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HomeMy WebLinkAbout217-067Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, May 13, 2019 8:40 AM To: 'Starck, Kai' Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA) Subject: KRU 3M-28 L1, L1-01, L1-02, L1-03, PTDs 217-066, 217-067, 217-068, 217-069 Permits Expired Hello Kai, 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 3M-28 L1, PTD 217-066, Issued 5 May 2017 • KRU 3M-28 1-1-01, PTD 217-067, Issued 5 May 2017 • KRU 3M-28 1-1-02, PTD 217-068, Issued 5 May 2017 • KRU 3M-28 1-1-03, PTD 217-069, Issued 5 May 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 Val GOVERNOR BILL WALKER Kai Starck CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-28L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-067 Surface Location: 1285' FNL, 1737' FEL, Sec. 25, T13N, R8E, UM Bottomhole Location: 5128' FNL, 2058' FEL, Sec. 27, TUN, R8E, UM Dear Mr. Starck: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 194-012, API No. 50-029- 22442-00-00. 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, Daniel T. Seamount, Jr. Commissioner DATED this day of May, 2017. RECEIVED STATE OF ALASKA AL .,K<A OIL AND GAS CONSERVATION COMMi-LION PERMIT TO DRILL 20 AAC 25.005 MAY 0 2.2017 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral 'I Stratigraphic Test ❑ Development - Oil ❑� - Service - Winj ❑ Single Zone ❑✓ - Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 KRU 3M-28L1-01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14850' TVD: 5972' Kuparuk River Field / Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1285' FNL, 1737' FEL, SEC 25, T 13N, R 8E, UM ADL 25524 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 886' FNL, 956' FEL, SEC 34, T 13N, R 8E, UM AKL 2655 5/6/2017 Total Depth: 9. Acres in Property: 'V 14. Distance to Nearest Property: 5128' FNL, 2058' FEL, SEC 27, T 13N, R 8E, UM 4928 Ilygb 6070' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): gg 15. Distance to Nearest Well Open Surface: x- 506131 Y 6016214 Zone- 04 GL Elevation above MSL (ft): 27 to Same Pool: 3M-24 1717' 16. Deviated wells: Kickoff depth: 13300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3968 • Surface: 3392 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 1850' 13000' 6030' 14850' 5982' 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): 13222 6272 N/A 13130 6210 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 121.00 16" 222 SX ASI CMT 121 121 Surface 6,065.00 9-5/8" 1250 SX ASIII, 650 SX G 6065 3398 120 SX ASI CMT TOP JOB Production 13,222.00 7" 250 SX CLASS G CMT 13222 6272 Perforation Depth MD (ft): 12,914-12-938 Perforation Depth TVD (ft): 6065-6081 20. Attachments: Property Plat BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 5/1/2017 22. I hereby certify that the foregoing is true and the procedure approved herein will not Trevor Hyatt 907-263-4107 be deviated from without prior written approval. Contact Email trevor.hvatt(a)contractor.conocoohillips.com Printed Name Kai Starck Title CTD Team Lead Signature Phone 907-263-4109 Date 5/1/2017 Commission Use Only Permit to Driff Number: a I — C)7— API Number: 50- V o — rJ0 I Permit Approval Date: S Z5 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: f fv L�UU C� J� S i Samples req'd: Yes ❑ No[+� Mud log req'd: Yes ❑ No[' a �� v� V Z"j, �.5 f f a ZSGU`� in�asures: Yes [f No ❑ Directional svy req'd: Yes V No ❑ c.4 /t- (1 l 5_� �1 Y� �) N� Spacing exception req'd: Yes ❑ No t� Inclination -only svy req'd: Yes❑ No❑✓� 9 _a" j _ecl �j J n 1� Post initial injection MIT req'd: Yes El NoP! a ��(' w vt l � �iG �'�` r� r rr � f D C/� avt OIL] r �.,-,/" a APPROVED BY Approved by:/24COMMISSIONER THE COMMISSION Date: J Submit Form and 7 Form 10-401 (Revised 11/2015) / s (rfisWAL4 0months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 1, 2017 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED MAY 0 2.2017 i ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad -lateral out of the KRU 3M-28 (PTD# 194-12) using the coiled tubing drilling rig, Nabors CDR3-AC. 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 (31VI-281-1, 31VI-281-1-01, 31M-281-1-02, & 31VI-281-1-03), targeting the Kuparuk A -sand intervals. The work is scheduled to begin May 6th, 2017. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3M-28L1, 3M-281_1-01, 3M-28L1-02, & 3M-281_1-03 — Detailed Summary of Operations — Directional Plans for 3M-28L1, 31VI-281-1-01, 31VI-281-1-02, & 3M-281_1-03 — Current wellbore schematic (proposed from ongoing RWO) — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4109. Sincerely, CTvor Hyatt Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 3M-28L1, 3M-28L1-017 3M-28L1-027 & 3M-281-1-03NA80RS+A`LAsxa 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 AA 25.005 c 3................................ 2 4. Drilling Hazards Information and Reservoir Pressure..................................................................2 (Requirements of 20 AA 25.005 c 4................................................. 2 5. Procedure for Conducting Formation Integrity tests.................................................................... 2 (Requirements of 20 A A C 25.005(c)(5)) ............._....................................._........................................................................................... 2 6. Casing and Cementing Program....................................................................................................3 (Requirements of 20 A A C 25.005(c)(6))................................................................................................................................................. 3 7. Diverter System Information..........................................................................................................3 (Requirements of 20 AA 25.005(c)(7))................................................................................................................................................. 3 8. Drilling Fluids Program...................................................................................................................3 (Requirements of 20 AA 25.005(c)(8))................................................................................................................................................. 3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AA 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 AA 25.005(c)(11))...............................................................................................................................................4 12. Evidence of Bonding......................................................................................................................4 (Requirements of 20 A A C 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 AA 25.005(c)(14))............................................................................................................................................... 6 15, Directional Plans for Intentionally Deviated Wells........................................................................6 (Requirements of 20 AA 25.050(b))..................................................................................................................................................... 6 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 3M-28L1, 3M-28L1-01, 3M-28L1-02, & 3M-28L1-03 laterals .................................. 7 Attachment 2: Current Well Schematic for 3M-28.......................................................................................................... 7 Attachment 3: Proposed Well Schematic for 3M-28L1, 3M-28L1-01, 3M-28L1-02, & 3M-28L1-03 laterals ................... 7 Page 1 of 7 May 1, 2017 PTD Application: 3M-28L1, 31VI-281_1-01, 3M-28L1-02 & 31VI-281_1-03 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 3M-28L1, 3M-281_1-01, 3M-281-1-02 & 3M-281_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 A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3M-28L1, 3M-281_1-01, 31VI-281-1-02 & 3M-281-1-03. 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 4,000 psi. Using the maximum formation pressure in the area of 3,968 psi in 3M-29A (i.e. 13.25 ppg EMW), the maximum potential surface pressure in 3M-28, assuming a gas gradient of 0.1 psi/ft, would be 3,392 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3M-28 was measured to be 3,744 psi (12.0 ppg EMW) on 4/27/2017. The maximum downhole pressure in the 3M-28 vicinity is to the south in the 3M-29A injector at 3,968 psi (13.25 ppg EMW) from 9/7/2012. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 3M-28 have only injected a small amount of gas and not recently, so there is a low probability of encountering free gas while drilling the 3M-28 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 3M-28 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3M-28 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 May 1, 2017 PTD Application: 3M-28L1, 31VI-281_1-01, 31VI-281_1-02 & 3M-28L1-03 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 3M-28L1 13,300' 14,850' 6,008' 5,996' 2-3/8", 4.7#, L-80, ST-L slotted liner, - aluminum billet on to 31VI-281_1-01 13,000' 14,850' 6,030' 5,972' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-28L1-02 13,300' 14,700' 6,008' 5,994` 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 3M-28L1-03 12,905' 15,050' 5,991' 5,998, 2-3/8", 4.7#, L-80, ST-L slotted liner; de to ment sleeve Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 L-80 BTC 0' 6,065' 0' 3,398' 3061 1925 Production 7" 26.0 L-80 BTC-R3 0' 13,222' 0' 6,272' 6296 5156 Tubing 3-1/2" 9.3 L-80 ELIE 0' 12,964' 0' 6,021' 8467 9164 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride -based FloVis mud (8.6 ppg) - Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: The well will be loaded with 12.2 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3M-28 laterals we will target a constant BHP of 12.0 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 May 1, 2017 PTD Application: 3M-28L1, 31VI-281_1-01, 31VI-281_1-02 & 31VI-281_1-03 Pressure at the 3M-28 Window (12,907' MD, 5991' TVD) Usina MPD Pumps On 1.5 b m Pumps Off A -sand Formation Pressure 12.0 3738 psi 3738 psi Mud Hydrostatic 8.6 2679 psi 2679 psi Annular friction i.e. ECD, 0.09 si/ft 1162 psi 0 psi Mud + ECD Combined no chokepressure) 3841 psi overbalanced —102psi) 2679 psi underbalanced —1059psi) Target BHP at Window 12.0 3738 psi 3738 psi Choke Pressure Required to Maintain Target BHP 0 psi 1059 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3M-28 is a Kuparuk A -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Al sands to the north and west of the 3M-28. The laterals will add new resources and improve existing recovery. Prior to CTD operations, a workover will replace the existing completion with a 3-1/2" tubing completion and Tandem Wedge Assembly to facilitate the CTD 3-1/2" x 7" window exit. Post CTD workover, a mechanical whip -stock will be set inside the 3-1/2" tubing completion at the planned kick off point of 12,907' MD. The 3M-28L1 lateral will exit through the 3-1/2" x 7" at 12,907' MD and TD at 14,850' MD, targeting the Al sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 13,300' MD with an alu ninum billet for kicking off the 3M-28L1-01 lateral. The 3M-28L 1-01 lateral will drill to a TD of 14,850' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 13,000' MD with an aluminum billet for kicking off the 3M-28L1-02 lateral. The 3M-28L1-02 lateral will drill to a TD of 14,700' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 13,300' MD with an aluminum billet for kicking off the 3M-28L 1-03 lateral. Page 4 of 7 May 1, 2017 PTD Application: 3M-28L1, 3M-281_1-01, 3M-281_1-02 & 3M-281_1-03 The 3M-28L1-03 lateral will drill to a TD of 15,050' MD targeting the Al sand. It will be completed with 2-3/8" slotted liner from TD up to 12,907' MD with a deployment sleeve. Pre-CTD Work 1. Perform RWO to install 3-1/2" tubing, packer, and Tandem Wedge Assembly. Rig Work 1. MIRU Nabors Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M-28L1 Lateral (Al sand) a. Set top of whipstock at 12,907' MD and orient to 0° ROHS (set pre -rig if timing allows). b. Mill 2.80" window at 12,907' MD. c. Drill 3" bi-center lateral to TD of 14,850' MD. d. Run 2-3/8" slotted liner with an aluminum billet from TD up to 13,300' MD. 3. 3M-28L1-01 Lateral (Al sand) a. Kick off of the aluminum billet at 13,300' MD. b. Drill 3" bi-center lateral to TD of 14,850' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 13,000' MD. 4. 3M-28L1-02 Lateral (Al sand) a. Kick off of the aluminum billet at 13,300' MD. b. Drill 3" bi-center lateral to TD of 14,700' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 13,300' MD. 5. 3M-28L1-03 Lateral (Al sand) a. Kick off of the aluminum billet at 13,300' MD. b. Drill 3" bi-center lateral to TD of 15,050' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 12,905' MD. 6. Freeze protect, set BPV, ND BOPS, and RDMO Nabors CDR3- AC rig. Post -Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install gas lift design. 4. Return to production. Page 5 of 7 May 1, 2017 PTD Application: 3M-28L1, 31VI-281-1-01, 3M-28L1-02 & 31VI-281-1-03 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 moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 3M-28 laterals will be displaced to an overbalancing fluid (12.2 ppg NaBr) 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 AA 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 31VI-2811_1 6070' 31VI-2811-1-01 6070' 31VI-2811-1-02 6460' 31VI-2811-1-03 7350' Page 6 of 7 May 1, 2017 PTD Application: 31VI-281-1, 31VI-281-1-01, 31VI-281-1-02 & 31VI-281-1-03 — Distance to Nearest Well within Pool Lateral Name Distance Well 3M-28L1 1717' 3M-24 3M-28L1-01 1717' 3M-24 3M-28L1-02 2164' 3M-24 3M-28L1-03 1550' 3M-24 16. Attachments Attachment 1: Directional Plans for 3M-28L 1, 3M-28L 1-0 1, 3M-28L 1-02, & 3M-28L 1-03 laterals Attachment 2: Current Well Schematic for 3M-28 Attachment3: Proposed Well Schematic for 3M-28L1, 3M-28L1-01, 3M-28L1-02, & 3M-28L 1-03 laterals Page 7 of 7 May 1, 2017 00 N 2 Cl) cl U � m _ �~\ V Q 7 to rn _ p in x O 0) v X Q cca E r> cl N v x ul a00 Q W a7 XX X �1 w � In W N 0 0 m U d C i O E J �# O E N N J 7 M U M of @ U = c� t> a N N N N N L Cl) Cl) co m c6 c0 m O 2 c O p Cc:a = m ��=J d O OW 01i =3 ,. °ON CLLZ O JvJ N Nx � cl�O ommeo t ��- (qT(n � W O chum! o.-= Z « « < r O 0 0 � rz g o 3 00 o m a i J II II � I I Q L I I I I O H O \\ \ I 1 ,l 11 11 11 \\1 I 1 Iv\\ 11�1 0 L o N 0 o No +� O O N J N U) 000 Q - N 2 M N N r � � M N O L� Q d,� ConocoPhillips Well Details: API: 50-029-22442-00 PTD: 194-012 Wellhead: McEvoy Gen IV 5M Casing/Tubing Details: 16" 62.5# H-40 Conductor to 121' MD 9-5/8" 36# L-80 Surface to 6,064' MD 7" 26# L-80 Production to 13,222' MD 3-1/2" 12.6# L-80 Tubing to 12,964' MD Kuparuk A Sand Perfs 12,914'-12,938' KB 3M-28 KRU Producer PROPOSED RWO COMPLETION 3-1/2" x 1" KBMG GLM PBR and Seal Assembly 3-%" x 7" FHL Packer Tandem Wedge Assembly 2.81" X Nipple Tandem Wedge Assembly 2.81" X Nipple Date: April 17, 2017 1 Drawn By: Andrew Beat w W � Alz we ' =a m (ui/gsn 009) (+)4ljoN/(-)ulnoS c 0 N Y CdCd ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3M Pad 3M-28 3 M-28 L 1-01 Plan: 3M-28L1-01_wp01 Standard Planning Report 28 April, 2017 we ppl_- 'A as BAKER HUGHES ConocoPhillips wel.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-28 Wellbore: 3M-28L1-01 Design: 3M-281-1-01_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-28 Mean Sea Level 3M-28 @ 68.00usft (3M-28) True Minimum Curvature ?roject Kuparuk River Unit, North Slope Alaska, United States Vlap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3M Pad Site Position: Northing: 6,016,202.17 usft Latitude: 70° 27' 19.780 N From: Map Easting: 506,126.99usft Longitude: 1490 56' 59.998 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.05 ° - Well 3M-28 Well Position +N/-S 0.00 usft Northing: 6,016,213.75 usft Latitude: 70° 27' 19.893 N +E/-W 0.00 usft Easting: 506,131.74 usft Longitude: 1490 56' 59,858 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3M-28L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2016 _ 8/1/2017 (1 (°) 17.48 81.00 (nT) 57,541 Design 3M-28L1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 13,300.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I 0.00 0.00 0.00 330.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (I (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 13,300.00 94.48 295.43 6,008.30-4,875.29 -9,777.98 0.00 0.00 0.00 0.00 13,400.00 88.41 298.93 6,005.78-4,829.65 -9,866.85 7.00 -6.07 3.49 150.00 13,500.00 88.42 305.93 6,008.55-4,776.08 -9,951.17 7.00 0.01 7.00 90.00 13,570.00 90.10 310.53 6,009.45-4,732.78 -10,006.14 7.00 2.40 6.58 70.00 13,670.00 91.91 317.30 6,007.69-4,663.47 -10,078.12 7.00 1.81 6.76 75.00 13,950.00 91.80 336.91 5,998.54-4,429.65 -10,229.38 7.00 -0.04 7.00 90.00 14,280.00 91.65 313.80 5,988.46-4,160.13 -10,415.64 7.00 -0.04 -7.00 270.00 14,550.00 91.57 294.89 5,980.81-4,008.56 -10,637.48 7.00 -0.03 -7.00 270.00 14,850.00 91.46 315.90 5,972.80-3,835.84 -10,880.58 7.00 -0.03 7.00 90.00 412812017 5:09:24PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips MAP .. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3M Pad Well: 3M-28 Wellbore: 3M-281-1-01 Design: 3M-28L1-01 _wp01 Planned Survey Measured TVD Below Depth Inclination Azimuth System (usft) (1) (°) (usft) 13,300.00 94.48 295.43 6,008.30 TIP/KOP 13,400.00 88.41 298.93 6,005.78 Start 7 dls 13,500.00 88.42 305.93 6,008.55 3 13.570.00 90.10 310.53 6,009.45 4 13,600.00 90.65 312.56 6,009.25 13,670.00 91.91 317.30 6.007.69 5 13,700.00 91.91 319.40 6,006.69 13,800.00 91.89 326.40 6,003.38 13,900.00 91.83 333.41 6,000.13 13,950.00 91.80 336.91 5.998.54 6 14,000.00 91.80 333.41 14,100.00 91.77 326.40 14,200.00 91.72 319.40 14,280.00 91.65 313.80 7 14,300.00 91.65 312.40 14,400.00 91.64 305.39 14,500.00 91.60 298.39 14,550.00 91.57 294.89 8 14,600.00 91.56 298.39 14,700.00 91.54 305.39 14,800.00 91.49 312.40 14,850.00 91.46 315.90 Planned TD at 14850.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3M-28 Mean Sea Level 3M-28 @ 68.00usft (3M-28) True Minimum Curvature Vertical Dogleg Toolface Map Map +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) -4,875.29 -9,777.98 666.87 0.00 0.00 6,011,330.91 496,358.75 -4,829.65 -9,866.85 750.83 7.00 150.00 6,011,376.47 496.269.85 -4,776.08 -9,951.17 839.38 7.00 90.00 6,011,429.96 496,185.49 -4,732.78 -10,006.14 904.36 7.00 70.00 6,011,473.21 496,130.50 -4,712.88 -10,028.59 932.82 7.00 75.00 6,011,493.09 496,108.03 -4,663.47 -10.078.12 1,000.37 7.00 75.01 6,011,542.45 496,058.47 -4,641.07 -10,098.05 1,029.74 7.00 90.00 6,011,564.83 496,038.52 -4,561,41 -10,158.30 1,128.85 7.00 90.07 6,011,644.44 495,978.21 -4,474.99 -10,208.39 1,228.74 7.00 90.30 6,011,730.81 495,928.06 -4,429.65 -10,229.38 1,278.50 7.00 90.53 6,011,776.13 495,907.03 5,996.97 -4,384.30 -10,250.37 1,328.27 7.00 -90.00 6,011,821.45 495,886.00 5,993.86 -4,297.88 -10,300.46 1,428.16 7.00 -90.11 6,011,907.82 495,835.85 5,990.82 -4.218.21 -10,360.72 1,527.28 7.00 -90.33 6,011,987.44 495,775.53 5,988.46 -4,160.13 -10,415.64 1,605.04 7.00 -90.54 6.012,045.46 495,720.57 5,987.89 -4,146.47 -10,430.24 1,624.17 7.00 -90.00 6,012,059.11 495,705.96 5,985.01 -4,083.75 -10,507.99 1,717.36 7.00 -90.04 6,012,121.76 495,628.17 5,982.19 -4,030.97 -10,592.81 1,805.48 7.00 -90.24 6,012,174.46 495,543.31 5,980.81 -4,008.56 -10,637.48 1,847.22 7.00 -90.44 6,012,196.83 495,498.63 5,979.44 -3,986.16 -10,682.14 1,888.96 7.00 90.00 6,012,219.20 495,453.95 5,976.73 -3,933.38 -10,766.96 1,977.08 7.00 90.10 6,012,271.91 495,369.09 5,974.09 -3,870.65 -10,844.72 2,070.28 7.00 90.29 6,012,334.56 495.291.29 5,972.80 -3,835.84 -10,880.58 2,118.35 7.00 90.47 6,012,369.34 495,255.41 412812017 5:09:24PM Page 3 COMPASS 5000.1 Build 74 ✓ ConocoPhillips MAP kI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3M-28 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-28 @ 68,00usft (3M-28) Site: Kuparuk 3M Pad North Reference: True Well: 31VI-28 Survey Calculation Method: Minimum Curvature Wellbore: 3M-28L1-01 Design: 3M-28L1-01_wp01 Targets Target Name - hittmiss target Dip Angle Dip Dir. TVD +N1-S +Ei-W Northing Easting - Shape (1) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3M-281-1-027Faultl_M 0.00 0.00 0.00 -5,640.661,130,482.00 6,011,504.00 1,636,505.00 70' 12' 27.492 N 140' 48' 22.910 W plan misses target center by 1140276.07usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Rectangle (sides W1.00 H500.00 D0.00) 3M-281-1-02 Faultl 0.00 0.00 5,987.00 -5,640.661,130,482.00 6,011,504.00 1,636,505.00 70° 12' 27.492 N 140' 48' 22.910 W plan misses target center by 1140260.24usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Polygon Point 1 5,987.00 0.00 0.00 6,011,504.00 1,636,505.00 Point 5,987.00 1.00 1.00 6,011,505.00 1,636,506.00 3M-281-1-03_Faultl 0.00 0.00 5,979.00 -5,768.691,130,502.90 6,011,376.00 1,636,526.00 700 12' 26.218 N 1400 48' 22.867 W plan misses target center by 1140281.23usft at 13300.O0usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Polygon Point 1 5,979.00 0.00 0.00 6,011,376.00 1,636,526.00 Point 5,979.00 1.00 1.00 6,011,377.00 1,636,527.00 3M-28 CTD Polygon Noi 0.00 0.00 0.00 -6,199.981,130,795.57 6,010,945.00 1,636,819.00 70° 12' 21.600 N 140° 48' 16.353 W plan misses target center by 1140590.14usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Polygon Point 1 0.00 0.00 0.00 6,010,945.00 1,636,819.00 Point 0.00 344.17-180.75 6,011,288.99 1,636,637.98 Point 0.00 1,785.26-102.63 6,012,730.00 1,636,714.91 Point 0.00 1,851.51-425.61 6,012,795.97 1,636,391.91 Point 0.00 156.39-489.93 6,011,100.97 1.636,328.99 Point 0.00 -110.81-261.11 6,010,833.99 1,636,558.01 Point 0.00 0.00 0.00 6,010,945.00 1,636,819.00 3M-28 CTD Polygon Ea: 0.00 0.00 0.00 -6,039.551,130,298.65 6,011,105.00 1,636,322.00 700 12' 23.889 N 140' 48' 29.894 W plan misses target center by 1140093.06usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Polygon Point 1 0.00 0.00 0.00 6,011,105.00 1,636,322.00 Point 0.00 575.96 132.46 6,011,681.01 1,636,453.97 Point 0.00 331.48 2,014.46 6,011,438.10 1,638,335.99 Point 0.00 -43.52 1,959.16 6,011,063.10 1,638,281.00 Point 0.00 124.66 452.14 6,011,230.02 1,636,773.99 Point 0.00 -70.31 388.98 6,011,035.02 1,636,711.00 Point 0.00 0.00 0.00 6,011.105.00 1,636,322.00 3M-28L1-01_T02 0.00 0.00 5,973.00 -5,022.601,129,264.39 6,012,121.00 1,635,287.00 70' 12' 35.283 N 140' 48' 55.120 W plan misses target center by 1139042.38usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Point 3M-281-1-03_Fault1_M 0.00 0.00 0.00 -5,768.691,130,502.90 6,011,376.00 1,636,526.00 70' 12' 26.218 N 140' 48' 22.867 W plan misses target center by 1140297.06usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Rectangle (sides W1.00 H500.00 D0.00) 3M-281-1-01_T01 0.00 0.00 6,009.00 -5,915.401,130,134.74 6,011,229.00 1,636,158.00 700 12' 25.335 N 1400 48' 34.052 W plan misses target center by 1139913.19usft at 13300.00usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Point 3M-28 CTD Polygon We 0.00 0.00 0.00 -5,949.861,130,680.77 6,011,195.00 1,636,704.00 70° 12' 24.198 N 140° 48' 18.557 W plan misses target center by 1140475.08usft at 13300.O0usft MD (6008.30 TVD,-4875.29 N,-9777.98 E) Polygon Point 1 0.00 0.00 0.00 6,011,195.00 1,636,704.00 Point 0.00 7.15-194.01 6,011,201.99 1,636,510.00 Point 0.00 188.37-457.90 6,011,382.97 1,636,245.99 Point 0.00 653.64-749.57 6,011,847.96 1,635,953.97 Point 0.00 1,057.09-1,277.31 6,012.250.93 1.635,425.95 Point 0.00 1,213.25-1,468.21 6,012.406.92 1,635,234.94 Point 0.00 925.38-1,662.45 6,012,118.92 1,635,040.96 Point 8 0.00 427.78-961.77 6,011,621.95 1,635,741.97 Point 9 0.00 -134.54-614.17 6,011,059.97 1,636,090.00 412812017 5:09:24PM Page 4 COMPASS 5000.1 Build 74 �,. ConocoPhillips RAW ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3M-28 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3M-28 @ 68.00usft (3M-28) Site: Kuparuk 3M Pad North Reference: True Well: 3M-28 Survey Calculation Method: Minimum Curvature Wellbore: 3M-2811-01 Design: 3M-28 L 1-01 _wp01 Point 10 0.00-336.93-139.27 6,010,857.99 1,636,565.02 Point 11 0.00-271.11 107.80 6,010,924.01 1,636,812.01 Point 12 0.00 0.00 0.00 6,011,195.00 1,636,704.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) ——14,850.00 5,972.80 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 13,300.00 6,008.30-4,875.29-9,777.98 TIP/KOP 13,400.00 6,005.78-4,829.65-9,866.85 Start 7 dls 13,500.00 6,008.55-4,776.08-9,951.17 3 13,570.00 6,009.45-4,732.78-10,006.14 4 13,670.00 6,007.69-4,663.47-10,078.12 5 13,950.00 5,998.54-4,429.65-10,229.38 6 14,280.00 5,988.46-4,160.13-10,415.64 7 14,550+00 5,980.81-4,008.56-10,637.48 8 14,850.00 5,972.80-3,835.84-10,880.58 Planned TD at 14850.00 412812017 5:09:24PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3M Pad Site Error: 0.00 usft Reference Well: 3M-28 Well Error: 0.00 usft Reference Wellbore 3M-281-1-01 Reference Design: 3M-28L1-01_wp01 Baker Hughes INTEQ Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3M-28 3M-28 @ 68.00usft (3M-28) 3M-28 @ 68.00usft (3M-28) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 3M-28L1-01_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 13,300.00 to 14,850.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,678.20 usft Error Surface: Elliptical Conic Survey Tool Program Date 4/28/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 76.69 12,888.02 3M-28 (3M-28) GCT-MS Schlumberger GCT multishot 12,888.02 13,300.00 3M-28L1_wp02 (3M-28L1) MWD MWD - Standard 13,300.00 14,850.00 3M-28L1-01_wp01 (3M-281-1-01) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 14,850.00 6,040.80 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3M Pad 3M-24 - 3M-24 - 3M-24 3M-24 - 3M-241_1 - 3M-241_1 3M-24 - 3M-241-1-01 - 3M-241-1-01 3M-24 - 3M-24L1-01PB1 - 3M-24L1-01PB1 3M-24 - 3M-241-1-02 - 3M-241-1-02 3M-24 - 3M-241-1-03 - 3M-241-1-03 3M-24 - 3M-241_1 PB1 - 3M-241_1 PB1 3M-24 - 3M-241_1 PB2 - 3M-241_1 PB2 3M-24 - 3M-241_1 PB3 - 3M-24L1 PB3 3M-28 - 3M-281_1 - 3M-28L1_wp02 3M-28 - 3M-281-1-02 - 3M-28L1-02_wp01 3M-28 - 3M-261-1-03 - 3M-28L1-03_wp01 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) Has BAKER HUGHES No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) 14,500.00 12,895.00 1,618.78 429.66 13,325.00 13,325.00 0.32 0.43 13,307.37 13,400.00 229,04 1.36 13,303.50 13,425.00 256.86 1.48 Out of range Out of range Out of range Out of range Out of range 1,237.00 Pass - Major Risk Out of range Out of range Out of range 0.03 Pass - Minor 1/10 228.31 Pass - Minor 1/10 256.03 Pass - Minor 1/10 Offset Design Kuparuk 3M Pad - 3M-24 - 3M-241-1-03 - 3M-241-1-03 offset site Error: 0.00 usft Survey Program: 73-GCT-MS, 12140-MWD, 12246-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) C) (usft) (usft) (") (usft) (usft) (usft) 14,450.00 6,05L59 12,725.00 6.135.27 95.25 86.70 34.76 -2.639.01 -9,666.74 2-11/16 1,671.67 423.08 1,304.69 Pass - Major Risk 14,450.00 6,051.59 12,750.00 6,130.71 95.25 86.74 34.64 -2,633.94 -9,690.79 2-11116 1,663.20 423.04 1,296.39 Pass - Major Risk 14,450.00 6,051.59 12,775.00 6,125.20 95.25 86.78 34.49 -2,629.06 -9,714.68 2-11/16 1,654.94 423.00 1,288.36 Pass- Major Risk 14,471.84 6,050.97 12,800.00 6,118.62 95.27 86.82 32.72 -2,624.30 -9,738.32 2-11116 1,646.57 425.95 1,272.67 Pass - Major Risk 14,479.40 6,050.76 12,825.00 6,110.98 95.28 86.85 31.94 -2,619.64 -9,761.66 2-11116 1,638.62 426.95 1,262.48 Pass - Major Risk 14,500.00 6,050.19 12,850.00 6,102.18 95.29 86.90 30.18 -2,614.90 -9,784.58 2-11116 1,631.32 429.71 1,248.49 Pass - Major Risk 14,500.00 6,050.19 12,875.00 6,092.29 95.29 86.94 29.86 -2,610.12 -9,807.03 2-11116 1,624.20 429.69 1,241.92 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/28/2017 1:10:39PM Page 2 COMPASS 5000.1 Build 74 W •lg_ `we lz O 2 A IL s a 0 V O C 0 0 ___- N 0 j N ' k'1 N W I � � J a, Q N' o 00 � - O N F 9 CI. O O O O o q O O O O O O O C O (ui/*n OOZ) (+)qi io U(-)u3noS 7600 7800 8000 9200 3400 3600 3800 )000 C )200 n )400 + `v a )600 )800 0000 0200 0400 0600 0800 1000 1200 � � a� w-In = aO J0 an LO O O m c N U *RM 1O y OR IC! M M M t n O N M U)c o(m oa Sri nv ]MOOI.- OC' az O tioJ O)O� cD aON cm _rn co N� m o 0 0 Cl 0 Cl 0 0 0 N J 0-)um 0 0,0 0 0 0 0 0 0 O O O O O O O C i r— Cl) N �O O)O 0 0 0 0 Cl 0 0 0 d] O O O O O O O O O m cq ' '7 t�J ll0 V jy �c �a Ml2 l-o 1= I� CO O � N rM 00 + � m m C'I O a - ca (h ;r � O) 91 0 0 0 0 0 0 r J W Up O) t i N cD O� CR Ut a0 Q O r• 1. Z �Cr a0 NM O)OM � p gggqq'Y'Yq"? J w Cn Cl)f� LL� V t0 �' a0 00 0)LO Q a0 A o] O I- a0 a0 O N M c c c c� LO In �n z c ' N M M M M O r• O O O avrnrn�nrncomrn CO LO Cl r- co Cl) v ui N N M N M M M M M LO r_( O cv�a rnmco In v; O V m cc; Ci - .--- — �- O OJT0 OM 01O)O)M 0 1+ p o 0 0 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 000000000 o oOnr-�n oo In �n M V �[J NCO Q)N �a0 O C� + CO oo — aJ co N zol 10-I Z-W£ -------- pp .-.Ea---:- N 0. O 1 1 1 1 1 1 1 1 1 I 1 1 k. 1 0 1 101 -- - Q N 9 al M 0 9 N 8 is 7 N 6. 7 V_ H 6 N 6' N 5. � 51 0 J 4: 41 3: Al O O O O O O O J lV (ui/ljsn OS) u3daQ poilian anil 250 200 150 100 050 000 950 900 850 800 750 700 550 Soo 550 )00 _ C 150 t00 p 150 i00 M 150 Q !00 U N 50 w U 00 7': 150 100 0 10 0 0 0 0 0 0 0 0 0 0 0 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: ��/a (u, PTD: - 06 ✓ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: kV&r 6l I 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. 12 4 - Q l)--, API No. 50-10�Zq -.2 9, q Irk - M - O_ , t/ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sam les are first caught and 10' sam le 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 25.07 ] (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#:2170670 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 3M-281-1-01 Program DEV Well bore seg FL./I DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025523, Surf Loc; ADL0025524, Top Prod Interv. & TD. 3 Unique well name and number Yes KRU 3M-281-1-01 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D. 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432D has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes \ 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes PKB 5/3/2017 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) 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 5/4/2017 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 5/3/2017 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 Co ission Date Conductor set in KRU 3M-28 Surface casing set in KRU 3M-28 Surface casing set and fully cemented Productive interval 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 3968 psig(13.25 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD MPSP is 3392 psig; will test BOPs to 4000 psig H2S measures required Wells on 3M-Pad are H2S-bearing. 1­12S measures required. Max. potential reservoir pressure is 13.25 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique. Onshore development lateral to be drilled.