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215-227
Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, January 10, 2018 8:14 AM To: 'Starck, Kai' Cc: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA) Subject: Expired Permits to Drill: KRU 3N-05 L1-01 and KRU 3N-05 L1-02 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 3N-05 1-1-01, PTD 215-226, Issued 6 January 2016 • KRU 3N-05 1-1-02, PTD 215-227, Issued 6 January 2016 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 01ALASKA GOVERNOR BILL WALKER D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas ,..nservation Co m o 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-05L1-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 215-227 Surface Location: 1562' FSL, 354' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 4292' FSL, 4926' FEL, SEC. 29, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 186-026, API No. 50-029- 21537-00-00. 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 � d y of January, 2016. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 DEC 23 Z015 0510--w* 1a. Type of Work: 1h. Proposed Well Class Exploratory -Gas ❑ Service - WAG ❑✓ - Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral 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 21 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc- Bond No. #BD89-2&-2:�6 s 1 KRU 3N-051-1-02 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360 Anchorage, AK 99510-0360 MD: 11095' , TVD: 6172' Kuparuk River Field / Kuparuk Oil Pool , 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1562' FSL, 354' FEL, Sec. 29, T13N, R9E, UM ADL 25521 ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1224' FSL, 3604' FEL, Sec. 29, T13N, R9E, UM ALK 2557 1/14/2016 Total Depth: 4292' FSL, 4926' FEL, Sec. 29, T13N, R9E, UM 9. Acres in Property: // q 2,�60 14. Distance to Nearest Property: 10355' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): - 67' 15. Distance to Nearest Well Open Surface: x- 518046 y- 6013799 Zone- 4 GL Elevation above MSL (ft): . 38' to Same Pool: 3N-04, 993' 16. Deviated wells: Kickoff depth: 9925' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96' degrees Downhole: 4577 psig ' Surface: 3957 psig , 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" 2.375" 4.6# L-80 STL 3495' 7600' 6159' 11095' 6172' 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): 7595' 6402' None 7482' 6318' None Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" 232 sx CS II 115' 115' Surface 3764' 9-5/8" 1070 sx PF "E" & 290 sx Class G 3764' 3599' Production 7569' 7" 300 sx Class G 7569' 6384' Perforation Depth MD (ft): 7299'-7392' Perforation Depth TVD (ft): 6183'-6231' 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 requireme n 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Keith Herring @ 263-4321 Email Keith.E.Herrin co .com Printed Name D. Venhaus Title CTD Engineering Supervisor Signature Phone 263-4372 Date 1Z—Z1-15 Commission Use Only Permit to Drill Number: t S— API Number: 50-0— a/53 — Q-00 Permit Approval Date: ` 1 See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to Other: 3 Q P fi �s f to 4 3e2c pl, 7 V i a /'J Yt ✓t v1 trr t ` d tG(ifL W/ �✓1 rS5- d /Vt (r- /.4- l ��� (�/✓d Cf �fr� S Ge �� 1 t explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Samples req'd : Yes ❑ No d Mud log req'd: Yes ❑ No ��Uf7-�S�imeasures: Yes [✓]Z No ❑ Directional svy req'd: Yes [�No❑ Spacing %9tion req'd: Yes ❑ NoW Inclination -only svy req'd: Yes ❑ No[V' Post initial injection MIT req'd: Yes ❑❑ No Approved by APPROVED BY COMMISSIONER THE COMMISSION Date: �- - V 7-44 r'Ab I v24 JCS Submit Form and Form 10-401 (Revised 11/2015) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL 'e��� Conocoo hilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 22, 2015 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad -lateral out of the KRU 3N-05 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin mid -January, 2016. The CTD objective will be to drill four laterals (3N-05L1, 3N-051_1-01, 3N-05L1-02, & 3N-051_1-03), targeting the Kuparuk A -sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3N-05L1, 3N-051_1-01, 3N-051_1-02, & 3N-051_1-03 — Detailed Summary of Operations — Directional Plans for 3N-05L1, 3N-051_1-01, 3N-051_1-02, & 3N-051_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 Kuparuk CTD Laterals NAOORS ALASRA 3N-05L1, L1-01, L1-02, & L1-03 M, l Application for Permit to Drill Document 2Rt 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))......................................................................................................................2 2. Location Summary.............................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))......................................................................................................................................................2 3. Blowout Prevention Equipment Information...................................................................................2 (Requirements of 20 AAC 25.005(c)(3))..................................................................................................................................................... 2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requirements of 20 AAC 25.005(c)(4)).....................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests.....................................................................2 (Requirements of 20 AAC 25.005(c)(5))......................................................................................................................................................2 6. Casing and Cementing Program......................................................................................................3 (Requirements of 20 AAC 25.005(c)(6))......................................................................................................................................................3 7. Diverter System Information.............................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))......................................................................................................................................................3 8. Drilling Fluids Program.....................................................................................................................3 (Requirements of 20 AAC 25.005(c)(8))...................................................................................................................................................3 9. Abnormally Pressured Formation Information...............................................................................4 (Requirements of 20 AAC 25.005(c)(9))......................................................................................................................................................4 10. Seismic Analysis................................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10))....................................................................................................................................................4 11. Seabed Condition Analysis...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11))....................................................................................................................................................4 12. Evidence of Bonding.........................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12))....................................................................................................................................................4 13. Proposed Drilling Program...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))....................................................................................................................................................4 Summaryof Operations.................................................................................................................................................. 4 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................6 (Requirements of 20 AAC 25.005(c)(14))....................................................................................................................................................6 15. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050(b))..........................................................................................................................................................7 16. Attachments.......................................................................................................................................8 Attachment 1: Directional Plans for 3N-051-1, 3N-051-1-01, 3N-05L1-02, & 3N-05L1-03................................................ 8 Attachment 2: Current Well Schematic for 3N-05........................................................................................................... 8 Attachment 3: Proposed Well Schematic for 3N-05L1, 3N-051-1-01, 3N-051-1-02, & 3N-05L1-03.................................. 8 Page 1 of 8 December 18, 2015 PTD Application: 3N-051-1, 1-1-01, L1-02 & 1-1-03. 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed laterals described in this document are 3N-051-1, 1-1-01, 1-1-02, & 1-1-03. All laterals will be classified as "Service — WAG" 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 3N-051-1, L1-01, 1-1-02, & 1-1-03. 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 CDR2-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 43p0 psi. Using the maximum formation pressure in the area of 4577 psi in 3M-13 (i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3N-05, assuming a gas gradient of 0.1 psi/ft, would be 3957 psi.' See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 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 3N-05 was measured to be 4041 psi (12.5 ppg EMW) on 11/09/2015. However the pressure is expected to decline to 11.5 ppg by the spud date. The maximum downhole pressure in the 3N- 05 vicinity is to the northwest in the 3M-13 producer at 4577 psi (14.2 ppg EMW) measured in November 2015. The lowest downhole pressure in the 3N-05 vicinity is to the north in the 3Q-22 producer at 2063 psi (6.4 ppg EMW) measure in February 2015. Due to the 3M-13 and 3Q-22 wells' being offset that high pressure is not expected during operations of drilling the 3N-05 laterals. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 3N-05 have ever injected gas, so there is a low probability of encountering free gas while drilling the 3N-05 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 3N-05 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3N-05 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 8 December 18, 2015 PTD Application: 3N-05L1, 1_1-01, L1-02 & L1-03. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Name MD MD TVDSS TVDSS Liner Details 2%", 4.7#, L-80, ST-L slotted liner; 3N-05L1 10070' 11600' 6180' 6245' openhole anchored aluminum billet on to 23/", 4.7#, L-80, ST-L slotted liner; 3N-05L1-01 9925' 11585' 6174' 6252' openhole anchored aluminum billet on to 2%", 4.7#, L-80, ST-L slotted liner; 3N-051-1-02 7600' 11095' 6159' 6172' openhole anchored aluminum billet on top 3N-05L1-03 7314' 9160' 6127' 6172' 2%" 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse si Conductor 16" 62.5 H-40 Welded 38' 115' 0' 115' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 37' 3764' 0' 3599' 3520 2020 Production 7" 26.0 J-55 BTC 35' 7569' 0' 6384' 4980 4330 Tubing 3-1/2" 9.3 L-80 EUE 8rd 33' 7239' 0' 6138' 10160 10530 Tubing Tail 5-1/2" 1 14.0 J-55 STC 7239' 7327' 1 6138' 6204, 4270 3120 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-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 CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (9.5 ppg) — Drilling operations: Chloride -based RoVis mud (9.3 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3N-05 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud Page 3 of 8 December 18, 2015 PTD Application: 3N-051-1, 1-1-01, L1-02 & 1-1-03. weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 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 3N-05 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3N-05 Window 7319' MD, 6198' TVD Using MPD Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 11.5 ) 3706 psi 3706 psi Mud Hydrostatic (9.3 p) 2997 psi 2997 psi Annular friction (i.e. ECD, 0.080 si/ft) 586 psi 0 psi Mud + ECD Combined 3583 psi 2997 psi (no choke pressure) (underbalanced (underbalanced —124psi) —709psi) Target BHP at Window 11.8 3803 psi 3803 psi Choke Pressure Required to Maintain 220 psi 806 psi Target BHP 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 3N-05 is a Kuparuk A -sand injection well equipped with 3Yz" tubing and 5 %" big tail pipe completion. Four laterals will be drilled to the northwest of the parent well with the laterals targeting the A 1, A2 and A3 sands. A thru-tubing whip -stock will be set pre -rig inside the 5Yz" tail pipe at the planned kickoff point of 7319' MD to drill all four laterals. Page 4 of 8 December 18, 2015 PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. The 3N-05L1 lateral will exit through the 5%2" tail pipe and 7" casing at 7319' MD and TD at 11600' MD, targeting the A2 sand. It will be completed with 2%" slotted liner from TD up to 10070' MD with an openhole anchored aluminum billet for kicking off the 3N-05L 1 -0 1 lateral. The 3N-05L1-01 lateral will drill northwest to a TD of 11585' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 9925' MD with an openhole anchored aluminum billet for kicking off the 3N-05L1-02 lateral. The 3N-05L1-02 lateral will drill northwest to a TD of 11095' MD targeting the A3 sand. It will be completed with 2%" slotted liner from TD up to 7600' MD with an openhole anchored aluminum billet for kicking off the 3N-05L 1-03 lateral. The 3N-05L1-03 lateral will drill northwest to a TD of 9160' MD targeting the Al sand. It will be completed with 2%" slotted liner from TD up to 7314' MD with a deployment sleeve back into the 5 ''/2" tail pipe. Pre-CTD Work 1. RU Slickline: Dummy all gas lift valves and obtain an A -sand SBHP, drift a dummy whip -stock to TD. RU E-line: Set Baker Hughes 3%2" x 5'/2" thru-tubing whip -stock at 7319' MD Perform injection test Pump degradable plug for temporary parent bore isolation Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3N-05L1 Lateral (A2 sand northwest) a. Mill 2.80" window at 7319' MD. b. Drill 3" bi-center lateral to TD of 11600' MD. c. Run 2%" slotted liner with an openhole anchored aluminum billet from TD up to 10070' MD. 3. 3N-05L1-01 Lateral (Al sand northwest) a. Kick off of the openhole anchored aluminum billet at 10070' MD. b. Drill 3" bi-center lateral to TD of 11585' MD. c. Run 2%" slotted liner from TD up to 9925' MD. 4. 3N-05L1-02 Lateral (A3 sand northwest) a. Kick off of the openhole anchored aluminum billet at 9925' MD. b. Drill 3" bi-center lateral to TD of 11095' MD. c. Run 2%" slotted liner from TD up to 7600' MD. 5. 3N-05L1-03 Lateral (Al sand northwest) a. Kickoff of the openhole anchored aluminum billet at 7600' MD. b. Drill 3" bi-center lateral to TD of 9160' MD. c. Run 2%" slotted liner from TD back into the 5 '/2" tail pipe at 7314' MD. 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Page 5 of 8 December 18, 2015 PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. Post -Rig Work 1. Pull BPV. 2. Pre -produce for less than 30 days 3. Return to injection. 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, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. 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 3N-05 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2'/" 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%" rams will provide secondary well control while running 2%" 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. (670-4200y Page 6 of 8 December 18, 2015 PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 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 Plan — 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 openhole section.,' — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3N-05L1 9863' 3N-05L1-01 9870' 3N-05L1-02 10355' 3N-05L1-03 12072' — Distance to Nearest Well within Pool Lateral Name Distance Well 3N-05L1 3N-04 932' 3N-05L1-01 3N-04 1000, 3N-05L1-02 3N-04 993' 3N-05L1-03 3N-04 1556' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There is one well within'/4-mile of the 3N-05L1, 1-1-01, L1-02, and L1-03 laterals 3N-05 (mother bore) Injector • Classified as a "Normal Well" • The well is completed with 3.5" 9.3# L-80 tubing and 7" 26# J-55 production casing. • Packer located at 7106' MD which is located less than 200' from the top of the perforations. • A -sand perforations: A3: 7299' - 7314' MD, A2: 7309' - 7342' MD, and Al: 7364' - 7392' MD • Well was recently worked over on 10-18-15, new tubing was run and a down hole deployment valve was installed. • Production casing was cemented with 300 sx of Class "G" cement. The proposed kick off point for the CTD sidetrack is in the A -sand perforations and should not compromise existing conformance. 3N-04 (Injector), —932' away from 3N-05L1, L1-01, 1-1-02, & L1-03 lateral to the east • 3N-04 is currently injecting water into the Kuparuk A, C, and Unit B sand intervals. • Classified as a "Normal Well" • Well is completed with 2.875" 6.5# L-80 tubing and 7" 26# J-55 production casing. • Packers located at 7383' and 7439' MD the lowest most which is located less than 200' from the top of the perforations. • A, C, Unit B perforations: C4/Unit B: 7574' - 7584' MD, A3: 7612' - 7622' MD, A2: 7625' - 7632' MD, and Al: 7639' - 7645' MD • Production casing was cemented with 350 sx Class 'G' and 175 sx PF 'C' Page 7 of 8 December 18, 2015 PTD Application: 3N-051-1, L1-01, L1-02 & L1-03. 17. Attachments Attachment 1: Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Attachment 2: Current Well Schematic for 3N-05 Attachment 3: Proposed Well Schematic for 3N-050, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Page 8 of 8 December 18, 2015 v W HIM we a NO .. � yt i .- r i a\ _ I i I - - z c k .... _ m 60 • 2 1J T '�&� a 33 K•A _.- r a - r I T sl o M$ 9 c4 o , Cc On E °oalr_ rr .: . v I • p � y � r _ r I' 600g < yGtg - K i - � I ros (U!/gsn OOL) (+)iluo (-)gtnoS 3 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-05 3N-05L1-02 Plan: 3N-051-1-02_wp01 Standard Planning Report 10 December, 2015 WE P ap' I BAKER HUGHES ConocoPhillips MAP aI ConocoPhillips Planning Report RAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3N Pad Well: 3N-05 Wellbore: 3N-051-1-02 Design: 3N-05L1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3N-05 Mean Sea Level 3N-05 @ 67.00usft (3N-05) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17 usft Latitude: 70° 26' 55.957 N From: Map Easting: 517,946.19usft Longitude: 149° 51' 12.938 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0,14 ° Well 3N-05 Well Position +N/-S 0.00 usft Northing: 6,013,799.48 usft Latitude: 700 26' 55.957 N +E/-W 0.00 usft Easting: 518,046.18 usft Longitude: 149° 51' 10.002 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 33.70 usft F- i Wellbore 3N-051-1-02 - Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGGM2015 3/1/2016 18.52 81.03 57,493 Design 3N-051-1-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,925.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) -33.70 0.00 0.00 345.5.00 - Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°I100ft) (°) Target 9,925.00 84.13 0.56 6,174.14 1,805.94 -4,014.05 0.00 0.00 0.00 0.00 10,115.00 95.65 353.90 6,174.50 1,995.29 -4,023.21 7.00 6.06 -3.52 -30.00 10,215.00 89.59 350.40 6,169.93 2,094.19 -4,036.85 7.00 -6.06 -3.50 -150.00 10,615.00 90.56 322.41 6,169.40 2,457.11 -4,195.37 7.00 0.24 -7.00 -88.00 11,095.00 88.81 288.86 6,172.04 2,732.78 -4,579.90 7.00 -0.37 -6.99 -93.00 1211012015 10:47:38AM Page 2 COMPASS 5000.1 Build 74 '0" ConocoPhillips MAP .. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3N Pad Well: 311-05 Well bore: 3 N-05 L 1-02 Design: 3N-05L1-02_wp01 Planned Survey Measured TVD Below Depth inclination Azimuth System (usft) (°) (°) (usft) 9,925.00 84.13 0.56 6,174.14 TIP/KOP 10,000.00 88.68 357.93 6,178.84 10,100.00 94.74 354.43 6,175.86 10,115.00 95.65 353.90 6,174.50 Start 7 dls 10,200.00 90.50 350.92 6,169.94 10,215.00 89.59 350.40 6,169.93 3 10,300.00 89.79 344.45 6,170.39 10,400.00 90.04 337.45 6,170.54 10,500.00 90.28 330.46 6,170.25 10,600.00 90.53 323.46 6,169.55 10,615.00 90.56 322.41 6,169.40 4 10,700.00 90.25 316.47 6,168.80 10,800.00 89.89 309.48 6,168.68 10,900.00 89.52 302.49 6,169.19 11,000.00 89.15 295.50 6,170.35 11, 095.00 88.81 288.86 6,172.04 Planned TD at 11095.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3N-05 Mean Sea Level 3N-05 @ 67.00usft (3N-05) True Minimum Curvature Vertical Dogleg Toolface Map Map +N/-S +El-W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 1,805.94 -4,014.05 2,783.32 0.00 0.00 6,015,595.52 514,028.17 1,880.76 -4,015.04 2,855.84 7.00 -30.10 6,015,670.33 514,027.00 1,980.43 -4,021.69 2,953.84 7.00 -29.98 6,015,769.97 514,020.11 1,995.29 -4,023.21 2,968.59 7.00 -29.98 6,015,784.83 514,018.55 2,079.39 -4,034.41 3,052.72 7.00 -149.90 6,015,868.89 514,007.15 2,094.19 -4,036.85 3,067,64 7.00 -150.00 6,015,883.68 514,004.68 2,177.11 -4,055.35 3,152.53 7.00 -88.02 6,015,966.55 513,985.98 2,271.58 -4,087.96 3,252.22 7.00 -88.01 6,016,060.93 513,953.14 2,361.37 -4,131.84 3,350.30 7.00 -87.99 6,016,150.60 513,909.05 2,445.14 -4,186.33 3,445.33 7.00 -87.98 6,016,234.24 513,854.36 2,457.11 -4,195.37 3,459.23 7.00 -88.00 6,016,246.18 513,845.30 2,521.66 -4,250.61 3,535.87 7.00 -92.98 6,016,310.59 513,789.90 2,589.79 -4,323.73 3,620.60 7.00 -92.99 6,016,378.53 513,716.63 2,648.51 -4,404.59 3,698.25 7.00 -93.01 6,016,437.05 513,635.63 2,696.95 -4,492.00 3,767.67 7.00 -93.04 6,016,485.28 513,548.12 2,732.78 -4,579.90 3,825.03 7.00 -93.06 6,016,520.90 513,460.13 12/10/2015 10:47:38AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips MGkI ConocoPhillips Planning Repoli BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 3N Pad North Reference: Well: 3N-05 Survey Calculation Method: Wellbore: 3N-05L1-02 Design: 3N-05L1-02_wp01 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Shape (1) (1) (usft) (usft) (usft) (usft) 3N-05 CTD Polygon 0.00 0.00 0.00-3,381.501,137,338.28 6,013,172.00 plan misses target center by 1141380.82usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Polygon Point 1 0.00 0.00 0.00 6,013,172.00 Point 0.00-185.28-310.47 6,012,985.99 Point 3 0.00 64.37-995.95 6,013,233.95 Point 0.00 2,197.04-1,608.96 6,015,364.92 Points 0.00 2,986.05-2,848.22 6,016,150.85 Point 6 0.00 3,958.12-2,411.87 6,017,123.87 Point 7 0.00 2,837.64-989.38 6,016.006.95 Point 0.00 1,615.78-679.24 6,014,785.97 Point 0.00 0.00 0.00 6,013,172.00 3N-051-1_Fault3 0.00 0.00 0.00-1,379.611,136,232.01 6,015,171.00 plan misses target center by 1140267.23usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-05L1_Fault4 0.00 0.00 0.00-305.961,135,592.55 6,016,243.00 plan misses target center by 1139625.28usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-05L1_FauIt1N 0.00 0.00 0.00-3,163.071,136,756.75 6,013,389.00 plan misses target center by 1140798.33usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-051-1-02_T03 0.00 0.00 6,172.00-268.911,135,575.63 6,016,280.00 plan misses target center by 1139591.58usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-05L1_Fault1S 0.00 0.00 0.00-3,400.861,137,074.21 6,013,152.00 plan misses target center by 1141116.84usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-051-1-027T02 0.00 0.00 6,170.00-543.551,135,827.00 6,016,006.00 plan misses target center by 1139843.47usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-05L1_Fault2 0.00 0.00 0.00-1,933.921,136,332.68 6,014,617.00 plan misses target center by 1140369.58usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point 3N-05L1-02_T01 0.00 0.00 6,170.00-885.181.136,072.19 6,015,665.00 plan misses target center by 1140089.42usft at 9925.00usft MD (6174.14 TVD, 1805.94 N,-4014.05 E) Point Casing Points Well 3N-05 Mean Sea Level 3N-05 @ 67.00usft (3N-05) True Minimum Curvature Easting (usft) Latitude Longitude 1,655,276.00 70° 12' 15.702 N 140' 39' 17.896 W 1,655,276.00 1, 654, 966.01 1,654,280.00 1, 653, 661.89 1,652,420.84 1,652,854.79 1,654,279.85 1,654,592.92 1,655,276.00 1,654,165.00 70' 12' 36.772 N 140' 39' 40.853 W 1,653,523.00 70° 12' 48.141 N 140° 39' 54.493 W 1,654,694.00 70' 12' 18.682 N 140' 39' 33.600 W 1,653.506.00 70° 12' 48.525 N 140' 39' 54.816 W 1,655,012.00 700 12' 15.904 N 140° 39' 25.544 W 1,653,758.00 70° 12' 45.488 N 140' 39' 48.811 W 1,654,267.00 70' 12' 31.242 N 140° 39' 40.387 W 1,654,004.00 70' 12' 41.809 N 140° 39' 43.275 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,095,00 6,172.04 23/8" 2.375 3.000 1211012015 10:47:38AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips rigs ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3N Pad Well: 3N-05 Wellbore: 3N-051-1-02 Design: 3 N-05 L 1-02_wp 01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3N-05 Mean Sea Level 3N-05 @ 67 00usft (3N-05) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E/-W (usft) (usft) (usft) (usft) Comment 9,925.00 6,174.14 1,805.94 -4,014.05 TIP/KOP 10,115.00 6,174.50 1,995.29 -4,023.21 Start 7dls 10,215.00 6,169.93 2,094.19 -4,036+85 3 10,615.00 6,169.40 2,457.11 -4,195+37 4 11,095.00 6,172.04 2,732.78 -4,579.90 Planned TD at 11095.00 1211012015 10:47:38AM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips iias ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3N Pad Site Error: 0.00 usft Reference Well: 3N-05 Well Error: 0.00 usft Reference Wellbore 3N-051-1-02 Reference Design: 3N-05L1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3N-05 3N-05 @ 67.00usft (3N-05) 3N-05 @ 67.00usft (3N-05) True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Reference 3N-05L1-02_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: 9,925.00 to 11,095.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,306.17 usft Error Surface: Elliptical Conic Survey Tool Program Date 12110/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 7,310.00 3N-05 (3N-05) GCT-MS Schlumberger GCT multishot 7,310.00 9,925.00 3N-05L1_wp02 (3N-051-1) MWD MWD - Standard 9,925.00 11,095.00 3N-05L1-02_wp01 (31\1-051-1-02) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,095.00 6,239,04 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 3N Pad 3N-04 - 3N-04 - 3N-04 3N-05 - 3N-05L1 - 3N-05L1_wp03 3N-05 - 3N-05L1-01 - 3N-05L1-01_wp01 3N-07 - 3N-07 - 3N-07 3N-07 - 3N-07A - 3N-07A 3N-07 - 3N-07AL1 - 3N-07AL1 3N-07 - 3N-07AL1-01 - 3N-07AL1-01 3N-07 - 3N-07AL1-02 - 3N-07AL1-02 3N-07 - 3N-07AL1-03 - 3N-07AL1-03 3N-07 - 3N-07AL2 - 3N-07AL2 3N-07 - 3N-07AL2-01 - 3N-07AL2-01 3N-07 - 3N-07AL2-02 - 3N-07AL2-02 3N-07 - 3N-07AL2-03 - 3N-07AL2-03 3N-09 - 3N-09 - 3N-09 3N-11 - 3N-11 - 3N-11 3N-11 - 3N-11A- 3N-11A 3N-11 - 3N-11AL1 - 3N-11AL1 3N-11 - 3N-11AL2 - 3N-11AL2 3N-11 - 3N-11 AL2-01 - 3N-11 AL2-01 3N-11 - 3N-11AL3 - 3N-11AL3 3N-13 - 3N-13 - 3N-13 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 10,300.00 7.825.00 993.77 291.38 714.76 Pass - Major Risk 10,498.10 10,500.00 12.86 0.35 12.64 Pass - Minor 1/10 9,950.00 9,950.00 0.19 0.84 -0.56 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 Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1211012015 9:31:28AM Page 2 COMPASS 5000.1 Build 74 �Y z 4 z F c z� � ' Y z m 0 4 z Y M m M (uisn OS£) (+)91ioN/(-)9znoS m � C,4 mo 0 0 - O 0 0 m C A n o a � O r � E QH 4JM V d V N T V �cN M t�94-JmN O N a z > - - - - N N N m� Imp JJ U i O O O O O 91 Z M cD N F i ai0 0 0 0 0 oo 000 o N m m rn v c+i��ai 0 0 4 Nco q?V 4V0 UJ J O W V G /) W + m rn N v N p N J wcna rn v o ?] Ol OJ c� C] V V O) O] N rrco co r Z M rn v v m O C6 c:;N m U �2 Q O — _ m m w O } p 0 0 0 0 0 0 0 0 0 0 rn o 0 0 o N zi z 4 w z z + oz Eoj zo-t So -NE 3 z0 z0-1 90-N� 101 zo-I S0-N£ - Y Q� F Y m r] 4 µl M 4 h z z (ut/Ijsn OSI) gldaQ leo[yan o-,L JjW KUP INJ 3N-05 ConocoPhIIIIps Well Attributes Max Angle & MD JTD Alaska. if1C. WeIlbore API/UWI Fiaid Name Wei lbore Status Ind (') MD (ftKB) 500292153700 KUPARUK RIVER UNIT INJ 44.90 6,400.00 Act Btm (kKB) 7,601.0 Comment H2S (ppm) Dale SSSV: NONE Annotation End Dale KB-Grd Last WO: 10/17/2015 (ft) Rig Releasa Date 38.49 2/22/1986 3N-05, 11/22/2015336:27 PM Vertical schematic acNal Annotation Depth (ftKB) Entl Dale Annotation Last Mod By nd D Eate ___.._..... HANGER;32.7- Last Tag: SLM 7,452.0 10/25/2015 Rev Reason: GLV C/O pproven 11/22/2015 Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Tap Thread SURFACE 9 5/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC Tubing Strings Tubing Description Strng Ma... ID (in) Top (ftKB)Set Depth (ft.. Set Depth (TVD) (... Wt (Ibkt) Gratle Top Connection TUBING - WO 2015 3 1!2 2.992 32,7 7, 120.0 6,050.9 9.30 L-80 EUE 8rd CONDUCT438.0-115.0-UPPER COMPLETION Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com Nominal ID (in) GAS LIFT; 2,505 ] 32.7 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6 4,150.8 42.50 OT Safety Baker Orbit valve 2.890 Valve 4500 7,097.8 6,034.6 42.84 XO Enlarging 3.5 EUE Box 4.51BT pin 2.960 7,098.3 6,034.9 42.84 Locator Locatersub 2.960 SURFACE; 37.0-3.764.3- 7,099.0 6,035.5 42.83 SEAL ASSY Baker80/40 seal assembly 21 ft 2.960 Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibtt) Grade TUBING WO 2015- 3112 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd GAS LIFT; 4,039.E LOWER PACKER IT.pC.n.ection COMPLETION Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl I') It.. Des Com Nominal ID (in) OT Safety valve, 4,509.E 7,106.1 6,040.7 42,81 PACKER Baker F packer 5.380 7,109.4 6,043.1 42.79 SEE Seal bore ext. 80-00 4.000 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple, PXX PLUG PULLED 10 25 15 2.812 7,239.2 6,138.7 42.35 Liner 5.5 X 14# J-55 W 6" wear soxs 5.000 GAS LIFT, 5,318 6 7,282.9 6,171.0 42.24 Liner 55 X 14# J-55 W 6" wear soxs mule shoe 5.000 Perforations & Slots Shot Dens Top (TVD) Btm (TVD) (shotsk GAS LIFT; 6 353 6 Top (ftKB) Ban (ftKB) (kKB) (ftKB) Zone Date t) Type Co. 7,299.0 7,314.0 6,183.0 6,194.1 A-3, 3N-05 6/28/1987 8.0 RPERF 2 118" EnerJet; 60 deg. ph 7,309.0 7,310.0 6,190.4 6,191.1 A-2, 3N-05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph GAS LIFT. 7,0420 7,324.0 7,342.0 6,201.5 6,214.8 A-2, 3N-05 6/28/1987 8.0 RPERF 2 1/8" EnerJet; 60 deg. ph 7,334.0 7,335.0 6,208.9 6,209.7 A-2, 3N-05 4/21/1986 1.0 IPERF 4" Csg Gun HJ II' 90 deg. ph 7,337.0 7,342.0 6,211.1 6,214.8 A-2, 3N-05 4/21/1986 1.0 IPERF 4" Csg Gun HJ 11' 90 XO Enlarging; 7, 097 B deg. ph Locator, 7,098.3 7,364.0 7,392.0 6,231.2 6,2520 A-1, 311-05 4/21/1986 4.0 IPERF 4" Csg Gun HJ II; 90 deg.phase PACKER; 7.106.1 Mandrel Inserts SEAL ASSY; 7,099.0 St SBE: 7,1094 ali xo Reducing (Tubing); 7,12e.e on N Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Se, Valve Type Latch Type Port Size TRO (in) (psi) Run Run Date Co. 1 2,505.7 2,502.3 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 1,348.0 10/10/2015 2 4,039.6 3,804.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,307.0 10/10/2015 3 5,318.E 4,748.9 1 Camco I MMG 1 1 1/2 GAS LIFT GLV RK 0.188 1,284.0 10/10/2015 4 6,353.E 5,499.8 CarricoMMG 1 1/2 GAS LIFT GLV RK 0.188 1,264.0 10/10/2015 NIPPLE; 7,2264 5 7,042.0 5,993.8 1 Camco I MMG 1 1 1/2 GAS LIFT OV RK 1 0.250 0.0 10/25/2015 Notes: General & Safety XO Enlargirg (Tubing); 7,238.2 End Dale Annotation 11/5/2010 NOTE: View Schematic wl Alaska Schematic9.0 Liner; 7,239 2 10/1712015 NOTE: Orbit Valve is NOT a safety valve, it does not fail to closed position. 10/17/2015 NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. Liner; 7,282.8 RPERF; ] 299 0-7,314.0 IPERF; 7,309.0-7,310.0- RPERF; 7,324.0-7,342.0� IPERF; 7,334.0-7,335.0-� IPERF; 7,337.0-7,3420 IPERF; 7,364.0-7,392.0� PRODUCTION; 35.0-7,569.1 c.i E U cn 0 i- U 0 0- 0 L a LO Q M 06 a N o M Cfl E c m E 0] N _ Y M LO U O U N N CE c M an o d o j �n N d Y � in m C N a-N Q U Q co�' N po co O M (` � cn a)M O U i a).Q- c 70 'D � O CD Y N 00 O C (OE ti � R N � M E o0 <O — co Y N N ~ o -0 E m p) C9 m _ m t` OU CD7 N N C-4 J Y00 E CO N O- Q N m Lo of U O o X o X M (V o CV Z � N O) � V Z N N CV C14 co M M� N d co co Cl) ❑ H� I II I II I II I II I II I II I II I II I II I II I II I II I II I II 1 II 1 II 1 II l II � II I � � I II 11 11 II /I /I i i i ❑p 2g m `n LQ m � O) r pO Z> O 0O O: ca a� u � 3 (D c a) C CLo ❑ `n v ��(0 ° - L M aM N L ❑ CVO �L �� C. N Mfn O O O N NN O yCO co10 CO L Q I� M a) n N r ,� a a L TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development ,Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 21\ POOL: Uz-_r KA,v6.r 61 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER / MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. API No. 50-06�9- a% S37- - ©0 - M . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2152270 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 3N-051-1-02 Program SER Well bore seg r� SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025521, entire wellbore 3 Unique well name and number Yes KRU 3N-05L1-02 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432C. 5 Well located proper distance from drilling unit boundary Yes CO 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432C 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 Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 12/29/2015 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 Yes AIO 2C-Kuparuk River Unit 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 3N-05, 3N-04, 3N-05L1, 3N-05L1-01 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) Yes Pre -produce for less than 30 days. 18 Conductor string provided NA Conductor set in KRU 3N-05 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 3N-05 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has stell tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pres is 4577 psi(14.2 ppg EMW); will drill w/ 9.3 ppg EMW and maintain overbal w/ MPD VTL 1/4/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3957 psig; will test BOPS to 4300 psig 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 112S measures required 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete; no mechanical/cementing issues 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 3N-Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Max. potential reservoir pressure is 14.2 ppg EMW; will be drilled using 9.3 ppg mud and MPD technique. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 12/29/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore service lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner Date Commissioner Date
