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Home My WebLink About216-079Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Tuesday, June 12, 2018 1:53 PM To: Phillips, Ron L; 'Starck, Kai' Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA) Subject: 216-026 KRU 2K-25 L1-02 and 216-079 KRU 1 L-24A L1-01: Permits Expired Hello Ron and Kai, On February 17, 2018, the permit for KRU 2K-25 L1-02 expired under Regulation 20 AAC 25.005 (g). On June 9, 2018, the permit for KRU 1L-24A L1-01 expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC database. 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 of LASKA GOVERNOR BILL WALKER Jason Burke Senior CTD Engineer 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.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 L-24AL 1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-079 Surface Location: 567' FNL, 143' FEL, Sec. 31, TI IN, RI OE, UM Bottomhole Location: 4660' FNL, 2276' FEL, Sec. 31, TI IN, RI OE, UM Dear Mr. Burke: 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. 216-049, API No. 50-029- 22170-01-00. 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 P. Foerster Chair DATED this` -day of June, 2016. STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM PERMIT TO DRILL ECEIVED DN JUN 0 6 ?01S 20 AAC 25.005 1 a. Type of Work: Drill ❑ ,Lateral Redrill ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas Stratigraphic Test ❑ Development - Oil Exploratory - Oil ❑ Development - Gas ❑ Service - WAG ❑ Service - Disp ❑ ❑✓ Service- Winj ❑ Single Zone [21 - ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. • 5. Bond: Blanket - Single Well ❑ Bond No. 5952180 . 11. Well Name and Number: KRU 1L-24AL1-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11750' TVD: 5981' . 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 567' FNL, 143' FEL, Sec 31, T11N, RI OE, UM Top of Productive Horizon: 1601' FNL, 1409' FEL, Sec 6, T10N, R10E, UM Total Depth: 4660' FNL, 2276' FEL, Sec 31, T11 N, R10E, UM 7. Property Designation (Lease Number): v14tl ADL 25664 S 8. Land Use Permit: ALK 473 13. Approximate Spud Date: 6/10/2016 9. Acres in Property: 2501 pt 14. Distance to Nearest Property: 11100, 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 539924 y- 5948401 Zone- 4 10. KB Elevation above MSL (ft): 130' GL Elevation above MSL (ft): 43' 15. Distance to Nearest Well Open Ito Same Pool: 1 L-13, 730' 16. Deviated wells: Kickoff depth: 9288 feet Maximum Hole Angle: 93 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4266 ( Surface: 3661 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.6# L-80 STL 2770' 8980' 5965' 11750' 5981' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 9241' Total Depth TVD (ft): 6287' Plugs (measured): None Effect. Depth MD (ft): 9155' Effect. Depth TVD (ft): 6232' Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor 78' 16" 235 sx AS 1 122' 122' Surface 5038' 9-5/8" 750 sx Type E, 550 sx Class G 5081' 3610' Production 9213' 7' 250 sx Class G Prem 9241' 6287' Perforation Depth MD (ft): 8735'-8782' / 8920'-8949' / 9010'-9029' Perforation Depth TVD (ft): 5966'-5996' / 6084'-6102' / 6141'-6153' 20. Attachments: Property Plat BOP Sketch Diverter Sketch Drilling Program 0 Time v. Depth Plot Shallow Hazard Analysis Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 re uir ents 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.Herring(d_)cop.com Printed Name Jason Burke Title Senior CTD Engineer Sign ure Phone 265-6097 Date Commission Use Only Permit t rill Number: Q 1 G — ( API Number: 50- 0 — ' QQ Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: P t C S yo ¢D �� Samples req'd: Yes ❑ No l Mud log req'd: Yes ❑ No U �-S H2S measures: Yes [� No ❑ Directional svy req'd: Yes Y No ❑ �t �� -� ��,� zso� S� d V( p ing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes ❑ No P APPROVED BY �— Approved by:(�& COMMISSIONER THE COMMISSION Date "d Submit Form and N-1-GI-N-A Form 10-401 (R vised 11/2015)L nths from the date of.ap royal (20 AAC 25.005(g)) Attachments in Duplicate � /�7�,6 � ConocoPhilli s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 6, 2016 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: COVED JUN 0 6 2016 AOGCC ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill two additional laterals out of the Kuparuk Well 1 L-24 using the coiled tubing drilling rig, Nabors CDR2-AC.JThe work is scheduled to begin as early as June 10, 2016. The CTD objective will be to drill the 1 L-24A sidetrack (PTD 216-049), 1 L-24AL1 lateral (PTD 216-050), 1 L-24AL1-01 lateral, and 1 L-24AL1 02 lateral targeting the Kuparuk A5-sand interval. Attached to this application are the following documents: — Permit to Drill Application Form (10-401) for 1L-24AL1-01, and 1L-24AL1-02 — Detailed Summary of Operations — Directional Plans for 1L-24AL1-01 & 1L-24AL1-02 — 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 NABOBSALASKA 1 L-24A, 1 L-24AL1, 1 L-24AL1-01, & 1 L-24AL1-02 Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)).............................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 1 L-24A, 1 L-24AL1, 1 L-24AL1-01, & 1 L-24AL1-02..................................................7 Attachment 2: Current Well Schematic for 1 L-24............................................................................................................7 Attachment 3: Proposed Well Schematic for 1 L-24A, 1 L-24AL1, 1 L-24AL1-01, & 1 L-24AL1-02....................................7 Page 1 of 7 June 6, 2016 PTD Application: 1 L-24A, 1 L-24AL 1, 1 L-24AL1-01, & 1 L-24ALl -02 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 1 L-24A, 1 L-24AL1, 1 L-24AL1-01, & 1 L-24AL1-02. 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 1 L-24A, 1 L-24AL1, 1 L-24AL1-01, & 1 L-24AL1-02. 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 4,000 psi. Using the maximum formation pressure in the area of 4,266 psi in 2E-05 (i.e. 13.4 ppg EMW), the maximum potential surface pressure in 1L-24, assuming a gas gradient of 0.1 psi/ft, would be 3,661 psi. ✓See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 L-24 was measured to be 2,743 psi (8.7 ppg EMW) on 3/31/2016. The maximum downhole pressure in the 1 L-24 vicinity is to the south in the 2E-05 injector at 4,266 psi (13.4 ppg EMW) from May of 2016. The 1 L-24A sidetrack will be drilled southeast across a N-S fault that could encounter formation pressure as high as 10.6 ppg, which is what was measured in 1 L-26A in June of 2012. The 1 L-24AL1 lateral will be drilled to the northwest towards a formation pressure of 9.4 ppg, which is what was measured in 1 L-15 in April of 2015. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 1 L pad have injected gas, so there is a chance of encountering free gas while drilling the 1 L-24 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1 L-24 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 L-24 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 June 6, 2016 PTDApplication: 1L-24A, 1L-24AL1, 1L-24AL1-01, & 1L-24AL1-02 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 1 L-24A 8970' 13400' 5964' 6014` 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1L-24AL1 9288' 11750' 5969' 5978' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on to 1 L-24AL1-01 8980' 11750' 5965' 5981 ` 2-3/8", 4.7#, L-80, ST-L slotted liner, aluminum billet on top 1L-24AL1-02 8640' 13400' 5775' 6014' 2-3/8", 4.7#, L-80, ST-L slotted liner; deployment sleeve on to 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' 122' 0' 122' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 5081' 0' 3610' 3520 2220 Production 7" 26.0 J-55 BTC-MOD 0' 9241' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 0 8655' 0 5914' 10160 10530 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 f — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloVis mud (8.6 ppg).r 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 11.8 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 1 L-24 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. Page 3 of 7 June 6, 2016 PTD Application: 1L-24A, 1L-24AL1, 1L-24AL1-01, & 1L-24AL1-02 Pressure at the 1L-24 Window (8875' MD, 6055' TVD) Using MPD Pumps On (1.5 b m) Pumps Off A -sand Formation Pressure 8.7 2743 psi 2743 psi Mud Hydrostatic (8.6 ) 2708 psi 2708 psi Annular friction i.e. ECD, 0.090 psi/ft 799 psi 0 psi Mud + ECD Combined no chokepressure) 3507 psi (overbalanced -764psi) 2708 psi underbalanced -35 si Target BHP at Window (11.8 ) 3716 psi 3716 psi Choke Pressure Required to Maintain Target BHP 209 psi 1008 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 KRU well 1 L-24 is a Kuparuk A -sand and C-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the A5 sand to the southeast and northwest of 1 L-24. The laterals will be supported by injectors 1 L-18 and 2E-05. Prior to CTD operations, E-line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 8621' MD will be milled out to a 2.80" ID. The existing A -sand and C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8905' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 8875' MD. The window will be milled at 8875' MD to drill and complete the 1 L-24A, 1 L-24AL l, 1 L-24AL 1-01. & 1 L- 24AL 1-02 laterals. The 1 L-24A southeastern sidetrack will exit the cement pilot hole at 8875' MD and TD at 13400' MD, targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8970'MD with an aluminum billet for kicking off the 1L-24AL1. The 1 L-24ALI lateral will drill to the northwest to a TD of 11750' MD targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 9288' MD with an aluminum billet for kicking off the 1 L-24AL1-01. Page 4 of 7 June 6, 2016 PTD Application: 1 L-24A, 1 L-24AL 1, 1 L-24AL1-01, & 1 L-24AL1-02 The l L-24AL1-01 lateral will drill to the northwest to a TD of 11750' MD targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8980' MD with an aluminum billet for kicking off the 1 L-24AL 1-02. The 1 L-24AL1-02 lateral will drill to the southeast to a TD of 13400' MD targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8640' MD, back into the 3-1/2" tubing tail with a deployment sleeve. Pre-CTD Work 1. RU Slickline: Obtain SBfIP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3-1/2" tubing tail at 8626' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the A -sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Ria Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. IL-24A Sidetrack (A5 sand - Southeast) a. Drill 2.80" high -side pilot hole through cement to 8905' MD b. Caliper pilot hole c. Set top of whipstock at 8875' MD d. Mill 2.80" window at 8875' MD. e. Drill 3" bi-center lateral to TD of 13400' MD. f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8970' MD. 1 L-24AL 1 Lateral (A5 sand -Northwest) a. Kick off of the aluminum billet at 8970' MD. b. Drill 3" bi-center lateral to TD of 11750' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9288' MD. 4. 1 L-24AL 1 -0 1 Lateral (A5 sand - Northwest) a. Kick off of the aluminum billet at 9288' MD. b. Drill 3" bi-center lateral to TD of 11750' MD. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8980' MD. 1 L-24AL 1-02 Lateral (A5 sand - Southeast) a. Kick off of the aluminum billet at 8980' MD. b. Drill 3" bi-center lateral to TD of 13400' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 8640' MD. 6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV. 2. Obtain SBUP. 3. Install gas lift design. 4. Return to production. Page 5 of 7 June 6, 2016 r3TD Application: 1 L-24A, 1 L-24AL ,, 1 L-24AL1-01, & 1 L-24AL1-02 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 1 L-24 laterals will be displaced to an overbalancing fluid (11.8 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 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 L-24A 7440' 1 L-24AL1 11100, 1 L-24AL1-01 11100' 1L-24AL1-02 7440' Page 6 of 7 June 6, 2016 r3TD Application: 1 L-24A, 1 L-24AL , 1 L-24AL1-01, & 1 L-24AL1-02 — Distance to Nearest Well within Pool Lateral Name Distance Well 1 L-24A 96' 1 L-25A 1 L-24AL1 730' 1 L-13 1 L-24AL1-01 730' 1 L-13 1 L-24AL1-02 116' 1 L-25A 16. Attachments Attachment 1: Directional Plans for 1 L-24A, 1 L-24AL 1, 1 L-24AL 1-01, & 1 L-24AL 1-02 laterals Attachment 2: Current Well Schematic for 1 L-24 Attachment 3: Proposed Well Schematic for 1 L-24A, 1 L-24AL 1, 1 L-24AL 1-01, & 1 L-24AL 1-02 laterals Page 7 of 7 June 6, 2016 ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-24 1 L-24A L 1-01 Plan: 1 L-24AL1-01_wp01 Standard Planning Report 06 June, 2016 BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-24 Wellbore: 1 L-24AL1-01 Design: 1 L-24AL1-01_wp01 ConocoPhillips i HAM Planning Report BAKER HUGHES Local Co-ordinate Reference: Well 1L-24 TVD Reference: Mean Sea Level MD Reference: 1 L-24 @ 130.00usft (1 L-24) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 L Pad Site Position: Northing: 5,949,190.90usft Latitude: 70° 16' 19.650 N From: Map Easting: 539,916.78 usft Longitude: 149° 40' 37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1 L-24 Well Position +N/-S 0.00 usft Northing: 5,948,401.14 usft Latitude: 70° 16' 11.882 N +E/-W 0.00 usft Easting: 539,924.95 usft Longitude: 149° 40' 37.648 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 L-24AL1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2015 6/1/2016 18.44 80.93 57,493 Design IL-24AL1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,288.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 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) (°) (°) (usft) (usft) (usft) (°1100ft) loll 00ft) (°/100ft) (°) Target 9,288.00 89.91 299.32 5,968.91 -6,313.67 -1,244.17 0.00 0.00 0.00 0.00 9,448.00 89.91 310.52 5,969.15 -6,222.24 -1,375.16 7.00 0.00 7.00 90.00 9,648.00 86.29 324.05 5,975.77 -6,075.76 -1,510.44 7.00 -1.81 6.78 105.00 9,848.00 89.91 337.58 5,982.39 -5,901.67 -1,607.66 7.00 1.81 6.76 75.00 10,148.00 89.91 358.58 5,982.84 -5,609.78 -1,669.27 7.00 0.00 7.00 90.00 10,328.00 89.91 345.98 5,983.11 -5,431.77 -1,693.40 7.00 0.00 -7.00 -90.00 10,528.00 88.94 332.01 5,985.11 -5,245.53 -1,764.90 7.00 -0.49 -6.98 -94.00 10,828.00 88.21 353.01 5,992.58 -4,961.09 -1,854.53 7.00 -0.24 7.00 92.00 11,028.00 89.43 339.06 5,996.72 -4,767.53 -1,902.67 7.00 0.61 -6.97 -85.00 11,208.00 90.09 326.47 5,997.49 -4,607.81 -1,984.88 7.00 0.37 -6.99 -87.00 11,750.00 93.39 4.29 5,981.04 -4,093.15 -2,119.20 7.00 0.61 6.99 85.00 6/6/2016 10:13:19AM Page 2 COMPASS 5000 1 Build 74 ConocoPhillips [GhI ConocoPhillips Planning Report BAKER HUGHES Database: Company: Project: Site: Well: Wellbore: Design: EDM Alaska NSK Sandbox ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-24 1 L-24AL1-01 1 L-24AL1-01_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 L-24 Mean Sea Level 1 L-24 @ 130.00usft (1 L-24) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 9,288.00 89.91 299.32 5,968.91 -6,313.67 -1,244.17 -4,845.72 0.00 0.00 5,942,081.58 538,714.41 TIP/KOP 9,300.00 89.91 300.16 5,968.93 -6,307.72 -1,254.59 -4,835.35 7.00 90.00 5,942,087.47 538,703.96 9,400.00 89.91 307.16 5,969.08 -6.252.33 -1,337.77 -4,745.79 7.00 90.01 5,942,142.41 538,620.49 9,448.00 89.91 310.52 5,969.15 -6,222.24 -1,375.16 -4,701.04 7.00 90.00 5,942,172.31 538,582.95 Start DLS 7.00 9,500.00 88.97 314.03 5,969.66 -6,187.27 -1,413.63 -4,651.52 7.00 105.01 5,942,207.07 538,544.30 9,600.00 87.16 320.80 5.973.03 -6,113.73 -1,481.22 -4,554.04 7.00 105.10 5,942,280.24 538,476.33 9,648.00 86.29 324.05 5,975.77 -6,075.76 -1,510.44 -4.506.54 7.00 105.09 5,942,318.05 538,446.91 3 9,700.00 87.23 327.57 5,978.71 -6,032.82 -1,539.61 -4,454.77 7.00 75.10 5,942,360.83 538,417.51 9,800.00 89.05 334.33 5,981.96 -5,945.50 -1,588.10 -4,354.90 7.00 75.13 5,942,447.89 538,368.56 9,848.00 89.91 337.58 5,982.39 -5,901.67 -1,607.66 -4,307.17 7.00 75.02 5,942,491.61 538,348.78 4 9,900.00 89.91 341.22 5,982.47 -5,853.00 -1,625.95 -4,255.88 7.00 90.00 5,942,540.17 538,330.23 10,000.00 89.91 348.22 5,982.62 -5,756.60 -1,652.28 -4,159.22 7.00 90.01 5,942,636.42 538,303.39 10,100.00 89.91 355.22 5,982.77 -5,657.70 -1,666.67 -4,066.38 7.00 90.01 5,942.735.23 538,288.47 10,148.00 89.91 358.58 5,982.84 -5,609.78 -1,669.27 -4,023.58 7.00 90.00 5,942,783.14 538,285.62 5 10,200.00 89.91 354.94 5,982.92 -5,557.87 -1,672.21 -3,977.15 7.00 -90.00 5,942,835.02 538,282.41 10,300.00 89.91 347.94 5,983.06 -5,459.05 -1,687.08 -3,884.13 7.00 -90.01 5,942,933.76 538,267.01 10,328.00 89.91 345.98 5,983.11 -5,431.77 -1,693.40 -3,857.35 7.00 -90.00 5,942,961.00 538,260.55 6 10,400.00 89.56 340.95 5,983.43 -5,362.77 -1,713.88 -3,787.36 7.00 -94.01 5,943,029.88 538,239.71 10,500.00 89.07 333.97 5,984.62 -5,270.47 -1,752.18 -3,688.27 7.00 -94.04 5,943,121.97 538,200.92 10,528.00 88.94 332.01 5,985.11 -5.245.53 -1,764.90 -3,660.31 7.00 -94.02 5,943,146.84 538,188.07 7 10,600.00 88.76 337.05 5,986.55 -5,180.56 -1,795.84 -3,588.58 7.00 92.05 5,943,211.64 538,156.79 10,700.00 88.52 344.05 5,988.93 -5,086.35 -1,829.11 -3,490.36 7.00 92.08 5,943,305.66 538,123.03 10,800.00 88.27 351.05 5,991.72 -4,988.80 -1,850.65 -3,395.11 7.00 92.09 5,943,403.08 538,100.97 10,828.00 88.21 353.01 5,992.58 -4,961.09 -1,854.53 -3,369.17 7.00 92.03 5,943,430.77 538,096.94 8 10,900.00 88.65 347.99 5,994.56 -4,890.13 -1,866.41 -3,301.77 7.00 -85.07 5,943,501.66 538,084.69 11,000.00 89.26 341.01 5,996.40 -4,793.84 -1,893.11 -3,205.03 7.00 -85.07 5,943,597.80 538,057.47 11,028.00 89.43 339.06 5,996.72 -4,767.53 -1,902.67 -3,177.46 7.00 -85.01 5,943,624.06 538,047.78 9 11,100.00 89.69 334.02 5,997.27 -4,701.50 -1,931.33 -3,105.96 7.00 -87.02 5,943,689.92 538,018.78 11,200.00 90.06 327.03 5,997.50 -4,614.50 -1,980.49 -3,006.02 7.00 -87.01 5,943,776.66 537,969.15 11,208.00 90.09 326.47 5,997.49 -4,607.81 -1,984.88 -2,998.04 7.00 -87.00 5,943,783.32 537,964.73 10 11,300.00 90.65 332.89 5,996.90 -4,528.43 -2,031.29 -2,906.09 7.00 84.98 5,943,862.44 537,917.90 11,400.00 91.26 339.86 5,995.24 -4,436.88 -2,071.33 -2,806.78 7.00 84.95 5,943,953.77 537,877.38 11,500.00 91.87 346.84 5,992.51 -4,341.17 -2,099.95 -2,709.58 7.00 84.91 5,944,049.32 537,848.26 11,600.00 92.48 353.82 5,988.72 -4,242.72 -2,116.73 -2,615.94 7.00 84.88 5,944,147.67 537,830.96 11,700.00 93.09 0.80 5,983.87 -4,143.01 -2,121.42 -2,527.24 7.00 84.84 5,944,247.34 537,825.75 11,750.00 93.39 4.29 5,981.04 -4,093.15 -2,119.20 -2,485.17 7.00 84.90 5,944,297.21 537,827.70 Planned TD at 11750.00 6/6/2016 10:13:19AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips F>LI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-24 Wellbore: 1 L-24AL1-01 Design: 1 L-24AL1-01_wp01 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 L-24 Mean Sea Level 1 L-24 @ 130.00usft (1 L-24) True Minimum Curvature Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude Interp @ 5981.04 (1 L-24 0.00 0.00 5,981.04 -10,390.061,138,006.98 5,944,048.21 plan misses target center by 1139258.44usft at 9288.00usft MD (5968.91 TVD,-6313.67 N,-1244.17 E) Point 1L-24 CTD Polygon Sou 0.00 0.00 0.00 -12,380.441,138,940.24 5.942,063.00 plan misses target center by 1140216.17usft at 9288.00usft MD (5968.91 TVD,-6313.67 N,-1244.17 E) Polygon Point 1 0.00 0.00 0.00 5,942,063.00 Point 2 0.00 -44.05 388.81 5,942,021.02 Point 0.00 -183.24 423.08 5,941,882.02 Point 0.00 -406.86 726.94 5,941,660.04 Point 0.00 -646.46 1,406.76 5,941,424.07 Point 6 0.00 -816.03 1,891.93 5,941,257.10 Point 7 0.00 -1,439.41 2,902.76 5,940,639.15 Point 8 0.00 -2,063.52 4,052.61 5,940,021.21 Point 0.00 -2,182.62 4,260.01 5,939,903.22 Point 10 0.00 -2,514.67 4,071.25 5,939,570.21 Point 11 0.00 -2,437.67 3,883.63 5,939,646.20 Point 12 0.00 -1,813.64 2,747.78 5,940,264.14 Point 13 0.00 -1,176.37 1,758.02 5,940,896.09 Point 14 0.00 -1,020.98 1,307.78 5,941,049.07 Point 15 0.00 -745.87 531.14 5,941,320.03 Point 16 0.00 -533.34 244.23 5,941,531.02 Point 17 0.00 -292.06 5.47 5,941,771.00 Point 18 0.00 0.00 0.00 5,942,063.00 1 L-24 CTD Polygon Nora 0.00 0.00 0.00 -12,380.441,138,940.24 5,942,063.00 plan misses target center by 1140216.17usft at 9288.00usft MD (5968.91 TVD,-6313.67 N,-1244.17 E) Polygon Point 1 0.00 0.00 0.00 5,942,063.00 Point 2 0.00 -37.01 381.85 5,942,028.02 Point 3 0.00 -244.81 339.75 5,941,820.02 Point 0.00 -404.20 219.90 5,941,660.01 Point 5 0.00 -459.15 18.59 5,941,604.00 Point 0.00 -346.75 -244.85 5,941,714.99 Point 7 0.00 9.92 -555.01 5,942,069.98 Point 0.00 1,191.70 -868.84 5,943,249.96 Point 9 0.00 2,005.90 -1,079.58 5,944,062.95 Point 10 0.00 2,199.88 -1,071.56 5,944,256.95 Point 11 0.00 2,169.76 -668.68 5,944,228.97 Point 12 0.00 1,982.81 -683.66 5,944,041.96 Point 13 0.00 1,272.55 -458.37 5,943,332.98 Point 14 0.00 271.08 -199.60 5,942,332.99 Point 15 0.00 34.44 -82.83 5,942,097.00 Point 16 0.00 0.00 0.00 5,942,063.00 Casing Points 1,677,859.29 70' 0' 30.819 N 140' 33' 40.717 W 1,678,803.00 700 0' 10.126 N 140° 33' 22.754 W 1, 678, 803.00 1,679,192.00 1,679,227.00 1,679,532.02 1,680,213.03 1,680,699.05 1,681,713.07 1, 682, 866.10 1, 683, 074.11 1, 682, 887.13 1,682, 699.12 1,681, 560.09 1,680,567.06 1,680,116.05 1,679,338.04 1, 679, 050.03 1, 678, 810.02 1, 678, 803.00 1, 678, 803.00 1, 678, 803.00 1,679,185.00 1,679,144.01 1, 679, 025.02 1,678,824.02 1,678,560.02 1,678,248.00 1,677,927.94 1,677,712.90 1,677,719.89 1,678,122.89 1,678,108.90 1, 678, 337.93 1,678,601.98 1,678,720.00 1, 678, 803.00 70' 0' 10.126 N 140' 33' 22.754 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,750.00 5,981.04 2 3/8" 2 375 3.000 6/6/2016 10:13.19AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-24 Wellbore: 1 L-24ALl-01 Design: 1 L-24AL1-01 _wp01 Plan Annotations ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,288.00 5,968.91 -6,313.67 -1,244.17 TIP/KOP 9,448+00 5,969.15 -6,222.24 -1,375.16 Start DLS 7.00 9,648.00 5,975.77 -6,075.76 -1,510.44 3 9,848.00 5,982.39 -5,901.67 -1,607.66 4 10,148.00 5,982.84 -5,609.78 -1,669.27 5 10,328.00 5,983.11 -5,431.77 -1,693.40 6 10,528.00 5,985.11 -5,245.53 -1,764.90 7 10,828.00 5,992.58 -4,961.09 -1,854.53 8 11,028.00 5,996.72 -4,767.53 -1,902.67 9 11,208.00 5,997.49 -4,607.81 -1,984.88 10 11,750.00 5,981.04 -4,093.15 -2,119.20 Planned TD at 11750.00 Well 1 L-24 Mean Sea Level 1 L-24 @ 130.00usft (1 L-24) True Minimum Curvature WG.I BAKER HUGHES 6/6/2016 10:13:19AM Page 5 COMPASS 5000.1 Build 74 Baker Hughes INTEQ HIM ConocoPhillips Travelling Cylinder Report RAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 1 L Pad Site Error: 0.00 usft Reference Well: 1 L-24 Well Error: 0.00 usft Reference Wellbore 1 L-24ALl-01 Reference Design: 1L-24AL1-01_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 L-24 1 L-24 @ 130.00usft (1 L-24) 1 L-24 @ 130.00usft (1 L-24) True Minimum Curvature 1.00 sigma OAKEDMP2 Offset Datum Reference 1L-24AL1-01_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: 9,288.00 to 11,750.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,362.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 6/6/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 8,800.00 1 L-24 (1 L-24) GCT-MS Schlumberger GCT multishot 8,800.00 8,970.00 1 L-24A_wp03 (1 L-24A) MWD MWD- Standard 8,970.00 9,288.00 1L-24AL1_wp01 (1L-24AL1) MWD MWD-Standard 9,288.00 11,750.00 1L-24AL1-01_wp01 (1L-24AL1-01) MWD MWD- Standard r Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,750.00 6,111.04 2 3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 L Pad 1 L-13 - 1 L-13AL1 - 1 L-13AL1 1 L-13 - 1 L-13AL1 - 1 L-13AL1_wp05 Extended 1 L-17 - 1 L-17A - 1 L-17A_wp05 1 L-1 8 - 1 L-1 8 - 1 L-1 8 1 L-18 - 1 L-18A - 1 L-18A_wp03 1 L-18 - 1 L-18AL1 - 1 L-18AL1_wp02 1 L-23 - 1 L-23 - 1 L-23 1 L-24 - 1 L-24 - 1 L-24 1 L-24 - 1 L-24A - 1 L-24A_wp04 1 L-24 - 1 L-24ALl - 1 L-24AL1_wp01 1 L-24 - 1 L-24ALl-02 - 1 L-24ALl-02_wp01 1 L-25 - 1 L-25 - 1 L-25 1 L-25 - 1 L-25A - 1 L-25A 1 L-25 - 1 L-25ALl-01 - 1 L-25ALl-01 1 L-25 - 1 L-25ALl-01 PB1 - 1 L-25ALl-01 PB1 1 L-25 - 1 L-25ALl-02 - 1 L-25ALl-02 1 L-25 - 1 L-25ALl-02PB2 - 1 L-25ALl-02PB2 1 L-25 - 1 L-25APB1 - 1 L-25APB1 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 9,565.11 11, 900.00 120.27 9,288.00 8,475.00 636.14 9,288.00 8,475.00 636.14 9,450.00 9,450.00 0.00 9,288.00 8,475.00 636.14 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range 15.38 120.04 Pass - Minor 1/10 Out of range Out of range Out of range Out of range 13.15 630.51 Pass - Major Risk 13.15 630.51 Pass - Major Risk 0.97 -0.35 FAIL- Minor 1/10 11.07 632.61 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 1 L Pad - 1 L-17 - 1 L-17A - 1 L-17A_wp05 Offset Site Error: 0.00 usft Survey Program: 200-GCT-MS, 8100-MWD Rule Assigned: Minor 1/10 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) (% (usft) (usft) 111) (usft) (usft) (usft) 9,300.00 6,098,93 12,200.00 5,981.77 56.56 67.34-102.28 -6,400.04 -1,308,89 2-11/16 158,74 17.28 158,51 Pass -Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 6/6/2016 9:52:51AM Page 2 COMPASS 5000.1 Build 74 c "a a, ,� Il 8 a v R� =5 0 a a F a (ni/A3sn OOZ) (+)9uoN/(-)41noS co M CD C g is o n .�OQ QHC./)chv inm�mrn�a O C NZ m OOON �[ �tOp Qmi� -a N vvcvvMmC`?�?c�cv Y �c °_ggogggggggg N J _ O m`L6 O rnZ� rn m m m � p p pp pp p _d O O O O O O O O g g O °Q O O 1 n V lfJ O 1p� �Opi M R � CV � Qi N (^J In cO��tOI�mOOim . CD J C'4 WO) �ZZ-q Q F- m m � tCi�oi� ui�tg,.: i + c`�� ooc�cmmom t h N O O l m V N T f 0 0 LO m co co19 LnL? Ln4Vgf"T J w mrn—i� ocvo cn mV M j CVi m � CV � In (V l() �� mco�mmmmrnrnrnm O O =m -N NLnmmm��m1�0 Qth u'!O �A u�O>000 V N M�16 m � M M M V R I n M C'�') C�7 CN7 _Na;a; v maa+rnorn �Y, o �o i 6616aiaioi-.6 c+i mmmmmmmmm�� U� C) 000000000000 o 0 0 0 0 0 0 0 0 0 m< V R- N N N N O� O Z O U) � 4 I S o 0 S is a C � Qw O 8 + cy W _ 3 � a _ 4 v Q 7 a XIN`7 ..1 S �sb _ o a `r sq Cam: a a 8 (oi/1;sn 08) 91daQ jeopioA onil G W ,t- KUP PROD 1 L-24 CQnocoPhillips Alaska, Inc. - Well Attributes Max Angle & MD JTD Wellbare API/UWI Field Name Wellbore Slalus 500292217000 KUPARUK RIVER UNIT PROD ncl (°) MD (ftKB) 53.31 4,700.00 Act Elm (ftKB) 9,241.0 Comment HIS (ppm) Date SSSV: NONE 60 8/2/2015 Annotation End Date Last WO: 12/17/2013 KB-Grtl (k) Rig Release Date 42.99 5/23/1991 1L-24,414120161:32:10 PM Vertical scnemahc actual Annotation 8 IRKS) Entl Date Last Tag: SLM 8,903.0 3/31/2016 Annotation Last Motl By End Dafe Rev Reason: TAG; GLV C/O lehalIf 4!4/2016 HANGER, 392 7COMDUCTOR; 44,0-122,o GAS LIFT; 3,338.E GAS LIFT; 4,994.3 - SURFACE; 43 0-5,081.2 GAS LIFT; 6,219.9 GAS LIFT; 7,199.4 GAS LIFT; ],8]0 9 GAS LIFT; 8,299.3 LOCATOR; 8,355.3 SEAL ASSY; 8,356.3 PBR; 8,3634 PACKER; 8,385.8 NIPPLE; 8,438.5 OVERSHOT{BG56.1 SEAL ASSY; 8,476.0 PER; 8,477.3 PACKER; 8,491.0 NIPPLE; 8,672.5 SEAL ASSY; 8,589.E PER; 8,590.9 PACKER; 8,603 ] NIPPLE; 8.621.0 SOS: 8,653.E IPERF; 8,735 0-8,782.0- IPERF; 8,920.0-8,949.0- IPERF; 9,010.0-9,029.0- PRODUCTION; 28.3-9,240.9 1 Casing ng rings Casing Description OD CONDUCTOR (in) 16 ID (in) 15.062 Top (ftKB) 44.0 Set Depth (ftKB) Set 122.0 Depth (TVD)... 122.0 Wt/Len (I... 62.50 Grade H-40 Top Thmd WELDED Casing Description OD SURFACE (in) 9 5/8 ID (in) 8.921 Top (ftKB) 43.0 Set Depth (ftKB) Set 5,081.2 Depth (TVD)... 3,610.2 WULen (I... 36.00 Gratle J-55 Top Thread BTC Casing Description OD PRODUCTION (in) 7 ID (in) 6.27E Top (kKB) 28.3 Set Depth (kKB) Set 9,24D.9 Depth (TVD)... 6,286.8 WHLan (I... 26.00 Grace J-55 Top Thread BTC-MOD Tubing Strings Tubing Description String Ma... ID (in) Top (kKB) Set Depth (4% Set Depth (TVD) (... Wt (I11) Gratle IT., Connection TUBING WO -2013 3 t/2 2.992 39.2 8,464.4 5,791.9 9.30 L-80 EUE-m Completion Details Top (ftKB) Top (ND) (ftKB) Top Ind (°) Item Des Cam Nominal ID (in) 39.2 39.2 0.08 HANGER FMC Gen IV TUBING HANGER 2.992 8,355.3 5,721.4 49.72 LOCATOR BAKER LOCATOR SUB 2.990 8,356.3 5,722.0 49.72 SEAL ASSY BAKER SEAL ASSY-Space out above PBR locator sub "Actual Space out 7.08' locator above PBR 2.990 8,363.4 5,726.6 49.72 PBR BAKER 80-40 POLISH BORE RECEPTACLE 40,000 Shear force 4.000 8,385.8 5,741.1 49.72 PACKER BAKER FHL RETRIEVABLE PACKER 60,000 PSI Shear Release 2,930 8,438.5 5,775.2 49.75 NIPPLE CAMCO "DS" NIPPLE 2,875" 2.875 8,456.1 5,786.E 49.7E 1 OVERSHOT BAKER POORBOY OVERSHOT 6" OD x 3.62" ID Swallowed 6.84' of tbg stub, 3.000 Tubing Description String Ma.., tD (in) Top (kKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibkl) Grotla Top Connection TUBING WO -2004 3 % 2.992 8,457.E 8,602.3 5,880.9 9.30 J-55 EUE AB MOD Completion Details Top(ftKB) Top (TVD) (ftKB) Top Ind (') Item Des Com Nominal ID (in) 8,476.0 5,799.4 49.78 SEAL ASSY BAKER 8040 SEAL ASSEMBLY 2.980 8,477.3 5,800.2 49.78 PBR BAKER 80-00 PBR 2.980 8,491.0 5,809.1 49.79 PACKER BAKER FHL PACKER 2.930 8,572.5 5,861.6 49.89 NIPPLE CAMCO DS NIPPLE WITH 2.72" NO-GO 2.812 8,589.6 5,872.6 49.92 SEAL ASSY TIW SEAL ASSEMBLY/PBR, STABBED INTO EXISTING PBR 3.000 Tubing Descnption String Ma... ID (in) Top (kKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibkt) Grade Top Connection TUBING - Original 31/2 2.992 8,590.9 8,654.E 5,914.4 9.30 J-55 EUE8rdABMOD Completion Details Top IRKS) I Top (TVD) (ftKB) Top Ind (°) Item Des Co. Nominal ID (in) 8,590.9 5,873.5 49.92 PBR TIW PBR w/ 1 O' STROKE 3.000 8,603.7 5,881.7 49.94 PACKER TIW HM-1 RETRIEVABLE PACKER 3.500 8,621.0 5,892.9 49.98 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,653.6 5,913.8 50.06 SOS TIW SHEAR OUT SUB 3.015 Perforations & Slots Top (ftKB) Stan (ftKB) Top (TVD) St. (ftKB) (TVD) (ftKB) Zane Date Shot Dens (shots" t) Type Co. 8, 735.0 8,782.0 5,966.0 5,996.0 C-4,1L-24 8/20/1991 6.0 IPERF 21/8"Flow deg, ph Jet Std;0 8,920.0 8,949.0 6,083.8 6,102.2 A-5, 1L-24 6/18/1991 4.0 IPERF 4.5" Carrier; 180 deg, ph 9,010.0 9,029.0 6,141.0 6,153.0 A-4,1L-24 6/18/1991 4.0 IPERF 4.5" Carrier, 180 deg. ph Mandrel Inserts St ad on N Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) San Valve Type Latch Type Port Size (in) TRO Run (psi) Run Data Com 1 3,338.6 2,496.9 CAMCO MMG 1 1/2 GAS LIFT OMY RK 0.000 0.0 4/1/2016 2 4,994.3 3,549.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/1/2016 3 6,219.9 4,344.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/1/2016 4 7,199.5 4,959.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/1/2016 5 7,870.9 5,403.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/1/2016 6 8,299.3 5,685.2 1 CAMCO MMG 1 112 GAS LIFT I DMY RK 0.000 0.0 12/22/ 0013 Notes: General & Safety End Dale I Annotation 6/12/2004 NOTE: WORKOVER 6/12/2004 NOTE:TREE CAP CONNECTION: 3" 6/12/2004 NOTE: TREE: CAMERONIGEN 5/3-1/8"/5000 psi 10/5/2010 NOTE: View Schematic w/Alaska Schematic9.0 16" 62# H-40 shoe (a) 22' MD 9-5/8" 36# J-55 shoe @ 5081' MD C-sand perfs 8735' - 8782' MD KOP @ 8875' PDC A -sand perfs 8920' - 8949' MD 9010' - 9029' MD 7" 26# J-55 shoe @ 9241' MD 1 L-24 Proposed CTD Schematic 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ 3339', 4994'. 6220', 7200', 7871', 8299' RKB Baker 80-40 PBR @ 8363' RKB (4.0" ID) Baker FHL packer @ 8386' RKB (2.93" ID) 3-1/2" Camco DS nipple @ 8439' RKB (2.875" min ID) Baker Poorboy Overshot @ 8456' RKB (3.00" min ID) Baker 80-40 PBR @ 8477' RKB (2.98" ID) Baker FHL packer @ 8491' RKB (2.93" ID) 3-1/2" Camco DS nipple @ 8573" RKB (8568' PDC) (2.812" min ID) TIW Seal Assy @ 8590' RKB (3.00" ID) TIW PBR @ 8591' RKB (3.00" ID) TIW HIM-1 Retrievable Packer@ 8604' RKB (8598' PDC) 3-112" Camco D nipple @ 8621' RKB (8616' PDC) (2.80" min ID) 3-1/2" SOS @ 8654' RKB (8649' PDC) \ IL-24AL1-02 wp01 (AS sand -Southeast) �1 1 TD @ 13,400' MD 1 1 1 I Top of liner @ 8640' MD — — — — — — — — — — — — — — — — — — + 1 1\ ..----- ————— —— — — — —— —I 1L-24ALl-01 wp01 (A5 sand - Northwest) \a_ i i TD @ 11.750' MD ----- liner Billet 8980' MD - -- - -- - - ------ - - - -- -- �_ ---- '' f—zF ------------+ 1L-24ALi wp01(A5 sand- TD@1i,750'MD ��—�— ----- ———— — '--—— _ . IP9288'MD ————— — — — — — — — — — — — — — — — — — — — — — — — — — — — —1 1 L-24A wp04 (A5 sand - Southeast) TD @ 13,400' MD Liner Billet @ 8970' MD TRANSMITTAL LETTER CHECKLIST WELL NAME: Qk_ /k—ak i — 6l PTD: 26 —6?� Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: �QG J`c,K }��1� POOL: r 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. 21(o - Q� , API No. 50-�- a 11, 0 -�- 00. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK_RIV UNIT 1L-24AL1-01 Program DEV Well bore seg ❑�/ PTD#: 2160790 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025659, Surf Loc & TD; ADL0025664, Top Prod Interv. 3 Unique well name and number Yes KRU 1L-24AL1-01 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order 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 PKB 6/7/2016 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),0.2.A-D) NA Engineering Appr Date VTL 6/9/2016 Geology Appr Date PKB 6/7/2016 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Conductor string provided Surface casing protects all known USDWs CMT vol adequate to circulate on conductor & surf csg CMT vol adequate to tie-in long string to surf csg CMT will cover all known productive horizons Casing designs adequate for C, T, B & permafrost Adequate tankage or reserve pit If a re -drill, has a 10-403 for abandonment been approved Adequate wellbore separation proposed If diverter required, does it meet regulations Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation BOPE press rating appropriate; test to (put psig in comments) Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown Is presence of H2S gas probable Mechanical condition of wells within AOR verified (For service well only) NA NA NA NA No Yes Yes NA Yes NA Yes Yes Yes Yes Yes Yes NA 35 Permit can be issued w/o hydrogen sulfide measures No 36 Data presented on potential overpressure zones Yes 37 Seismic analysis of shallow gas zones NA 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Conductor set in KRU 1 L-24 Surface casing set in KRU 1 L-24 Surface casing set and fully cemented Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures; Well 1L-17A is a well plan. Max formation pressure is 4266 psig(13.4 ppg EMW); will drill w/ 8.7 ppg and maintain overbal w/ MPD MPSP is 3661 psig; will test BOPs to 4000 psig H2S measures required Wells on 1L-Pad are H2S-bearing. H2S measures required. Max. potential reservoir pressure is 13.4 ppg EMW; will be drilled using 8.6 ppg and MPD technique. Onshore development lateral to be drilled. Geologic Commissioner: Date: Engineering Public issioner Dale,' Commissioner Date