135.00 5,959,205.56 554,654.92 10,900.00 92.62 171.21 6,062.63 -923.26 4,360.35 923.26 7.00 -135.18 5,959,106.72 554,666.57 10,925.00 91.37 169.98 6,061.76 -947.91 4,364,43 947.91 7.00 -135.62 5,959,082.10 554.670.81 13 11,000.00 89.15 174.74 6,061.41 -1,022.22 4,374.39 1,022.22 7.00 115.00 5,959,007.87 554,681.27 11,100.00 86.20 181,10 6,065.47 -1,122.01 4,378.02 1,122.01 7.00 115.02 5,958,908.11 554,685.57 11,125.00 85.47 182.69 6,067.29 -1,146.93 4,377.20 1,146.93 7.00 114.76 5,958,883.19 554,684.92 14 11,200.00 85.49 177.42 6,073.20 -1.221.67 4,377.13 1,221.67 7.00 -90.00 5,958,808.46 554.685.34 11,300.00 85.57 170.40 6,081.01 -1,320.74 4,387.69 1,320.74 7.00 -89.58 5,958,709.47 554,696.57 Planned TD at 11300.00 21912017 3:13 53PM Page 3 COMPASS 5000.1 Build 74 I ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: 1 E-20 Wellbore: 1 E-20L1-02 Design: 1E-20L1-02_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Shape (1) (1) (usft) (usft) (usft) (usft) 1E-201-1-02_T07 0.00 0.00 6,081.00 -9,202.021,144,502.65 5,958,461.00 plan misses target center by 1140142.20usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 1E-201-1-02_T05 0.00 0.00 6,102.00 -8,362.321,144,412.26 5,959,300.00 plan misses target center by 1140046.31 usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 1E-20 CTD Polygon 0.00 0.00 0.00 -6,188.001,144,253.79 5,961,473.00 plan misses target center by 1139892.71 usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Polygon Point 1 0.00 0.00 0.00 5,961,473.00 Point 0.00 78.68 199.55 5,961,553.01 Point 0.00 57.85 325.42 5,961,533.02 Point 0.00 -69.21 482.60 5,961,407.03 Point 5 0.00 -235.45 515.50 5,961,241.03 Point 6 0.00 -525.72 400.56 5,960,950.02 Point 7 0.00 -921.52 212.90 5,960,553.02 Point 8 0.00 -3,001.00 397.11 5.958,475.02 Point 9 0.00 -3,311.71 349.04 5,958,164.02 Point 10 0.00 -3,289.69 45.15 5,958,184.01 Point 11 0.00 -2,985.44 13.17 5,958,488.01 Point 12 0.00 -1,368.57-240.12 5,960,102.99 Point 13 0.00 -872.84-190.82 5,960,598.99 Point 14 0.00 -595.74 -49.96 5,960,877.00 Point 15 0.00 -325.08 156.86 5,961,149.01 Point 16 0.00 0.00 0.00 5,961,473.00 1E-201-1 Fault2_M 0.00 0.00 0.00 -8,066.931,144,359.23 5,959,595.00 plan misses target center by 1140007.72usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1E-201-1-02_T06 0.00 0.00 6,061.00 -8,853.861,144,483.98 5,958,809.00 plan misses target center by 1140121.17usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 1E-20L1_Fault2 0.00 0.00 6,056.00 -8,066.931,144,359.23 5.959,595.00 plan misses target center by 1139991.50usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Polygon Point 1 6,056.00 0.00 0.00 5,959,595.00 Point 6,056.00 1.00 1.00 5,959,596.01 HIM BAKER HUGHES Well 1 E-20 Mean Sea Level 1 E-20 @ 105.70usft (1 E-20) True Minimum Curvature Easting (usft) Latitude Longitude 1,694,728.00 70' 2' 24.861 N 140' 24' 37.664 W 1,694,632.00 70° 2' 33.146 N 140° 24' 36.607 W 1.694,459.00 70' 2' 54.488 N 140' 24' 31.719 W 1,694,459.00 1, 694, 658.00 1,694,783.99 1, 694, 942.01 1, 694, 976.01 1, 694, 863.03 1, 694, 678.04 1, 694, 876.15 1,694,830.17 1, 694, 526.17 1, 694, 492.15 1, 694, 228.07 1, 694, 274.05 1,694,413.03 1, 694, 618.02 1,694,459.00 1, 694, 577.00 70' 2' 36.092 N 140' 24' 36.838 W I 1,694,707.00 70° 2' 28.268 N 140° 24' 36.691 W 1,694,577.00 70' 2' 36.092 N 140' 24' 36.838 W 1,694,577.00 1, 694, 577.99 1 E-201-1-02_T01 0.00 0.00 6,141.00-6.943.351,144,293.74 5,960,718.00 1.694,504.00 70° 2' 47.096 N 140° 24' 33.847 W plan misses target center by 1139919.92usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 1E-201-1-02_T04 0.00 0.00 6,092.00-8,102.301,144,415.00 5,959,560.00 1,694,633.00 70' 2' 35.666 N 140' 24' 35.406 W plan misses target center by 1140047.48usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 1 E-201-1_Fault1_M 0.00 0.00 0.00-6,660.691,144,497.66 5,961,002.00 1,694,706.00 70° 2' 49.539 N 140° 24' 26.829 W plan misses target center by 1140138.69usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 1E-201-1_Faultl 0.00 0.00 6,203.00-6,660.691,144,497.66 5,961,002.00 1,694,706.00 70° 2' 49.539 N 140' 24' 26.829 W plan misses target center by 1140122.48usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Polygon Point 1 6,203.00 0.00 0.00 5,961,002.00 1,694,706.00 Point 6,203.00 1.00 1.00 5,961,003.01 1,694,706.99 1 E-20L1-02_T02 0.00 0.00 6.110.00-7,251.791.144,203.67 5,960,409.00 1,694,416.00 700 2' 44.234 N 140° 24' 37.739 W plan misses target center by 1139831.41 usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point 2/9/2017 3:13:53PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: 1 E-20 Wellbore: 1 E-20L1-02 Design: 1 E-20L1-02_wp02 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 E-20 Mean Sea Level 1 E-20 @ 105.70usft (1 E-20) True Minimum Curvature CAkI BAKER HUGHES -201-1-02_T03 0.00 0.00 6,076.00-7,731.551,144,309.47 5,959,930.00 1,694,525.00 70° 2' 39.421 N 140° 24' 36.804 plan misses target center by 1139939.80usft at 11300.00usft MD (6081.01 TVD,-1320.74 N, 4387.69 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,300.00 6,081 01 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 8,725.00 6,187.86 8,795.00 6,174.85 8,895.00 6,154.17 9,000.00 6,137.48 9,200.00 6,117.53 9,600.00 6,084.76 9,800.00 6,076.42 10,150.00 6,089.55 10,300.00 6,098.05 10,450.00 6,101.65 10,600.00 6,095.97 10,775.00 6,075.13 10,925.00 6,061.76 11,125.00 6,067.29 11,300.00 6,081.01 Local Coordinates +N/-S +E/-W (usft) (usft) Comment 1,139.29 4,317.66 TIP/KOP 1,086.96 4,273.05 Start 7dls 1,007.17 4.216.55 3 916.34 4,166.73 4 728.44 4,102.73 5 334.04 4,117.40 6 150.23 4,194.52 7 -181.25 4,297.44 8 -330.80 4,297.36 9 -480.55 4,297.28 10 -628.09 4,322.47 11 -799.63 4,347.97 12 -947.91 4,364.43 13 -1,146.93 4,377.20 14 -1,320.74 4,387.69 Planned TD at 11300.00 21912017 3:13:53PM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ FCC.■ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Site Error: 0.00 usft Reference Well: 1 E-20 Well Error: 0.00 usft Reference Wellbore 1 E-201-1-02 Reference Design: 1 E-20L1-02_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 E-20 1 E-20 @ 105.70usft (1 E-20) 1 E-20 @ 105.70usft (1 E-20) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1E-20L1-02_wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,725.00 to 11,300.O0usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,319.43 usft Error Surface: Elliptical Conic Survey Tool Program Date 2/8/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 7,900.00 1E-20 (1E-20) FINDER -MS SDC Finder multishot 7,900.00 8,725.00 1E-20L1_wp03(1E-201-1) MWD MWD- Standard 8,725.00 11,300.00 1E-20L1-02_wp02(1E-201-1-02) MWD MWD- Standard Casing Points Measured Vertical Depth Depth (usft) (usft) 11,300.00 6,186.71 2 3/8" Summary Casing Hole Diameter Diameter Name 2-3/8 3 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-03 - 1 E-03 - 1 E-03 11,296.30 8,125.00 305.50 198.80 195.84 Pass - Major Risk 1 E-07 - 1 E-07A - 1 E-07A Out of range 1 E-07 - 1 E-07AL1 - 1 E-07ALl Out of range 1 E-102 - 1 E-102 - 1 E-102 Out of range 1 E-102 - 1 E-10211 - 1 E-10211 Out of range 1 E-102 - 1 E-1021-1 - Plan 1 E-102 D Lat (wp05) Out of range 1 E-102 - 1 E-10211 PB1 - 1 E-10211 P131 Out of range 1 E-102 - 1 E-102PB1 - 1 E-102PB1 Out of range 1 E-102 - 1 E-102PB1 - Plan 1 E-102 B lat (wp5.0) Out of range 1 E-102 - 1 E-102PB2 - 1 E-102PB2 Out of range 1 E-104 - 1 E-104 - 1 E-104 Out of range 1 E-104 - 1 E-104 - Plan 1 E-104 (wp04) Out of range 1 E-105 - 1 E-105 - 1 E-105 Out of range 1 E-105 - 1 E-105L1 - 1 E-105L1 Out of range 1 E-105 - 1 E-1051-2 - 1 E-10512 Out of range 1 E-105 - 1 E-105PB1 - 1 E-105PB1 Out of range 1 E-105 - 1 E-105PB2 - 1 E-105PB2 Out of range 1 E-112 - 1 E-112 - 1 E-112 Out of range 1 E-112 - 1 E-112L1 - 1 E-112L1 Out of range 1 E-112 - 1 E-1121_2 - 1 E-1121_2 Out of range 1 E-112 - 1 E-112PB1 - 1 E-112PB1 Out of range 1 E-126 - 1 E-126 - 1 E-126 Out of range 1 E-126 - 1 E-126L1 - 1 E-1261-1 Out of range 1 E-126 - 1 E-1261_2 - 1 E-1261_2 Out of range 1 E-18 - 1 E-18 - 1 E-18 Out of range 1 E-19 - 1 E-19 - 1 E-19 Out of range 1 E-20 - 1 E-20 - 1 E-20 8,734.10 7,575.00 582.26 14.41 571.34 Pass - Major Risk 1E-20-1E-201_1-1E-201_1 w03 8,725.00 8,725.00 0.00 0.31 -0.22 FAIL - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 21812017 1:33:08PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Site Error: 0.00 usft Reference Well: 1 E-20 Well Error: 0.00 usft Reference Wellbore 1E-20L1-02 Reference Design: 1E-201-1-02_wp02 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 E Pad 1 E-20 - 1 E-201-1-01 - 1 E-20L1-01_wp03 1 E-20 - 1 E-201-1-03 - 1 E-20L1-03_wp00 1 E-21 - 1 E-21 - 1 E-21 1 E-22 - 1 E-22 - 1 E-22 1 E-23 - 1 E-23 - 1 E-23 1 E-24 - 1 E-24 - 1 E-24 1 E-24 - 1 E-24A - 1 E-24A 1 E-24 - 1 E-24B - 1 E-24B 1 E-24 - 1 E-24131_1 - 1 E-241311 1 E-24 - 1 E-24 B L1 P B 1- 1 E-24B L 1 P E 1 1 E-24 - 1 E-24BL1 PB2 - 1 E-24131_1 P132 1 E-24 - 1 E-24BL1 P133 - 1 E-24131_1 PB3 1 E-24 - 1 E-24BL2 - 1 E-24BL2 1 E-24 - 1 E-24131-2-01 - 1 E-24131-2-01 1 E-24 - 1 E-24131-2-02 - 1 E-24131-2-02 1 E-33 - 1 E-33 - 1 E-33 1 E-33 - 1 E-33P B 1- 1 E-33 P B 1 Plan 1 E-108 - Plan 1 E-108 - Plan 1 E-108 (wp03) Baker Hughes INTEQ ��.. Travelling Cylinder Report BAKER HUGHES Local Co-ordinate Reference: Well 1 E-20 TVD Reference: 1 E-20 @ 105.70usft (1 E-20) MD Reference: 1 E-20 @ 105.70usft (1 E-20) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: OAKEDMP2 Offset ND Reference: Offset Datum Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 8,725.00 8,725.00 0 00 0.31 -0.22 FAIL- Minor 1110 8,810.56 8,800.00 0.54 1.37 -0.41 FAIL- Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 1 E Pad - 1 E-03 - 1 E-03 - 1 E-03 Offset site Error: 0.00 usft Survey Program: 200-FINDER-MS Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) V) (usft) (usft) (") (usft) (usft) (usft) 10,928.56 6,167.37 7,000.00 5,021-47 37.70 30.87 -161.09 -1,033.12 3,742.61 2-11116 1,305.98 179.03 1,192.57 Pass - Major Risk 10,937.37 6,167.20 7,025.00 5,040.07 37.76 30.99 -160.68 -1,038.91 3,758.28 2-11116 1,282+57 179.13 1,169.15 Pass - Major Risk 10,946.08 6,167.07 7,050.00 5,058+71 37.82 31.12 -160.29 -1,044.74 3,773.89 2-11116 1,259.16 179.23 1,145.75 Pass - Major Risk 10,954.71 6,166.97 7,075.00 5,077+38 37.88 31.24 -159.92 -1,050.62 3,789.45 2-11/16 1,235.76 179.31 1,122.36 Pass - Major Risk 10,963.26 6,166.92 7,100.00 5,096.08 37.93 31.37 -159.56 -1,056.52 3,804.95 2-11/16 1,212.36 179.37 1,098.99 Pass - Major Risk 10,971.67 6,166.90 7,125.00 5,114.82 37.98 31.50 -159.22 -1,062.43 3,820.40 2-11/16 1,188.96 179.43 1,075.63 Pass - Major Risk 10,979-91 6,166.92 7,150.00 5,133.60 38.04 31.62 -158.90 -1,068.28 3,835.83 2-11/16 1,165.54 179.48 1,052.27 Pass - Major Risk 10,98Z97 6,166.97 7,175.00 5,152.42 38.09 31.75 -158.61 -1,074.08 3,851.24 2-11116 1,142.12 179.54 1,028.91 Pass - Major Risk 10,995.87 6,167.06 7,200.00 5,171.26 38A4 31.87 -158.34 -1,079.83 3,866.62 2-11/16 1,118.68 179.60 1,005+55 Pass - Major Risk 11,003.71 6,167.17 7,225.00 5,190+15 38.20 32.00 -158.09 -1,085.63 3,881.94 2-11116 1,095.26 179.65 982.22 Pass - Major Risk 11,011.58 6,167.32 7,250.00 5,209+07 38.25 32.12 -157.84 -1,091.58 3,897.16 2-11/16 1,071.88 179.70 958.93 Pass - Major Risk 11,019.49 6,167.50 7,275.00 5,228.03 38.31 32.25 -157.61 -1,097.67 3,912.27 2-11/16 1,048+54 179.75 935.68 Pass - Major Risk 11,027.45 6,167.71 7,300.00 5,247.03 38.36 32.37 -157.38 -1,103.92 3,927.28 2-11/16 1,025.24 179.79 912.48 Pass - Major Risk 11,035.39 6,167.96 7,325.00 5,266.05 38.42 32.49 -157.16 -1,110.26 3,942.21 2-11/16 1,001.98 179.84 889.32 Pass - Major Risk 11,043.28 6,168.24 7,350.00 5,285.12 38.48 32.61 -156.96 -1,116+65 3,957.06 2-11/16 978.73 179.89 866.19 Pass - Major Risk 11,051.11 6,168.55 7,375.00 5,304.22 38.53 32.74 -156.78 -1,123+09 3,971.85 2-11/16 955.51 179.93 843.10 Pass - Major Risk 11,058.89 6,168.88 7,400.00 5,323.35 38.59. 32.86 -156.63 -1,129.58 3,986.58 2-11/16 932.32 179.98 820.04 Pass - Major Risk 11,066.66 6,169+25 7,425.00 5,342.54 38.65 32.98 -156.48 -1,136.15 4,001.19 2-11/16 909.15 180.02 797.03 Pass - Major Risk 11,074.46 6,169+65 7,450.00 5,361.79 38.71 33.10 -156.35 -1,142.86 4,015.66 2-11/16 886.03 180.07 774.05 Pass - Major Risk 11,082.30 6,170.08 7,475.00 5,381.12 38.77 33.22 -156.23 -1,149.69 4,029+97 2-11/16 862.94 180.12 751.11 Pass - Major Risk 11,090.17 6,170+55 7,500.00 5,400.52 38.83 33.34 -156.12 -1,156.65 4,044.12 2-11116 839.90 180.17 728.23 Pass - Major Risk 11,098.00 6,171.04 7,525.00 5,419.93 38.89 33.46 -156.04 -1,163.67 4,058.23 2-11/16 816.90 180.22 705.40 Pass - Major Risk 11,105.72 6,171.56 7,550.00 5,439.31 38.95 33.58 -156.00 -1,170.66 4,072.39 2-11/16 793.95 180.27 682.64 Pass - Major Risk 11,113.31 6,172.10 7,575.00 5,458.65 39.01 33.70 -156.01 -1,177.63 4,086.61 2-11/16 771.05 180.33 659.97 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 21812017 1:33:08PM Page 3 COMPASS 5000.1 Build 74 g- g N .G O 7 a j L O W aLLJ N > > J N C G N N W Y OIL di a- O oy3aN! - O O LU C a _ 0 W 0 o a W w o o W W W W � W 00 P .-. •-' .-. 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O O O O O O O Jp m (ui/lisn 06) uldaQ poijnn onjL TRANSMITTAL LETTER CHECKLIST WELL NAME: K R U� PTD: a - o Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: In {var POOL: K " iV a �✓1 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. 1S3—o0S , API No. 50-�,�- 0 (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 (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2170240 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 1E-201-1-02 Program DEV Well bore seg DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal [' Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025651, entire wellbore. 3 Unique well name and number Yes KRU 1E-201-1-02 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No 432D. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432D has no intenaell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 2/27/2017 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 3/7/2017 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date / 37 Seismic analysis of shallow gas zones NA PKB 2/27/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date C io r Date Conductor set in KRU 1 E-20 Surface casing set in KRU 1 E-20 Surface casing set and fully cemented Productive interval will be completed with slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3034 psig(9.4 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD MPSP is 2412 psig; will test BOPs to 3500 psig 112S measures required Wells on 1E-Pad are H2S-bearing. H2S measures required. Max potential reservoir pressure is 9.4 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Onshore development lateral to be drilled.