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214-086
Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, March 02, 2017 8:29 AM To: Starck, Kai Cc: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA) Subject: Expired Permits to Drill: 214-086, 214-087, 214-156 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 3Q-14AL4, PTD 214-086, issued 23 June 2014 • KRU 3Q-14AL5, PTD 214-087, issued 23 June 2014 • KRU 1G08AL2-01, PTD 214-156, issued 7 October 2014 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 S ATE GOVERNOR SEAN P A RNEI L D. Venhaus V I" Engineering 0UPGI V15V1 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 333 West Seventh Avenue Anchorage, Alaska 99501-3572 dam: 907.279,1 d33 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3Q-14AL4 ConocoPhillips Alaska, Inc. Permit No: 214-086 Surface Location: 2289' FNL, 2013' FEL, Sec. 17, T13N, R09E, UM Bottomhole Location: 2500' FNL, 1896' FEL, Sec. 20, T13N, R09E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well Permit No. 214082, API No. 50-029- 21665-01-00. Production should continue to be reported as a function of the original API number stated above. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, CN4'/" athyPoerster Chair XA DATED this ?3 day of June 2014. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ECEI M E, JUN 18 2014 1a. Type of Work: Drill ❑ - Lateral ✓ Redrill ❑ Reentry 1 In Proposed Well Class: Development - Oil ❑ ' Service - Winj ❑ Single Zone ❑ , Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 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. 59-52-180 11. Well Name and Number: 3Q-14AL4 ` 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9900' , TVD: 6373' 12. Field/Pool(s): Kuparuk River Field . Kuparuk Oil Pool 4a. Location of Well (Governmental Section): Surface: 2289' FNL, 2013' FEL, Sec. 17, T13N, R09E, UM Top of Productive Horizon: 1675' FNL, 815' FEL, Sec. 20, T13N, R09E, UM Total Depth: 2500' FNL, 1896' FEL, Sec. 20, T13N, R09E, UM 7. Property Designation (Lease Number): ADL 25512 8. Land Use Permit: 2553 13. Approximate Spud Date: 7/1/2014 9. Acres in Property: 2560 14. Distance to Nearest Property: 11600 41b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 516324 y- 6025783 Zone- 4 10. KB Elevation above MSL: 60 feet GL Elevation above MSL: 22 feet 15. Distance to Nearest Well Open to Same Pool: 3N-09 , 1100' 16. Deviated wells: Kickoff depth: 9305 ft. Maximum Hole Angle: 980 deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25,035) Downhole: 4378 psig Surface: 3728 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3' 2.375" 4.7# L-80 ST-L 1375' 8525' 6409' 9900, 6373' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 8506 Total Depth TVD (ft): 6657 Plugs (measured) none Effective Depth MD (ft): 1 8401' Effective Depth TVD (ft): 6580' Junk (measured) 8356', 8395' Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 16" 1875# Poleset 115, 115' Surface 4490' 4527' 1250 sx AS III, 300 sx Cl G 4527' 3747' Intermediate Production 8455' 8489' 300 sx Class G, 175 sx AS 1 8489' 6645' Perforation Depth MD (ft): 8204'-8248', 8258'-8302' Perforation Depth TVD (ft): 1 6438'-6470', 6477'-6509' 20. Attachments: Property Plat ❑ BOP Sketct ❑ Drilling Prograrr ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketct ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date: _-- -- 22. 1 hereby certify that the foregoing is true and correct. Contact Jason Burke @ 265-6097 Email Jason. Burke cDconocophillips.com Printed Name ,D. VenhTitle CTD Engineering Supervisor Signature Phone: 265-6120 Datey Commission Use Only Permit to Drill Number: C 0 API Number: 50- � `� — -I us _ 63 —oo I Permit Approval Date: (., 23 - 2p 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 m thane, gas hydrates, or gas contained in shales: Other: B P te'S f to 4 Z 0 C S 1 Samples req'd: Yes [ No Mud log req'd: Yes No H2S measures: Yes © No Directional svy req'd: Yes No❑ Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No [� V D T E / Approved by: CN iOMMISS S i N Date: �P 3 —� Form 10-401 (Re ed 1012012) This permit is valid for 24 mont s o t e e Af roval (20 AAC 25.005(g)) �Y I J1'CF 6/20/14- /9� ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 9, 2014 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED .JUN�✓ "J 18 2014 G C C ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a six lateral well out of the Kuparuk well 3Q-14 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in July 2014. The CTD objective will be to drill six laterals (3Q-14A, 3Q-14AL1, 3Q-14AL2, 3Q-14AL3, 3Q-14AL4 & 3Q-14AL5), targeting the A sand intervals. A cement plug must be placed in the 7" casing of well 3Q-14 to facilitate a casing exit for these laterals, which will likewise effectively plug off the existing perforations. There is insufficient room to plug the perfs in accordance with 20 AAC 25.112 (c), so ConocoPhillips requests a variance from the plugging requirements of 20 AAC 25.112 (c) to facilitate the casing exit of the 3Q-14 horizontal laterals. The proposed plugging procedure meets the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents: — 10-403 Sundry application to plug A -sand perfs in 3Q-14 — Permit to Drill Application Form 10-401 for 3Q-14A, 3Q-14AL1, 3Q-14AL2, 3Q-14AL3, 3Q-14AL4 & 3Q- 14AL5 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, Jason Burke Coiled Tubing Drilling Engineer 907-231-4568 Kuparuk CTD Laterals A'ASOMAIASKA 3Q-14A, AL1, AL2, AL3, AL4 & AL5' 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.................................................................................................................................................. 5 PressureDeployment of BHA.......................................................................................................................................... 6 LinerRunning.................................................................................................................................................................. 7 14. Disposal of Drilling Mud and Cuttings.............................................................................................7 (Requirements of 20 AAC 25.005(c)(14))....................................................................................................................................................7 16. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050 b...................................................................................... 7 16. Quarter Mile Injection Review (for injection wells only).....................Error! Bookmark not defined. (Requirements of 20 AAC 25.402).............................................................................................................. Error! Bookmark not defined. 17. Attachments.......................................................................................................................................8 Attachment 1: Directional Plans for 2T-32A & 2T-32AL1............................................................................................... 8 Attachment 2: Current Well Schematic for 2T-32........................................................................................................... 8 Attachment 3: Proposed Well Schematic for 2T-32A & 2T-32AL1................................................................................. 8 Page 1 of 8 6/11/2014 ORIGINAL PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 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 3Q-14A, AL1, AL2, AL3, AL4 & AL5. All laterals will be classified as "Development - Oif' 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 the attached 10-401 form for surface and subsurface coordinates of the 3Q-14A, AL1, AL2, AL3, AL4 & AL5. 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 4200 psi. Using the maximum formation pressure in the area of 4378 psi in the 3N-11, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3728 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)) A static bottom hole pressure of 3Q-14 in February 2014 indicated a reservoir pressure of 2462 psi or 7.3 ppg equivalent mud weight. The maximum down hole pressure in the 3Q-14 pattern is at 3N-11 with 4378 psi. It is expected that reservoir pressure as high as 3N-11 may be encountered while drilling the 3Q-14 laterals because we will be drilling towards that fault block. Using the 3N-11 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3728 psi. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection is currently being performed on the 3Q-13, so the drilling fluid will need to be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 3Q-14 laterals will be high differentials between fault blocks because we are drilling from a low pressure block into a higher pressure block. Managed pressure drilling will be used to reduce this risk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 8 ORIGINAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 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 Liner Details Name MD MD TVDSS TVDSS 3Q-14A 10,750' 11,400' 6,369' 6,377' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL1 10,150' 11,400' 6,391' 6,377' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL2 10,080' 10,600' 6,391' 6,413' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL3 9,305' 10,580' 6,360' 6,360' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL4 8,525' 9,900, 6,409' 6,373' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3Q-14AL5 8,120' 9,150' 6,301' 6,319' 2%", 4.7#, L-80, ST-L slotted liner; Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.50 H-40 Welded 37' 115' 0' 115' 1640 630 Surface 9-5/8" 36 J-55 SMLS 37' 4527' 0' 3747' 3520 2020 Casing 7" 26 J-55 BTC 34' 8489' 0' 6644' 4980 4330 Tubing 3 %2" 9.2 L-80 EUE-MOD 34' 8135' 0' 6387' 10160 10540 7. Diverter System Information (Requirements of 20 AA 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AA 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 6. Drilling Fluids Program (Requirements of 20 AA 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride -based Flo -Pro mud (9.2 ppg) - Drilling operations: Chloride -based Flo -Pro mud (9.2 ppg). This mud weight will hydrostatically overbalance the reservoir pressure; we will maintain these conditions using MPD practices described below. - Completion operations: 3Q-14 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over -balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-198 bbl) of at least 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 8 6/11/2014 ORIGINAL PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of the minimum of 12.0 ppg will be initially targeted at the window based on the recent static bottom -hole pressure and expected draw down reservoir pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. 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 3Q-14 Window (8.215' MD. 6386' TVD) Usina MPD Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure 7.3 ppg) 2447 psi 2447 psi Mud Hydrostatic (9.2 ppg) 3084 psi 3084 psi Annular friction (i.e. ECD, 0.090 psi/ft) 739 psi 0 psi Mud + ECD Combined 3828 psi 3084 psi (no choke pressure) (overbalanced (overbalanced —1376psi) —637psi) Target BHP at Window (12.0 4022 psi 4022 psi Choke Pressure Required to Maintain 199 psi 938 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AA 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA 25.005(c)(11)) N/A - Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AA 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA 25.005(c)(13)) Page 4 of 8 nRIGINAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Summary of Operations Background Well 3Q-14 is a Kuparuk A -sand development well equipped with 3'/2" tubing and 7" production casing. Six laterals from well 3Q-14 will be drilled to the Southwest side of parent well 3Q-14 to access reserves in an adjacent fault block. These laterals will target the A1, A2 & A3 sands. The D-Nipple located at 8125' MD will have the ID milled out to a 2.80" to allow the drilling assemblies access through the tubing tall. The tubing tail will also be perforated prior to cementing to allow cement between the 3-1/2" tubing tail and 7" casing. Prior to drilling, the existing A -sand perfs in 3Q-14 will be squeezed with cement to provide a means to kick out of the 7" casing. ConocoPhillips requested a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner in the Sundry application (Approved 314-146) After plugging off the existing A -sand perfs with cement, pilot hole drilled, a mechanical whipstock will be placed in the 7" casing at the planned kickoff point. The 3Q-14A sidetrack will exit through the 7" casing at 8215' MD and all subsequent laterals will be drilled off of this sidetrack. The laterals will be completed with 2 %" slotted liner. The final liner will be run with the top located inside the 3 %2" tubing at 8120' MD. Pre-CTD Work 1. RU slickline — Dummy off GLM adn obtain a SBHP 2. RU Pump — Perform injectivity test 3. RU E-Liner — Perforate tubing tail at 8119' — 8121' MD 4. RU coil — Mill out D-nipple at 8125' MD then pump cement and squeeze A-perfs. 5. RU slick -line - Tag top of cement and pressure test. 6. 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. 3Q-14A Sidetrack (Al & A2 sand - Southwest) a. Drill 2.80" high -side pilot hole through cement to 8265' MD b. RU Slickline — caliper pilot hole c. Drift pilot hole with whip -stock dummy d. Set whip -stock at 8215' MD with high -side orientation e. Mill 2.80" window at 8215' MD f. Drill 2.74" x 3.0" bi-center lateral to TD of 11400' MD g. Run 2%" slotted liner with an aluminum billet from TD up to 10750' MD 3. 3Q-14AL1 Lateral (A2 & A3 sand - Southwest) a. Kickoff of the aluminum billet at 10750' MD b. Drill 2.74" x 3.0" bi-center lateral to TD of 11400' MD c. Run 2%" slotted liner from TD up to 10150' MD Page 5 of 8 ORIGINAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 4. 3Q-14AL2 Lateral (Al sand - Southwest) a. Kickoff of the aluminum billet at 10150' MD b. Drill 2.74" x 3.0" bi-center lateral to TD of 10600' MD c. Run 2%" slotted liner from TD up to 10080' MD 5. 3Q-14AL3 Lateral (A3 sand - Southwest) a. Kickoff of the aluminum billet at 10080' MD b. Drill 2.74" x 3.0" bi-center lateral to TD of 10580' MD c. Run 2%" slotted liner from TD up to 9305' MD 6. 3Q-14AL4 Lateral (Al & A2 sand - Southwest) a. Kickoff of the aluminum billet at 9305' MD b. Drill 2.74" x 3.0" bi-center lateral to TD of 9900' MD c. Run 2%" slotted liner from TD up to 8525' MD 7. 3Q-14AL5 Lateral (Al & A2 sand - Southwest) a. Kick off of the aluminum billet at 8525' MD b. Drill 2.74" x 3.0" bi-center lateral to TD of 9150' MD c. Run 2%" slotted liner into the tubing tail at 8120' MD 8. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV. 3. Turn over to production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, 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 slickline lubricator. 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. Page 6 of 8 R I G I N A L 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 — 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 3Q-14 CTD laterals will be displaced to an overbalancing fluid (12.0 ppg NaBr) prior to running liner. See the "Drilling Fluids" section for more details. — While running 23/" slotted liner, a joint of 23/" 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. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional 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 3Q-14A 11600' 3Q-14AL1 11600' 3Q-14AL2 11600' 3Q-14AL3 11600' 3Q-14A L4 11600' 3Q-14AL5 11600, — Distance to Nearest Well within Pool (heel measured to offset well) Page 7 of 8 OR I G I NAL 6/11/2014 PTD Application: 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Lateral Name Distance Well 3Q-14A 1100, 3N-09 3Q-14AL1 1100, 3N-09 3Q-14AL2 1100, 3N-09 3Q-14AL3 1100, 3N-09 3Q-14AL4 1100, 3N-09 3Q-14AL5 1100, 3N-09 16. Attachments Attachment 1: Directional Plans for 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Attachment 2: Current Well Schematic for 3Q-14 Attachment 3: Proposed Well Schematic for 3Q-14A, AL1, AL2, AL3, AL4 & AL5 Page 8 of 8 6/11/2014 ORIGINAL V Lo Ifl In N d d' 000 p ao N p al 0 (a)- O O N t M N a nj p /a` O O 0 N O lJ a N 2 � O p 00 0-- p 47 ZI N r .0 C- V a H m (D co::) _ M .a f- C.D N O- (a)a) C E O] O Cco p :E � m n. p o0 0 Ip 0 a @ M E E N CO C c6 Co V ca Q (U 7 U of U ti U co U (V (V (V 0) cV N al (V cV � Y Y M Cl) M M GO Cl) 6 N CO m Cl) Cl) p al 0 a `� 00 o In In Lo �\ Ll o vC ' a O N co co co � N j N � V r p Lo N JOcO c) lam a) 0 w In In p 2 co m N o0 f— W ORIGINAL ConocoPhillips Alaska, Inc. KUP PROD 3Q-14 30-14. 2/11/20141:08 vertical mates ji ................................................................ HANGER; 34.0 CONDUCTOR; 37.0.115.0 NIPPLE; 509.3- GAS LIFT; 2,884.0- GAS LIFT; 4,425.1- SURFACE; 37.0-4,527. GAS LIFT; 5,654. GAS LIFT; 6.599. GAS LIFT; 7.414.1 GAS LIFT; 8,023.( NIPPLE; 8,068.E PACKER; 8,108.2 NIPPLE; 8,125.1 SOS; 8.13,12 IPERF; 8,211.0-8,212.0 IPERF; 8,214.0-8,215.0 RPERF; 8,204 M,248A IPERF; 8,234.D8,235.0 IPERF; 8,237.0-8.238.0 IPERF; 8,259.0-8.261.0 IPERF; 8,264.0-8,265.0 _ IPERF; 8,2660-8,267.0 PERF; 8,269.0-8,270.0 - IPERF; 8,274.0-8,276.0 IPERF; 8,278.0-8,279.0 RPERF; 8,258.0-8,302.0- (PERF; 8,286.0-8.288.0 FISH; 8.356.0 FISH; 8,395.0 5OU292166500 KUPARUK RIVER UNIT (PROD 11 47.. Comment SSSV: NIPPLE 25 H(ppm) Date 150 12/24/2012 Annotation Last WO: End Date 2/1/1998 Annotation Depth (ftKB) End Date Last Tag: SLM 8,274.0 2J7/2014 Annotation Rev Reason: TAG Casing tangs Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 37.0 Set Depth (ftKB) 115.0 Set Depth (TVDI 41E Casing Description SURFACE OD (in) 95/8 ID (in) 8.765 Top (ftKB) 37.0 I Set Depth (ftKB) 4,527.2 Set Depth (TVD) 3,74i Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 34.0 Set Depth (ftKB) - 8,488.9 Set Depth (TVD) 6,644 Tubing Strings Tubing Description String TUBING WO Ma... ID (in) Top IRK B) 31/2 2.992 34.0 Set Depth (ft.. Set Depth (TVD) (... V 8.135.2 6.38Z5 12/4/1986 Date 2/11/2014 J-55 SMLS Grade ree J-55 Top BTCTh de Top Connectio EUE 8rd Mod Top (ftKB) Top (TVD) (ftKB) Top Intl (°) I Item Des Com (in) 34.0 34.0 0.03 HANGER 3.5" 5M CIW Gen IV Tubing Hanger w/ 3.5" L-80 EUE 8rd 3.500 Mod Pin Down 509.3 509.3 0.35 NIPPLE 3.5" Camco'DS' Nipple w/2.812" No -Go Profile 2.812 8,068.6 6,338.8 42.71 NIPPLE 3.5" Camco'W' Nipple w/ 2.812" Selective Profile 2.812 8,108.2 6,367.8 42.94 TACKER 3.5" x 7" Baker'SAB-3' Permanent Packer w/ K22 Anchor 3.250 Latch Seal Assy Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(TVD) Top Intl Top (ftKB) (ftKB) (°) Des Com I Run Date ID (in) 8,356.01 6,548.0 43.43 FISH 1"X 2" Piece of Tree Saver Left in Hole 110/14/1991 0.000 8,395.0 6,576.4 43.43 FISH 1 1/2" OV w/ RK Latch Empty Pocket; Dropped to 2/8/1998 0.000 Rathole Perforations & Slots Shot Dens Top (TVD) St. (TVD) (shots/f Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,204.0 8,248.0 6,437.7 6,469.6 A-3, A-2, 3Q- 4/11/1991 1 6.0 RPERF 2 11T Dyna Strip; 0 deg 14 ph 8,211.0 8,212.0 6,442.7 6,443.5 A-4, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet, 0 deg. phasing 8,214.0 8,215.0 6,444.9 6,445.6 A-3, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing 8,234.0 8,235.0 6,459.4 6,460.2 A-2, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing 8,237.0 8,238.0 6.461.6 6,462.3 A-2, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing 8,258.0 8,302.0 6,476.9 6,508.8 A-1, 3Q-14 4/11/1991 6.0 RPERF 2 1/T Dyna Strip; 0 deg ph 8,259.0 8,261.0 6,477.E 6,479.0 A-1, 3Q- 44 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing 8,264.0 8,265.0 6,481.2 6,482.0 A-1, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing 8,266.0 8,267.0 6,482.7 6,483.4 A-1, 3Q- 44 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet, 0 deg. phasing 8,269.0 8,270.0 6.484.9 6,485.6 A-1, 3Q-14 3/2/1987 1.0 IPERF 21/8" HJ II EnerJet; 0 deg. phasing 8,274.0 8,276.0 6,488.5 6,489.9 A-1, 3Q-14 3/2/1987 1.0 IPERF 2 118" HJ II EnerJet; 0 deg. phasing 8,278.0 8,279.0 6,491.4 6,492.1 A-1, 3Q-14 3/2/1987 1.0 IPERF 2 1/8" HJ II EnerJet; 0- deg. phasing 8,286.0 8,288.0 6,497.2 6,498.7 A-1, 3Q-14 TO19 77 1.0 IPERF 2 1/8" HJ II EnerJet; 0 deg. phasing Mandrel Inserts St at! IJ TND Valve Latch Port Size TROun(ftKB) No Top (ftKB Make Model OD(in) Sent Type Type (in) (psi) RunDate x Annotation PRODUCTION; ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-14 3Q-14AL4 Plan: 3Q-14AL4_wp01 Standard Planning Report 14 May, 2014 Few P ap" I BAKER HUGNES �a�;;�INAL ConocoPhillips Database: EDM Alaska Sandbox v16 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3Q Pad Well: 3Q-14 Wellbore: 3Q-14AL4 Design: 3Q-14AL4_wp01 Planning Report Local Co-ordinate Reference: Well 30-14 TVD Reference: Mean Sea Level MD Reference: 30-14 @ 60.00ft (3Q-14) 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 //.Fag BAKER HUGHES Site Kuparuk 3Q Pad Site Position: Northing: 6,025,873.15ft Latitude: 70° 28' 54.757 N From: Map Easting: 515,959.89ft Longitude: 149° 52' 10.513 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.12 ° Well 3Q-14 Well Position +N/-S 0.00 ft Northing: 6,025,783.47 ft Latitude: 70° 28' 53.867 N +E/-W 0.00 ft Easting: 516,323.80 ft Longitude: 1490 51' 59.814 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3Q-14AL4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 8/1/2014 15.07 80.01 57,400 Design 3Q-14AL4_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,305.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 178.60 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,305.00 88.85 230.53 6,359.54 -5,111.90 584.74 0.00 0.00 0.00 0.00 9,395.00 97.85 230.53 6,354.29 -5,168.95 515.46 10.00 10.00 0.00 0.00 9,465.00 90.85 230.53 6,348.99 -5,213.30 461.61 10.00 -10.00 0.00 180.00 9,535.00 94.85 224.78 6,345.51 -5,260.36 409.97 10.00 5.72 -8.21 305.00 9,605.00 89.98 219.75 6,342.56 -5,312.09 362.96 10.00 -6.96 -7.18 226.00 9,705.00 82.80 226.73 6,348.87 -5,384.71 294.70 10.00 -7.18 6.98 136.00 9,900.00 83.21 246.38 6,372.84 -5,490.84 134.00 10.00 0.21 10.07 90.00 511412014 2:26:37PM Page 2 COMPASS 2003.16 Build 69 F\ G I N A rigs ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3Q Pad Well: 3Q-14 Wellbore: 3Q-14AL4 Design: 3 Q-14 A L 4_w p 01 Planned Survey Measured TVD Below Depth Inclination Azimuth System +N/-S (ft) (I (I (ft) (ft) 9,305.00 88.85 230.53 6,359.54 -5,111.90 TIP/KOP 9,395.00 97.85 230.53 6,354.29 -5,168.95 Start 10 dls 9,400.00 97.35 230.53 6,353.63 -5,172.10 9,465.00 90.85 230.53 6,348.99 -5,213.30 3 9,500.00 92.85 227.66 6,347.86 -5,236.20 9,535.00 94.85 224.78 6,345.51 -5,260.36 4 9,600.00 90.32 220.11 6,342.58 -5,308.25 9,605.00 89.98 219.75 6,342.56 -5,312.09 5 9,700.00 83.16 226.38 6,348.26 -5,381.30 9,705.00 82.80 226.73 6,348.87 -5,384.71 6 9,800.00 82.90 236.31 6,360.72 -5,443.30 9,900.00 83.21 246.38 6,372.84 -5,490.84 Planned TD at 9900.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3Q-14 Mean Sea Level 3Q-14 @ 60.00ft (3Q-14) True Minimum Curvature Vertical Dogleg Toolface Map Map +E/-W Section Rate Azimuth Northing Easting (ft) (ft) (°/100ft) (°) (ft) (ft) 584.74 5,124.64 0.00 0.00 6,020,673.38 516,919.70 515.46 5,179.99 10.00 0.00 6,020,616.17 516,850.55 511.63 5,183.05 10.00 -180.00 6,020,613.02 516,846.73 461.61 5,223.01 10.00 -180.00 6,020,571.72 516,796.80 435.18 5,245.26 10.00 -55.00 6,020,548.76 516,770.42 409.97 5,268.79 10.00 -55.09 6,020,524.55 516,745.27 366.17 5,315.61 10.00 -134.00 6,020,476.56 516,701.58 362.96 5,319.36 10.00 -134.21 6,020,472.72 516,698.38 298.30 5,386.98 10.00 136.00 6,020,403.37 516,633.88 294.70 5,390.30 10.00 135.60 6,020,399.95 516,630.28 221.00 5,447.07 10.00 90.00 6,020,341.21 516,556.72 134.00 5,492.47 10.00 88.81 6,020,293.49 516,469.84 511412014 2:26:37PM Page 3 COMPASS 2003.16 Build 69 0, R I N A L ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Company: Con000Philiips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 3Q-14 Welibore: 3Q-14AL4 Design: 3Q-14AL4_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Shape (I V) (ft) (ft) (ft) 3Q-14AL4_T3 0.00 0.00 6,373.00-8,219.101,140,265.59 plan hits target center Point 3Q-14A Fault3 0.00 0.00 plan hits target center Rectangle (sides W295.00 H1.00 D0.00) 3Q-14 CTD Polygon 0.00 0.00 plan hits target center Polygon Well 3Q-14 Mean Sea Level 30-14 @ 60.00ft (3Q-14) True Minimum Curvature Northing Easting (ft) (ft) Latitude Longitude 6,020,067.00 1,656,491.00 70' 13' 20.790 N 140- 38' 12.388 W 0.00-8,278.901,140,168.45 6,020,007.00 1,656,394.00 70° 13' 20.354 N 140° 38' 15.435 W l 0.00-7,162.071,141,211.01 6,021,126.00 1,657,434.00 70' 13' 29.647 N 140° 37' 40.649 W l Point 1 0.00 -7,162.071,141,211.01 6,021,126.00 1,657,434.00 Point 0.00 -7,307.101,141,217.70 6,020,981.00 1,657,441.01 Point 0.00 -7,448.871,141,103.38 6,020,838.99 1,657,327.01 Point 0.00 -7,702.981,140,678.80 6,020,583.98 1,656,903.03 Points 0.00 -8,152.701,140,055.77 6,020,132.94 1,656,281.05 Point 0.00 -8,540.561,139,508.88 6,019,743.92 1,655,735.07 Point 0.00 -8,879.591,139,037.11 6,019,403.89 1,655,264.09 Point 0.00 -9,253.631,139,038.31 6,019,029.89 1,655,266.11 Point 0.00 -9,026.351,139,383.83 6,019,257.90 1,655,611.10 Point 10 0.00 -8,552.631,140,004.91 6,019,732.94 1,656,231.07 Point 11 0.00 -8,225.581,140,463.66 6,020,060.96 1,656,689.06 Point 12 0.00 -7,706.181,141,234.85 6,020,582.00 1,657,459.03 Point 13 0.00 -7,491.621,141,454.33 6,020,797.02 1,657,678.02 Point 14 0.00 -7,293.751,141,520.76 6,020,995.01 1,657,744.01 Point 15 0.00 -7,120.641,141,477.13 6,021,168.01 1,657,700.00 Point 16 0.00 -7,162.071,141.211.01 6,021,126.00 1,657,434.00 3Q-14AL4_T1 0.00 0.00 6,350.00-7,946.881,140,634.23 6,020,340.00 1,656,859.00 70' 13' 22.885 N 140' 38' 0.627 W plan hits target center Point 3Q-14AL4_T2 0.00 0.00 6,342.00-8,063.61 1,140,502.96 6,020,223.00 1,656,728.00 70° 13' 21.947 N 140' 38' 4.902 W plan hits target center Point 3Q-14A_Fault2 0.00 0.00 0.00-7,824.181,140,775.51 6,020,463.00 1,657,000.00 70' 13' 23.867 N 140° 37' S6.038 W plan hits target center Rectangle (sides W310.00 H1.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 9,900.00 6,372.84 2-3/8" 2.375 3.000 511412014 2:26:37PM Page 4 COMPASS 2003.16 Build 69 R I G HNI A L 10-1 RFAI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox v16 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3Q Pad Well: 3Q-14 Welibore: 3Q-14AL4 Design: 3 Q-14 A L4_w p 01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3Q-14 Mean Sea Level 3Q-14 @ 60.00ft (3Q-14) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,305.00 6,359.54 -5,111.90 584.74 TIP/KOP 9,395.00 6,354.29 -5,168.95 515.46 Start 10 dls 9,465.00 6,348.99 -5,213.30 461.61 3 9,535.00 6,345.51 -5,260.36 409.97 4 9,605.00 6,342.56 -5,312.09 362.96 5 9,705.00 6,348.87 -5,384.71 294.70 6 9,900.00 6,372.84 -5,490.84 134.00 Planned TD at 9900.00 511412014 2:2637PM Page 5 COMPASS 2003.16 Build 69 !�h�,._ ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-14 3Q-14AL4 3Q-14AL4_wp01 Travelling Cylinder Report 12 May, 2014 Few FA I BAKER NUGNES V' MIN ConocoPhillips Travelling Cylinder Report BAMR HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3Q Pad Site Error: 0.00ft Reference Well: 3Q-14 Well Error: 0.00ft Reference Wellbore 3Q-14AL4 Reference Design: 3Q-14AL4_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3Q-14 30-14 @ 60.00ft (3Q-14) 3Q-14 @ 60.00ft (3Q-14) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Reference 3Q-14AL4_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,305.00 to 9,900.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,184.00ft Error Surface: Elliptical Conic Survey Tool Program Date 5/12/2014 From To (ft) (ft) Survey (Welibore) Tool Name Description 100.00 8,200.00 30-14 (3Q-14) BOSS -GYRO Sperry -Sun BOSS gyro multishot 8,200.00 9,305.00 3Q-14A_wp04 (3Q-14A) MWD MWD - Standard 9,305.00 9,900.00 3Q-14AL4_wp01 (3Q-14AL4) MWD MWD- Standard Casing Points Measured Vertical Depth Depth (ft) (ft) 9,900.00 6,432.84 2-3/8" Summary Site Name Offset Well - Welibore - Design Kuparuk 3Q Pad 3Q-06 - 3Q-06 - 3Q-06 3Q-06 - 30-06A - 3Q-06A 3Q-06 - 3Q-06AL1 - 3Q-06AL1 3Q-07 - 3Q-07 - 3Q-07 3Q-09 - 3Q-09 - 3Q-09 3Q-13 - 3Q-13 - 3Q-13 3Q-14 - 3Q-14A - 3Q-14A_wp04 3Q-14 - 3Q-14AL1 - 3Q-14AL1_wp01 3Q-14 - 3Q-14AL2 - 3Q-14A1_2_wp01 3Q-14 - 3Q-14AL3 - 3Q-14AL3_wp01 3Q-22 - 3Q-22 - 3Q-22 Name Casing Diameter 2-3/8 Hole Diameter 3 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) Out of range Out of range Out of range Out of range Out of range Out of range 9,324.99 9,325.00 0.47 0.90 -0.31 FAIL - Major Risk 9,324.99 9,325.00 0.47 0.90 -0.31 FAIL - Major Risk 9,324.99 9,325.00 0.47 0.90 -0.31 FAIL - Major Risk 9,324.99 9,325.00 0.47 0.90 -0.31 FAIL - Major Risk Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 511212014 10:13:22AM Page 2 of 7 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 30-14 Project: Kuparuk River Unit ND Reference: 3Q-14 @ 60,00ft (3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft (3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 30-14 Survey Calculation Method: Minimum Curvature Well Error. 0,00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14AL4 Database: EDM Alaska Prod v16 Reference Design: 3Q-14AL4_wp01 Offset ND Reference: Offset Datum Mras BAKER HUGHES Offset Design Kuparuk 3Q Pad - 3Q-14 - 3Q-14A - 3Q-14A_Wp04 Offset Site Error: 0.00 It Survey Program: 100-BOSS-GYRO, 8200-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis - Measured Vertical Measured Vertical Reference offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N1S +E1-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) Ift) (ft) (°) 00 (ft) (ft) (ff) 00 (ft) 9,324,99 6,419.59 9,325,00 6,420.00 0.07 0.09 80,71 -5,124.79 569.46 0.22 0,47 0,90 -0,31 FAIL- Major Risk, CC, ES, SF 9,349.86 6,418,69 9,350,00 6,420.74 0.15 0.19 80.76 -5,141,41 550.80 0.22 2,38 1.67 1.00 Pass - Major Risk 9,374A8 6,416.73 9,375,00 6,421.67 0.24 0,30 80.84 -5,158,56 532.64 0.22 5,75 2.37 3.90 Pass- Major Risk 9,398S4 6,413.78 9,400.00 6,422,87 0.33 0.42 79.91 -5,176,12 514.88 0.22 10,52 3.12 8.19 Pass - Major Risk 9,423.85 6,411.07 9,425.00 6,424,72 0,42 0.55 78.23 -5,193,48 496.99 0,22 15,47 3.94 12,66 Pass - Major Risk 9,449.14 6,409.44 9,450,00 6,427.26 0.51 0.69 77,06 -5,210.57 478.93 0.22 1994. 4.78 16.66 Pass - Major Risk 9,474.27 6,408.81 9,475.00 6,430,50 0.62 0.83 75.03 -5,227.39 460.71 0.22 23,99 5.64 20.26 Pass - Major Risk 9,498.57 6,407.93 9,500.00 6,434A3 0.71 0.97 69.42 -5,243,90 442.36 0.22 28,54 6.47 24.52 Pass - Major Risk 9,522.51 6,406.49 9,525.00 6,438,79 0,82 1.12 62Al -5,260,15 423.87 0.22 33.79 7,27 29.63 Pass - Major Risk 9,547.21 6,404.57 9,550.00 6,442,53 0,92 1.26 55.43 -5,276.36 405.21 0.22 38.84 8.07 34,63 Pass - Major Risk 9,573.16 6,403,16 9,575,00 6,445.52 1.03 1.40 48,69 -5,292.54 386.39 0.22 42,67 8,89 38.45 Pass - Major Risk 9,59922 6402.58 9,600.00 6,447.77 1.14 1,55 41.71 -5,308,67 367.42 0.22 45,20 9.68 40.93 Pass - Major Risk 9,625,37 6,402.S3 9,625,00 6,449,26 1.26 1.70 37,53 -5,324.73 348.32 0.22 46.54 10.64 41.82 Pass - Major Risk 9,651.80 6,403.96 9,650,00 6,450.00 1.38 1.85 34.92 -5,340.72 329.12 0.22 46,59 11,65 41.07 Pass - Major Risk 9,678.33 6405,96 9,675,00 6,450.13 1.51 2.02 32.59 -5,356.52 309.75 0.22 45,39 12.73 38.91 Pass - Major Risk 9,704.81 6,408.84 9,700,00 6,450.22 1.63 2.19 29.81 -5,371.77 289.94 0.22 43,59 13.82 35.95 Pass - Major Risk 9,730.11 6,412.01 9,725.00 6,450.35 1.77 2.38 27.29 -5,386,41 269.68 0.22 41.66 14.99 32.72 Pass - Major Risk 9,755.56 6,415.20 9,750.00 6,450.50 1.90 2.57 24.82 -5,400,43 248.97 0.22 39.94 16.18 29,57 Pass - Major Risk 9,781.15 6,418,38 9,775.00 6,450,68 2.05 2.78 22.45 -5413.80 227.85 0.22 38.36 17.41 26.46 Pass - Major Risk 9,806.86 6,421.57 9,800,00 6,450,89 2.20 2.99 2021 -5,426,52 206.34 022 36.S9 18.63 23.39 Pass - Major Risk 9,832.66 6,424.74 9,825.00 6,451.12 2.36 3,21 18,13 -5,438.58 184.44 0.22 35.4E 19.89 20.30 Pass - Major Risk 9,858.54 6,427.88 9,850.00 6,451,39 2.52 3.43 16,22 -5,449.97 162A9 0.22 34.08 21.12 17,20 Pass - Major Risk 9,884.47 6,431.00 9,875.00 6,451 67 2,69 3.65 14.76 -5,460.91 139.71 0.22 32.43 22.35 13,89 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 511212014 10:13:22AM Page 3 of 7 COMPASS 2003.16 Build 69 ORIGINAL 10- ri.S ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3Q-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft (3Q-14) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-14 @ 60.00ft (3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0,00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-14AL4 Database: EDM Alaska Prod v16 Reference Design: 3Q-14AL4_wp01 Offset TVD Reference: Offset Datum Offset Design Kuparuk 3Q Pad - 3Q-14 - 3Q-14AL1 - 3Q-14AL1_wp01 onset site Error: 0.00 ft Survey Program: 100-BOSS-GYRO, 8200-MWD, 10750-MWD Rule Assigned: Major Risk Offset Well Error: 0.00 ft 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 +N1-S +EI-W Hole Size Centre Distance Deviation (ft) Ift) Iff) Iffj (n) (n) 1°) Iffl (ff) Iff) Iffl (ff) (ff) 9,324,99 6,419.59 9,325,00 6,420.00 0.07 0,09 80.71 -5,124.79 569A6 0.22 0.47 0.90 -0.31 FAIL - Major Risk, CC, ES, SF 9,349.86 6,418.69 9,350,00 6,420.74 0.15 0.19 80.76 -5,141.41 550.80 0.22 2,38 1.67 1.00 Pass - Major Risk 9,374.48 6,416.73 9,375.00 6421.67 0,24 0.30 80,84 -5,158.56 532.64 0.22 5.75 2.37 3.90 Pass - Major Risk 9,398.84 6,413.78 9,400.00 6.422,87 0.33 0.42 79,91 -5,176.12 514,88 0,22 10.52 3,12 8.19 Pass - Major Risk 9,423.85 6,411.07 9,42500 6,424,72 0.42 0,55 78.23 -5,193.48 496.99 0.22 15.47 3.94 12.66 Pass - Major Risk 9,449.14 6,409.44 9,450.00 6,427.26 0.51 0.69 77,06 -5,210.57 478.93 0.22 19.94 4.78 16.66 Pass - Major Risk 9,474.27 6,408.81 9,475.00 6,430,50 0,62 0.83 75,03 -5,227.39 460,71 0,22 23.99 5,64 20.26 Pass - Major Risk 9,498.57 6,407.93 9,50a00 6.434.43 0.71 0,97 69,42 -5,243,90 442.36 0.22 28.54 6,47 24.52 Pass - Major Risk 9,522.51 6,406.49 9,525.00 6,438.79 0.82 1.12 62,41 -5,260.15 423.87 0.22 33.79 7.27 29.63 Pass - Major Risk 9,547.21 6,404.57 9,550,00 6,442.53 0.92 1.26 55.43 -5,276,36 405.21 0,22 38.84 8.07 34.63 Pass - Major Risk 9,573.16 6,403.16 9,575.00 6,445.52 1.03 1.40 48.69 -5,292.54 386.39 0,22 42.67 8,89 38.45 Pass - Major Risk 9,599,22 6,40258 9,600,00 6,447.77 1,14 1.55 41.71 -5,308.67 367,42 0.22 45,20 9.68 40.93 Pass - Major Risk 9,625.37 6,402,83 9,625,00 6,449.26 1.26 1.70 37.53 -5,324,73 348,32 0.22 46.54 10.64 41.82 Pass - Major Risk 9,651.80 6,403,96 9650.00 6,450.00 1.38 1,85 34.92 -5,340.72 329.12 0,22 46.59 11,65 41.07 Pass Major Risk 9,678.33 6,405.96 9,675,00 6,450.13 1.51 2.02 32.59 -5,356.52 309.75 0.22 45.39 12,73 38.91 Pass - Major Risk 9,704,81 6,408S4 9,700,00 6.450,22 1,63 2.19 29,81 -5,371.77 289.94 0,22 43,59 13,82 35.95 Pass - Major Risk 9,730.11 6,412.01 9,725.00 6,450,35 1.77 2,38 27,29 -5,386.41 269.68 0,22 41.66 14,99 32.72 Pass - Major Risk 9,755.56 6,415.20 9,750.00 6,450.50 1.90 2.57 24,82 -5,400.43 248.97 0.22 39.94 16.18 29.57 Pass - Major Risk 9,781.15 6,418.38 9,775,00 6,450,68 2.05 2.78 22.45 -5,413.80 227.85 0,22 38.36 17,41 26.46 Pass - Major Risk 9,806,86 6,421.57 9,800,00 6450.89 2.20 2.99 20.21 -5,426.52 206.34 0.22 36.89 1863 23.39 Pass - Major Risk 9,832,66 6,424.74 9,825.00 6,451.12 2.36 3.21 18.13 -5,438.58 184.44 0.22 35.48 1989. 20.30 Pass - Major Risk 9,858.54 6,427.88 9,850.00 6,451,39 2.52 3.43 16.22 -5,449.97 162.19 0,22 34.08 21.12 1Z20 Pass - Major Risk 9,884.47 6,431.00 9,875.00 6,451.67 2.69 3.65 14,76 -5,460.91 139,71 0.22 32,43 22.35 13,89 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 511212014 10:13:22AM Page 4 of 7 COMPASS 2003.16 Build 69 0- RIGINAL ConocoPhillips Travelling Cylinder Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 30-14 Project: Kuparuk River Unit TVD Reference: 3Q-14 @ 60.00ft (3Q-14) Reference Site: Kuparuk 3Q Pad MO Reference: 3Q-14 @ 60.00ft (3Q-14) Site Error: 0.00ft North Reference: True Reference Well: 3Q-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore 3Q-14AL4 Database: EDM Alaska Prod v16 Reference Design: 3Q-14AL4_wp01 Offset TVD Reference: Offset Datum FCC .I BAKER HUGHES Offset Design Kuparuk 3Q Pad - 3Q-14 - 3Q-14AL2 - 3Q-14AL2_wp01 Offset Site Error: 0.00 ft Survey Program: 100-BOSS-GYRO, 8200-MWD, 10150-MWD Rule Assigned: Major Risk Onset Well Error: 0,00 It 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 (ft) (ff) Ift) (h) (ft) (ft) (°) (n) (ft) (ft) (f) (ft) (ft) 9,324.99 6,419.59 9,325.00 6,420.00 0.07 0.09 80,71 -5,124.79 569.46 0.22 0.47 0.90 -0.31 FAIL- Major Risk, CC, ES, SF 9,349.86 6,418.69 9,350.00 6,420.74 0.15 0.19 80.76 -5,141.41 550.80 0.22 2.38 1.67 1.00 Pass - Major Risk 9,374.48 6,416.73 9,375.00 6,421.67 0.24 0.30 80.84 -5,158.56 532.64 0.22 5.75 2.37 3.90 Pass - Major Risk 9,398.84 6,413.78 9,400.00 6,422.87 0.33 0.42 79.91 -5,176.12 514.88 0.22 10.52 3.12 8.19 Pass - Major Risk 9,423.85 6,411.07 9,425.00 6,424.72 0.42 0.55 78.23 -5,193.48 496.99 0.22 15.47 3.94 12.66 Pass - Major Risk 9,449.14 6,409.44 9,450.00 6,427.26 0.51 0.69 77.06 -5,210.57 478.93 0.22 19.94 4.78 16.66 Pass - Major Risk 9,474.27 6,408.81 9,475.00 6,430.50 0.62 0.83 75.03 -5,227.39 460.71 0.22 23.99 5.64 20.26 Pass - Major Risk 9,498.57 6,407.93 9,500.00 6,434.43 0.71 0.97 69.42 -5,243.90 442.36 0.22 28.54 6.47 24.52 Pass - Major Risk 9,522.51 6,406.49 9,525.00 6,438.79 0.82 1.12 62.41 -5,260.15 423.87 0.22 33.79 7.27 29.63 Pass - Major Risk 9,547.21 6,404.57 9,550.00 6,442.53 0,92 1.26 55.43 -5,276.36 405.21 0.22 38.84 8.07 34.63 Pass - Major Risk 9,573.16 6,403.16 9,575.00 6,445.52 1,03 1.40 48.69 -5,292.54 386.39 0.22 42.67 8.89 38.45 Pass - Major Risk 9,599.22 6,402.58 9,600.00 6,447.77 1.14 1.55 41.71 -5,308.67 367.42 0.22 45.20 9.68 40.93 Pass - Major Risk 9,625.37 6,402.83 9,625.00 6,449.26 1.26 1.70 37.53 -5,324.73 348.32 0.22 46.54 10.64 41.82 Pass - Major Risk 9,651.80 6,403.96 9,650.00 6,450.00 1.38 1.85 34.92 -5,340.72 329.12 0.22 46.59 11.65 41.07 Pass - Major Risk 9,678.33 6,405.96 9,675.00 6,450.13 1.51 2.02 32.59 -5,356.52 309.75 0.22 45.39 12.73 38.91 Pass - Major Risk 9,704.81 6,408.84 9,700.00 6,450.22 1.63 2.19 29.81 -5,371.77 289.94 0.22 43.59 13.82 35.95 Pass- Major Risk 9,730.11 6,412.01 9,725.00 6,450.35 1.77 2.38 27.29 -5,386.41 269.68 0.22 41.66 14.99 32.72 Pass - Major Risk 9,755.56 6,415.20 9,750.00 6,450.50 1.90 2.57 24.82 -5,400.43 248.97 0.22 39.94 16.18 29.57 Pass - Major Risk 9,781.15 6,418.38 9,775.00 6,450.68 2.05 2.78 22.45 -5,413.80 227.85 0.22 38.36 17.41 26.46 Pass - Major Risk 9,806.86 6,421.57 9,800.00 6,450.89 2.20 2.99 20.21 -5,426.52 206.34 0.22 36.89 18.63 23.39 Pass - Major Risk 9,832.66 6,424.74 9,825.00 6,451.12 2.36 3.21 18.13 -5,438.58 184.44 0.22 35.48 19.89 20.30 Pass - Major Risk 9,858.54 6,427.88 9,850.00 6,451.39 2.52 3.43 16.22 -5,449.97 162.19 0.22 34.08 21.12 17.20 Pass - Major Risk 9,884.47 6,431.00 9,875.00 6,451.67 2.69 3.65 14.76 -5,460.91 139.71 0.22 32.43 22.35 13.89 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation &1212014 10:13:22AM Pa e 5 of 7 COMPASS 2003.15 Build 69 Y 'G NAB ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3Q Pad Site Error. 0.00ft Reference Well: 3Q-14 Well Error. 0.00ft Reference Wellbore 3Q-14AL4 Reference Design: 3Q-14AL4_wp01 Offset Design Survey Program: Reference Measured Vertical Depth Depth (ft) (ft) 9,324s9 6,419.5 9,349.86 6,418.6 9,374.48 6,416.7 9,398.84 6,413.7 9,423.85 6,411.0 9.449.14 6.409.4 9,474.27 6,408.8 9,498.57 6,407.9 9,522.51 6,406.4 9,54Z21 6.404.5 9,573,16 6,403.1 9,599.22 6,402.5 9,625.37 6,402.8 9,651.80 6,403.9 9,678.33 6,405.9 9,704.81 6,408.8 9,730.11 6,412.0 9,755.56 6,415.2 9,781.15 6,418.3 9.806,86 6,421.5 9,832,66 6,424.7 9,858.54 6,427.8 9,884.47 6,431.0 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Kuparuk 3Q Pad - 3Q-14 - 3Q-14AL3 - 3Q-14AL3_wp01 100-BOSS-GYRO, 8200-MWD, 10080-MWD Offset Semi Major Axis Measured Vertical Reference Onset Toolface+ Offset Wellbore Centre Depth Depth Azimuth +N/S +E(-W (ft) (R) (ft) (ft) V) (ft) (ft) 9 9,325,00 6,420,00 0.07 0.09 80.71 -5,124,79 569,46 9 9,350.00 6,420.74 0,15 0.19 80.76 -5,141,41 550.80 3 9,375.00 6,421.67 0.24 0.30 80.84 -5,158.56 532,64 8 9,400.00 6,422.87 0.33 0.42 79.91 -5,176.12 514,88 7 9,425.00 6,424.72 042 0.55 78.23 -5,193.48 49699 4 9,450,00 6,427.26 0.51 0.69 77.06 -5,210,57 478,93 1 9,475.00 6,430.50 0,62 0.83 75,03 -5,227.39 460.71 3 9,500.00 6,434.43 0.71 0.97 69,42 -5,243.90 442.36 9 9,525,00 6,438.79 0.82 1_12 62.41 -5,260.15 423.87 7 9,550.00 6,442.53 0.92 1.26 55.43 -5,276.36 405,21 6 9,575.00 6445,52 1,03 1.40 48.69 -5,292,54 386.39 8 9,600.00 4 1 0 8 7 4 8 0 6,447+77 1.14 1.55 41.71 3 9,625.00 6,449,26 1.26 1,70 37.53 6 9,650.00 6,450,00 1,38 1.85 34,92 6 9,675,00 6,450.13 1.51 2.02 32.59 9,700.00 6,450.22 1,63 2.19 29.81 9,725.00 6,450.35 1.77 2.38 27.29 9,750.00 6,450,50 1.90 2.57 24.82 9,775.00 6,450.68 2.05 2,78 22.45 9,800,00 6,450.89 2.20 2.99 20.21 9,825.00 6,451.12 2.36 3,21 18.13 9,850.00 6,451.39 2,52 3.43 16.22 9,875.00 6,451,67 2,69 3.65 14.76 Well 3Q-14 3Q-14 @ 60.00ft (3Q-14) 3Q-14 @ 60,00ft (3Q-14) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Offset Site Error: 0.00 ft Rule Assigned: Major Risk Offset Well Error: 0.00It Casing - Hole Size (ft) 0,22 0.22 0.22 0.22 0,22 0,22 0,22 0.22 0,22 0.22 0.22 Centre to Centre Ift) 0.47 2.38 5.75 10.52 15A7 19.94 23.99 28.54 33.79 38.84 42,67 -5.308.67 367.42 0.22 45,20 -5,324.73 348.32 0.22 46.54 -5,340.72 329,12 0.22 46.59 -5,356.52 309.75 0.22 45.39 -5,371,77 289.94 0.22 43,59 -5,386.41 269.68 0.22 41.66 -5,400.43 248,97 0.22 39.94 -5,413.80 227.85 0.22 38.36 -5,426.52 206,34 0.22 36.89 -5,438.58 184,44 0.22 35.48 -5,449,97 162,19 0,22 34.08 -5,460.91 139,71 0.22 32.43 No Go Allowable Warning Distance Deviation (ft) (ft) 0.90 -0,31 FAIL- Major Risk, CC, ES, SF 1.67 1.00 Pass - Major Risk 2,37 3.90 Pass - Major Risk 3,12 8.19 Pass - Major Risk 3.94 12.66 Pass - Major Risk 4,78 16,66 Pass - Major Risk 5,64 20.26 Pass - Major Risk 6A7 24.52 Pass - Major Risk 7,27 29.63 Pass - Major Risk 8.07 34.63 Pass - Major Risk 8.89 38.45 Pass - Major Risk 9.68 40.93 Pass - Major Risk 10,64 41.82 Pass - Major Risk 11.65 41.07 Pass - Major Risk 12.73 38,91 Pass - Major Risk 13.82 35.95 Pass - Major Risk 14.99 32.72 Pass - Major Risk 16.18 29.57 Pass - Major Risk 17,41 26A6 Pass - Major Risk 18,63 23,39 Pass - Major Risk 19.89 20.30 Pass - Major Risk 21.12 17.20 Pass - Major Risk 22,35 13.89 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 511212014 10:13:22AM Page 6 of 7 COMPASS 2003.16 Build 69 ORIGINAL Vedas ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3Q Pad Site Error. 0.00ft Reference Well: 3Q-14 Well Error: 0.00ft Reference Wellbore 3Q-14AL4 Reference Design: 3Q-14AL4_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3Q-14 3Q-14 @ 60.00ft (3Q-14) 3Q-14 @ 60.00ft (3Q-14) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Reference Depths are relative to 3Q-14 @ 60.00ft (3Q-14) Coordinates are relative to: 30-14 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is: 0.12' Ladder Plot 60 45 C 120 cU Q U) N 30 U 0 a� C N U 15 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND —Ar-- 3Q-14, 3Q-14A, 3Q-14A wp04 VO 3Q-14, 3Q-14AL2, 3Q-14AL2 wp01 VO —8- 3Q-14,3Q-14AL1,3Q-14AL1_wp01 VO $ 3Q-14,3Q-14AL3,3Q-14AL3_wp01 VO I I I I I 1 I I I I I I i 1 I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I i I I I I I I 1 I I 1 I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I 1 I i I I I I i I I I I I I I I I I I I I 1 I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ! I I I I I I I I I I I I I I I I I I I I I 1 I I I CC -Min \\ -i6 \ )§/ \ )/ � ]§ \ / 04 )§§ggqqm § {w ¥�2&&&22 _ _ ( ]/ \ )5§5§\)§ 0r ZLO CN S 78 ®� ° a \ mG@a2@2 g q ui i ui M-M-/ \§ /\ _,eas _. (u!q£d m&G[eo *o o I \ WELL NAME: PTD: oC 1 y O 16 "Development Service Exploratory Stratieraphic Test Non -Conventional FIELD: POOL: Ktni.11` ��y�J'. /�t�1lGJtnl�iJ✓,J— �/1 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 (If last two digits No. a l V OE )_ -1 API No. 50- 0Z j_-� ) 6(oS - o f - bD. in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation 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 Well Logging also required for this well: 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 4/2014 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2140860 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 30-14AL4 Program DEV Well bore seg d DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025512. entire wellbore 3 Unique well name and number Yes KRU 3Q-14AL4 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order 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 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes PKB 6/19/2014 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),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in 3Q-14 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 3Q-14 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 steel 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 performed; major failures with laterals in same producing interval 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pres is 4378 psi(13.2 ppg EMW); will drill w/ 9.2 ppg EMW and maintain overpressure w/ MPD VLF 6/20/2014 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3728 psi; will test BOPs to 4200 psi 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 H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Well on 3Q-Pad are H2S bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 7.3 ppg EMW, but may range to 13.23 ppg; will be drilled using 9.2 ppg mud Appr Date 37 Seismic analysis of shallow gas zones NA and MPD technique. Two_wellbore volumes of at least 13.1 ppg KWF will be available. PKB 6/19/2014 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly_ progress reports_ [exploratory only] NA Onshore development_ well. Geologic Engineering Public Commissioner: Date: Commissioner, Date Commissioner Date ]CIS i�li'
