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215-021
1 Guhl, Meredith D (CED) From:Guhl, Meredith D (DOA) Sent:Tuesday, April 4, 2017 10:14 AM To:Starck, Kai Cc:Loepp, Victoria T (DOA); Bettis, Patricia K (DOA) Subject:KRU 1L-04B L1, PTD 215-021, Permit Expired Kai, Permit to Drill 215‐021, for Kuparuk River Unit 1L‐04B L1, issued 4 February 2015, has expired under Regulation 20 AAC 25.005 (g). The PTD 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. 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 °fALAS-KA GOVERNOR BILL WALKER D. Venhaus CTD Engineering Supervisor 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 ww\v.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-04BL1 ConocoPhillips Alaska, Inc. Permit No: 215-021 Surface Location: 403' FSL, 144' FEL, SEC. 30, T11N, RI OE, UM Bottomhole Location: 1460' FSL, 1194' FEL, SEC. 30, T11N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 215-020, API No. 50-029- 21179-02-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2015. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 EDEIVED FEB 0 2 9015 1a. Type of Work: 1 b. Proposed Well Class: Development - Oil ❑' Service - Winj ❑ Single Zone ❑ ' Drill Lateral Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Redrill ❑ Reentry 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: KRU 1L-04BL1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10575' + TVD: 6054' - 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 403' FSL, 144' FEL, Sec. 30, T11 N, R10E, UM - Top of Productive Horizon: 1482' FNL, 1121' FEL, Sec. 30, T11 N, R10E, UM Total Depth: 1460' FSL, 11 94'FEL, Sec. 30, T11 N, R10E, UM 7. Property Designation (Lease Number): ADL 25659 8. Land Use Permit: 2585 13. Approximate Spud Date: 2/2/2015 9. Acres in Property: 2490 14. Distance to Nearest Property: 18630 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 539915 y- 5949371 Zone- 4 . 10. KB Elevation above MSL: 116 feet GL Elevation above MSL: 86 feet 15. Distance to Nearest Well Open to Same Pool: 1 L-02 , 370' 16. Deviated wells: Kickoff depth: 8100 ft. Maximum Hole Angle: 100' deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4135 psig Surface: 3531 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 3455' 7120' 5902' 10575' 6054' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 7668 Total Depth TVD (ft): 6371 Plugs (measured) none Effective Depth MD (ft): 1 7538 Effective Depth TVD (ft): 6259 Junk (measured) 7134 Casing Length Size Cement Volume MD TVD Conductor/Structural 65' 16 210 sx Cold Set II 96' 96, Surface 2312' 9.625 830 sx AS III, 250 sx Cl G 2343' 2243' Intermediate Production 7597' 7 600 sx Class G, 150 sx AS 1 7625' 6334' Liner Perforation Depth MD (ft): 7201'-7214', 7316'-7331', 7347'-7377' Perforation Depth TVD (ft): 1 5971'-5982', 6070'-6082', 6096'-6122' 20. Attachments: Property Plat ❑ BOP Sketcl- ❑ Drilling Program a Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Gary Eller @ 263-4172 Email J.Gary. Eller(a)cop.com Printed Name D. 7Venus Title CTD Engineering Supervisor Signature Phone: 263-4372 Date Commission Use Only Permit to Drill Number: p2 1 S- Qp2r API Number: 50- ©'°� 1 ., al _ GS —dt4 Permit Approval / Date: 15 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 . thane, gas hydrates, or gas contained in shales: Other:'0a P ��S fi f p of,C' 5 f Samples req'd: Yes ❑ No [ Mud log req'd: Yes❑ No U vt✓7It t f z'S H2S measures: Yes 2 No Directional svy req'd: Yes M No ❑ fo Z Sac'PS r Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No [� _ APPROVED BY THE "-7 �- Approved by: v COMMISSIONER OM ISSION Date: Form 10,401 (Revised )7 /!T� permit id v i r j4tjntj1j e Pate of approgl,0 AA,Cg2¢;0�05(g)) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 2, 2015 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ECEIVIED FEB 0 2 2015 AOGCV ConocoPhillips Alaska, Inc. has experienced complications while drilling the KRU 1 L-04A sidetrack (214-158) that have forced us to abandon drilling efforts of all coiled tubing drilling laterals to the north of 1 L-04. We are progressing with drilling of the previously planned southern laterals, but the loss of the planned 'A' sidetrack requires that the names of these southern laterals be changed so that production can ultimately be properly booked to this well. Accordingly, ConocoPhillips requests the AOGCC to do the following: • Please cancel the drilling permits for KRU 1 L-04AL3 (214-161) and 1 L-04AL3-01 (214-162) • Please approve replacement permit -to -drill applications 1 L-04B and 1 L-04BL1, respectively. Please note that these replacement permit -to -drill applications are identical to the previously approved applications for 1 L-04AL3 and 1 L-04AL3-01 except for the naming convention. Window milling of the 1 L-04B sidetrack is expected to commence on February 3, 2015 (i.e. tomorrow) so your prompt attention to this matter is greatly appreciated. Attached to this application are the following documents: — 10-401 Applications for 1 L-04B and 1 L-04BL1 — Detailed Summary of Operations (revisions shown in red) — Directional Plans for 1 L-04B and 1 L-04BL1 — Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-263-4172. Sin. rely, �1 Gary Eller ConocoPhillips ska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NA13011S ALASKA Dn Uling 1q 1 L-04A, AL4, AL1, AL29 B & BL1 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............................................................................................................. 5 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 5 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 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050 b 7 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plan for 1L-04B & BL1............................................................................................................7 Attachment2: Current Well Schematic...........................................................................................................................7 Attachment 3: Proposed Well Schematic for 1 L-04B CTD Laterals................................................................................7 3�+�- Page 1 of 7 February 02, 2015 PTD Application: 'I L-04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04BL1 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-04A, i i_- 6=4 \i_= ; 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L- 04131-1. 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 the attached 10-401 form for surface and subsurface coordinates of the 1 L-04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04131-1. 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 4000 psi. Using the maximum formation pressure in the area of 4135 psi in well 1 L-05, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3531 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 1 L-04 in June 2014 indicated a reservoir pressure of 2796 psi or 8.9 ppg equivalent mud weight. The maximum down hole pressure in the 1 L-04 pattern is at 1 L-04. The highest pressure in an offset well is at the 1 L-05 injector to the east with 4135 psi, or 13.1 ppg EMW. Using the 1 L-05 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3531 psi. We do not expect to encounter this magnitude of formation pressure while drilling the 1 L-04 laterals since they are oriented drilled north -south along a line of producers. In fact, it's likely that we will drill into areas of reduced formation pressure. Well 1 F-09 to the north recently measured A -sand formation pressure of 7.3 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled but both the 1 L and 1 F pads are active gas injection sites. There is a distinct potential that free gas could be associated with any formation influx. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) An expected risk of 1 L-04 is the hole stability through the A5 & A4 basal shales. We will use MPD techniques to target a constant 11.4 ppg formation pressure while drilling and completing all laterals. There is a risk of differential sticking since we're drilling into areas of reduced formation pressure. There are limited backup window exit locations in 1 L-04. 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(o, thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7(GINA L February 02, 2015 PTD Application: 1 L-04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04131_1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Name MD MD TVDSS TVDSS Liner Details 1L-04A 8020' 8850' 5983' 5984' No liner just anchored aluminum billet 1 L-04AL4 10300' 11700' 5983' 6000' 2%", 4.7#, L-80, ST-L slotted liner; with aluminum billet 1 L-04ALl 8100' 11700' 6094' 6078' 23/", 4.7#, L-80, ST-L slotted liner; with aluminum billet 1 L-04AL2 7240' 10200' 6004' 6064' 23/ , 4.7#, L-80, ST-L slotted liner with deployment sleeve 1 L-04B 8100' 10550' 6134' 6095' 23/", 4.7#, L-80, ST-L slotted liner; with aluminum billet 1 L-04BL1 7120' 10575' 5902' 6054' 2% , 4.7#, L-80, ST-L slotted liner with deployment sleeve Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.50 H-40 Welded 0' 96' 0' 96' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 0' 2343' 0' 2243' 3520 2020 Casing 7" 26 J-55 BTC 0' 7625' 0' 6334' 4980 4320 Tubing 3 %2" 9.3 L-80 EUE-MOD 0' 1 7092' 0' 5879' 1 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. 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 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 (9.6 ppg) — Drilling operations: Chloride -based Flo -Pro mud (9.6 ppg). This mud weight should hydrostatically overbalance reservoir pressure. However, if increased formation pressure is encountered then overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 L-04 does not contain a subsurface safety valve (SSSV). The well will be loaded with 11.6 ppg NaBr completion fluid in order to provide formation over -balance while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-285 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. 1I�IL Page 3 of 7 February 02, 2015 PTD Application: I L-04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04131-1 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, 11.4 ppg has been identified as the minimum EMW to ensure stability of shale sections. 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 IL-04A Window (7250' MD, 6013' TVD) Usina MPD Pumps On 1.5 bpm Pumps Off A -sand Formation Pressure (8.9 pp) 2783 psi 2783 psi Mud Hydrostatic 9.6 p) 3002 psi 3002 psi Annular friction (i.e. ECD, 0.060 psi/ft) 435 psi 0 psi Mud + ECD Combined 3437 psi 3386 psi (no choke pressure) (overbalanced (overbalanced —650psi) —220 psi) Target BHP at Window (11.4 p 3564 psi 3564 psi Choke Pressure Required to Maintain 130 psi 560 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is not for an exploratory or stratigraphic test 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. Page 4 of 7 ""`j N February 02, 2015 PTD Application: '► L-04A, 1 L-04AL41 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04BL1 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1L-04 is a Kuparuk A -sand producer (development) well equipped with 31/2" tubing and 7" production casing. Six laterals from well 1L-04 will be drilled, four to the north (IL-04A, AL4, AL1, & AL2) and two to the south (1L-04B & BL1) to augment A sand production from 1F-09 to the north and 1L-02 to the south. Operations will target the A4 and A5 sand intervals. Well 1L-04 was completed into the Kuparuk A and C-sand intervals in 1984 as a commingled single completion. In 1998 the C-sand perfs were cement squeezed to make an A -only producer. A RWO was performed earlier this year to replace the existing tubing with a stacked packer completion above the failed packer and change the IC packoffs. Prior to CTD operations, the existing A -sand perfs in will be squeezed with cement to provide a means to kick out of the 7" casing. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. Immediately prior to cementing the A -sand perfs, the D-nipple at 7128' MD will be milled out to a 2.80" ID and the tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A -sand perfs with cement pre -rig, the Nabors CDR2-AC drilling rig will drill a pilot hole to 7280' and set a whipstock in the 2.80" pilot hole at the planned kickoff point. All northern laterals will exit through the 7" casing at 7240' MD and will target the A4 & A5 sands. All southern laterals will exit through a second exit in the 7" casing at 7225' MD and will also target the A4 & A5 sands. The laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 3'/2" tubing. Pre-CTD Work 1. Slickline: Dummy all GLVs. 2. E-line: Shoot 2' of holes in the 3'/2" tubing tail at 7120' MD. 3. Coil: Mill out Cameo D-nipple at 7128' MD to 2.80" 4. Coil: Cement squeeze the A -sand perfs bringing cement up into the tubing tail. 5. Slickline: Drift tubing, 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. IL-04A Sidetrack (A4 sand - north) a. Drill 2.80" high -side pilot hole through cement to 7280' MD b. Caliper pilot hole c. Set whipstock at 7250' MD (actually set 7240' due to hole problems) d. Mill 2.80" window at 7250' MD (TOWS at 7240') e. Drill 31/4" bi-center lateral to TD of 11,700' MD (could not drill past fault at 8850') f. Run 2%" slotted liner with an aluminum billet from TD up to 10,300' MD (Plan to set an anchored billet at 8020' MD but, did not run liner since we plan to drill in the same sand just to the east. 1 L-04A expected to remain open to production without any liner installed) Page 5 of 7 n I GINAL February 02, 2015 PTD Application: 'I L-04A, 1 L-04AL4, 1 L-04AL1, 1 L-04AL2, 1 L-04B & 1 L-04BL1 3. 1L-04AL4 Lateral (A4 sand - north) a. Kick off of the aluminum billet at 8,020' MD b. Drill 3!4" hi -center Lateral to TD of 1 1,700' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,300' MD 4. IL-04AL1 Lateral (A5 sand - north) a. Kick off of the aluminum billet at 10,300' MD b. Drill 3'/4" bi-center lateral to TD of 11,700' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD 5. IL-04AL2 Lateral (A5 sand - north) a. Kickoff of the aluminum billet at 8100' MD b. Drill 3'/4" bi-center lateral to TD of 10,200' MD c. Run 2%" slotted liner from TD up to 7240' MD 6. IL-04B Lateral (A4 sand - south) a. Set whipstock at 7230' MD b. Mill 2.80" window at 7230' MD c. Drill 3" bi-center lateral to TD of 10,550' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD 7. 1L-04BL1 Lateral (A5 sand - south) a. Kickoff of the aluminum billet at 8100' MD b. Drill 3" bi-center lateral to TD of 10,575' MD c. Run 2%" slotted liner from TD up to 7120' MD, inside the 3'/z" tubing tail 8. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return 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. — 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. Page ,,,,, ORIGINAL February 02, 2015 PTD Application: , L-04A, 1 L-04AL -, 1 L-04AL1, 1 L-04HL2, 1 L-04B & 1 L-04131_1 — 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 Runnings — The 1 L-04 CTD laterals will be displaced to an overbalancing fluid (11.6 ppg NaBr) prior to running liner. See the "Drilling Fluids" section for more details. — While running 2%" 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 (1R-18 or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional 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 and nearest well in the same pool. Sidetrack Name Directional Plan Distance to Unit Boundary Distance to Nearest Well Nearest Well 1 L-04A 06 23,745' 340' 1 F-09 1 L-04AL4 01 23,745' 605' 1 F-09 1 L-04AL1 06 23,745' 350' 1 F-09 1 L-04AL2 06 23,745' 380' 1 F-09 1 L-04B 10 18,630' 345' 1 L-02 1 L-04BL1 10 18,630' 370' 1 L-02 16. Attachments Attachment 1: Directional Plan for 1 L-04B & BL 1 Attachment 2: Current Well Schematic Attachment 3: Proposed Well Schematic for IL-04B CTD Laterals Page 7 of 7 ORIGINAL February 02, 2015 W �W� a N Q. s �a 0 0 c 0 U (ui/gsn 00£) (+)uuoN/(-)u;noS ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1 L Pad 1 L-04 Standard Planning Report 02 October, 2014 WE RI BAKER HUGHES ORIGINAL ConocoPhillips Planning Report Database: EDM Alaska Sandbox Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1L Pad North Reference: Well: 1 L-04 Survey Calculation Method: Wellbore: tb-�-9 94 Design: _ Well 1 L-04 Mean Sea Level 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature roject Kuparuk River Unit, North Slope Alaska, United States ap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using geodetic scale factor //.&I BAKER HUGHES Site Kuparuk I 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-04 Well Position +N/-S +E/-W Position Uncertainty 0.00 usft Northing: 5,949,370.89 usft 0.00 usft Easting: 539,914.96 usft 0.00 usft Wellhead Elevation: usft Wellbore 4 6 94"'Ing 94 Magnetics Model Name Sample Date Declination BGGM2014 12/1/2014 19.12 Design -11 ndni "4r:WpQ2 Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/-S (usft) (usft) 0.00 0.00 Plan Sections Measured TVD Below Depth Inclination Azimuth System +N/-S +E/-W (usft) (°) (°) (usft) (usft) (usft) 8,100.00 91.43 145.96 5,981.54 3,298.77 -447.96 8,185.00 99.93 145.96 5,973.13 3,228.74 -400.66 8,255.00 99.61 153.06 5,961.23 3,169.34 -365.68 8,345.00 91.44 156.85 5,952.57 3,088.25 -327.82 8,470.00 90.76 169.34 5,950.16 2,968.91 -291.55 8,595.00 91.06 181.83 5,948.17 2,844.55 -281.95 8,975.00 92.19 219.83 5,936.96 2,496.01 -414.54 9,275.00 90.05 189.90 5,930.95 2,226.97 -539.21 9,625.00 87.18 224.80 5,939.68 1,920.97 -697.42 9,975.00 90.55 189.95 5,946.85 1.615.01 -855.77 10,225.00 90.96 214.95 5,943.50 1,385.81 -950.46 10,575.00 90.79 179.94 5,937.98 1,057.11 -1,053.76 Latitude: 700 16' 21.420 N Longitude: 149° 40' 37.789 W Ground Level: 0.00 usft Dip Angle Field Strength (°) (nT) 80.89 57,571 Tie On Depth: +E/-W (usft) 0.00 Dogleg Rate (°/100ft) 0.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 Build Rate (°/100ft) 0.00 10.00 -0.45 -9.08 -0.55 0.25 0.30 -0.71 -0.82 0.96 0.17 -0.05 8,100.00 Direction (°) 315,09 Turn Rate (°1100ft) 0.00 0.00 10.14 4.21 9.99 10.00 10.00 -9.98 9.97 -9.96 10.00 -10.00 TFO 0.00 0.00 92.00 155.00 93.00 88.50 87.80 266.30 95.00 275.00 88.90 270.00 Target 101212014 12:54:49PM Page 2 COMPASS 5000.1 Build 61 n RI rulNAL ConocoPhillips Planning Report rigs BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 L-04 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-04 @ 116.00usft (1 L-04) Site: Kuparuk 1 L Pad North Reference: True Well: 1L-04 Survey Calculation Method: Minimum Curvature Wellbore: 1+6 94 Design: I Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 8,100.00 91.43 145.96 5,981.54 3,298.77 -447.96 2,652.54 0.00 0.00 5,952,666.92 539,449.56 TIP/KOP 8,185.00 99.93 145.96 5,973.13 3,228.74 -400.66 2,569.55 10.00 0.00 5,952,597.15 539,497.22 Start 10 dls 8,200.00 99.87 147.49 5,970.55 3,216.39 -392.55 2,555.08 10.00 92.00 5,952,584.84 539,505.39 8,255.00 99.61 153.06 5,961.23 3,169.34 -365.68 2,502.79 10.00 92.26 5,952,537.93 539,532.51 3 8,300.00 95.53 154.97 5,955.31 3,129.25 -346.15 2,460.60 10.00 155.00 5,952,497.95 539,552.25 8,345.00 91.44 156.85 5,952.57 3,088.25 -327.82 2,418.63 10.00 155.25 5,952,457.06 539,570.80 4 8,400.00 91.15 162.35 5,951.33 3,036.73 -308.66 2,368.62 10.00 93.00 5,952,405.65 539,590.23 8,470.00 90.76 169.34 5,950.16 2,968.91 -291.55 2,308.51 10.00 93.12 5,952,337.92 539,607.70 6 8,500.00 90.83 172.34 5,949.75 2,939.30 -286.78 2.284.16 10.00 88.50 5,952,308.34 539,612.63 8,595.00 91.06 181.83 5,948.17 2,844.55 -281.95 2,213.65 10.00 88.54 5,952,213.62 539,617.96 6 8,600.00 91.08 182.33 5,948.08 2,839.55 -282.13 2,210.24 10.00 87.80 5,952,208.63 539,617.80 8,700.00 91.45 192.33 5,945.86 2,740.52 -294.87 2,149.09 10.00 87.81 5,952,109.54 539,605.59 8,800.00 91.77 202.33 5,943.05 2,645.22 -324.61 2,102.59 10.00 88.03 5,952,014.09 539,576.36 8,900.00 92.03 212.33 5,939.73 2,556.54 -370.43 2,072.14 10.00 88.31 5,951,925.18 539,531.01 8,975.00 92.19 219.83 5,936.96 2,496.01 -414.54 2,060.41 10.00 88.64 5,951,864.42 539,487.23 7 9,000.00 92.03 217.34 5,936.04 2,476.48 -430.12 2,057.58 10.00 -93.70 5,951,844.81 539,471.75 9,100.00 91.34 207.36 5,933.09 2,392.14 -483.53 2,035.56 10.00 -93.79 5,951,760.20 539,418.79 9,200.00 90.61 197.38 5,931.38 2,299.80 -521.54 1,996.98 10.00 -94.09 5,951,667.67 539,381.28 9,275.00 90.05 189.90 5,930.95 2,226.97 -539.21 1,957.88 10.00 -94.26 5,951,594.75 539,364.00 8 9,300.00 89.83 192.39 5,930.97 2,202.44 -544.05 1,943.92 10.00 95.00 5,951,570.20 539,359.29 9,400.00 88.97 202.36 5,932.02 2,107.13 -573.87 1,897.48 10.00 95.00 5,951,474.74 539,329.98 9,500.00 88.14 212.32 5,934.55 2,018.44 -619.72 1,867.04 10.00 94.89 5,951,385.82 539,284.60 9,600.00 87.36 222.30 5,938.49 1,939.07 -680.21 1,853.53 10.00 94.64 5,951,306.14 539,224.54 9,625.00 87.18 224.80 5.939.68 1,920.97 -697.42 1,852.86 10.00 94.25 5,951,287.95 539,207.43 9 9,700.00 87.85 217.32 5,942.94 1,864.52 -746.60 1,847.59 10.00 -85.00 5,951,231.24 539,158.56 9,800.00 88.81 207.36 5,945.86 1,780.17 -800.00 1,825.56 10.00 -84.68 5,951,146.62 539,105.60 9,900.00 89.80 197.41 5,947.08 1,687.83 -838.04 1,787.02 10.00 -84.38 5,951,054.09 539,068.06 9,975.00 90.55 189.95 5,946.85 1,615.01 -855.77 1,747.96 10.00 -84.26 5,950,981.18 539,050.73 10 10,000.00 90.60 192.45 5,946.60 1,590.49 -860.62 1,734.02 10.00 88.90 5,950,956.64 539,046.00 10,100.00 90.77 202.45 5,945.40 1,495.22 -890.56 1,687.68 10.00 88.92 5,950,861.22 539,016.57 10,200.00 90.93 212.45 5,943.91 1,406.60 -936.59 1,657.42 10.00 89.04 5,950,772.37 538,971.01 10,225.00 90.96 214.95 5,943.50 1,385.81 -950.46 1,652.48 10.00 89.19 5,950,751.50 538,957.25 11 10,300.00 90.95 207.45 5,942.25 1,321.71 -989.28 1,634.49 10.00 -90.00 5,950,687.20 538.918.78 10,400.00 90.92 197.45 5,940.61 1,229.41 -1,027.41 1,596.04 10.00 -90.13 5,950,594.72 538,881.15 10,500.00 90.85 187.44 5,939.06 1,131.90 -1,048.93 1,542.17 10.00 -90.29 5,950,497.10 538,860A5 10,575.00 90.79 179.94 5,937.98 1,057.11 -1,053.76 1,492.61 10.00 -90.44 5,950,422.30 538,855.72 Planned TD at 10575.00 101212014 12:54:49PM Page 3 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 1 L Pad Well: 1 L-04 +� Wellbore: - ^n"4 v...1-'ssr Design: Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Shape (1) (1) (usft) (usft) (usft) Well 1 L-04 Mean Sea Level 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature Northing Easting (usft) (usft) Latitude Longitude 1L-04AL3-01 T04 0.00 0.00 5,947.00 -4,644.491,139,279.30 5,950,769.00 1,679,091.00 700 V 34.161 N 1400 32' 35.955 W plan misses target center by 1139585.86usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Point 1L-04A_Fault2 0.00 0.00 0.00 -297.691,139,410.37 5,955,116.00 1,679,199.00 70' 2' 16.173 N 140' 32' 13.562 W plan misses target center by 1139712.17usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Rectangle (sides W310.00 1-11.00 D0.00) 1L-04AL3-01_T03 0.00 0.00 5,931.00 -4,050.081,139,591.49 5,951,365.00 1,679,400.00 70' 1' 39.474 N 140' 32' 24.536 W plan misses target center by 1139894.29usft at 8595.00usft MD (5948.17 TVD, 2844.55 N. -281.95 E) Point 1L-04 CTD Polygon_Sot 0.00 0.00 0.00 -2,926.751,138,988.38 5,952,485.00 1,678,791.00 70' 1' 51.266 N 140' 32' 36.845 W plan misses target center by 1139300.47usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Polygon Point 1 0.00 0.00 0.00 5,952,485.00 1,678,791.00 Point 0.00 156.14 -23.18 5,952,641.00 1,678,766.99 Point 0.00 280.90 25.48 5,952,766.00 1,678,814.99 Point 0.00 374.25 150.98 5,952,860.01 1,678,939.98 Point 0.00 390.39 315.09 5,952,877.02 1,679,103.98 Point 0.00 309.42 498.68 5,952,797.03 1,679,287.98 Point 0.00 50.86 788.36 5,952,540.04 1,679,579.00 Point 0.00 -140.83 916.36 5,952,349.05 1,679,708.00 Point 0.00 -505.35 1,007.46 5,951,985.05 1,679,801.03 Point 10 0.00 -696.24 982.45 5,951,794.05 1,679,777.03 Point 11 0.00 -900.87 908.37 5,951,589.05 1,679,704.05 Point 12 0.00 -1,295.89 712.27 5,951,193.03 1,679,510.06 Point 13 0.00 -1,618.11 557.56 5,950,870.03 1,679,357.08 Point 14 0.00 -2,168.81 297.64 5,950,318.01 1,679,100.11 Point15 0.00 -2,446.57 247.18 5,950,040.02 1,679,051.13 Point 16 0.00 -2,402.84 -81.63 5,950,082.00 1,678,722.12 Point 17 0.00 -2,118.02 -42.13 5,950,366.99 1,678,760.11 Point 18 0.00 -1,501.26 207.14 5,950,985.01 1,679,006.08 Point 19 0.00 -1,148.30 414.01 5,951,339.02 1,679,211.05 Point20 0.00 -771.19 590.02 5,951,717.03 1,679,385.04 Point21 0.00 -642.50 652.70 5,951,846.03 1,679,447.03 Point22 0.00 -521.62 678.34 5,951,967.04 1,679,472.03 Point23 0.00 -246.25 613.78 5,952,242.03 1,679,406.02 Point24 0.00 -134.91 551.35 5,952,353.03 1,679,343.00 Point25 0.00 88.51 285.50 5,952,575.01 1,679,076.00 Point26 0.00 0.00 0.00 5,952,485.00 1,678,791.00 1L-04AL3-01_T02 0.00 0.00 5,949.00 -3,416.341,139,843.87 5,952,000.00 1,679,649.00 70' V 45.257 N 140' 32' 14.645 W plan misses target center by 1140143.01 usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Point 1 L-04AL3_Faultl 0.00 0.00 0.00 -3,454.221,139,819.67 5,951,962.00 1,679,625.00 70° V 44.924 N 140° 32' 15.496 W plan misses target center by 1140134.54usft at 8595.O0usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Rectangle (sides W330.00 H1.00 D0.00) 1L-04AL3-01_T01 0.00 0.00 5,954.00 -3,194.041,139,792.05 5,952,222.00 1,679,596.00 70° 1' 47.491 N 140° 32' 15.163 W plan misses target center by 1140089.99usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Point 1L-04 CTD Polygon_Noi 0.00 0.00 0.00 -2,926.751,138,988.38 5,952,485.00 1,678,791.00 70' V 51.266 N 140' 32' 36.845 W plan misses target center by 1139300.47usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Polygon Point 1 0.00 0.00 0.00 5,952,485.00 1,678,791.00 Point 0.00 201.25 -43.95 5,952,685.99 1,678,745.99 Point 0.00 398.08 -6.91 5,952,883.00 1,678,781.98 Point 0.00 650.56 98.43 5,953,136.01 1,678,885.97 101212014 12:54:49PM Page 4 COMPASS 5000.1 Build 61 � Rl I N A L ConocoPhilli s was p Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Go -ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1 L Pad North Reference: Well: 1L-04 \ -, Survey Calculation Method: Wellbore: 44__� Design: tt-94kt311 rWi�2 ��- Ci� �` W 0�1, Well 1 L-04 Mean Sea Level 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature Point 0.00 929.59 288.91 5,953,416.02 1,679,074.95 Point 0.00 1,299.60 484.88 5,953,787.03 1,679,268.93 Point 0.00 1,738.35 542.19 5,954,226.03 1,679,323.91 Point 0.00 2,182.67 489.52 5,954,670.02 1,679,268.89 Point 0.00 2,463.33 369.98 5,954,950.02 1,679,147.87 Point 10 0.00 2,671.25 200.05 5,955,157.01 1,678,976.86 Point 11 0.00 2,864.40 -15.96 5,955,348.99 1,678,759.85 Point 12 0.00 3,269.73 -258.85 5,955,752.99 1,678,514.84 Point 13 0.00 4,029.55 -589.90 5,956,510.97 1,678,179.80 Point 14 0.00 4,169.12 -315.14 5,956,651.98 1,678,453.78 Point 15 0.00 3,448.24 28.11 5,955,933.00 1,678,800.82 Point 16 0.00 3,127.22 214.45 5,955,613.01 1,678,988.84 Point 17 0.00 2,870.98 445.13 5,955,358.02 1,679,220.85 Point 18 0.00 2,632.01 625.89 5,955,120.03 1,679,402.86 Point 19 0.00 2,217.85 836.74 5,954,707.04 1,679,615.88 Point20 0.00 1,736.59 877.22 5,954,226.05 1,679,658.91 Point21 0.00 1,182.96 795.30 5,953,672.05 1,679,579.94 Point22 0.00 805.98 592.30 5,953,294.03 1,679,378.96 Point23 0.00 485.10 371.59 5,952,972.02 1.679,159.98 Point24 0.00 189.60 270.03 5,952,676.01 1,679,059.99 Point25 0.00 91.49 288.51 5,952,578.01 1,679,078.99 Point26 0.00 0.00 0.00 5,952,485.00 1,678,791.00 1 L-04AL3-01_T05 0.00 0.00 5,938.00 -5,239.461,139,072.12 5,950,173.00 1,678,887.00 70' 1' 28.688 N 140' 32' 44.392 W plan misses target center by 1139382.75usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Point 1L-04A_Faultl 0.00 0.00 0.00 -2,534.581,139,153.47 5,952,878.00 1,678,954.00 700 1' 54.831 N 140° 32' 30.471 W plan misses target center by 1139463.65usft at 8595.00usft MD (5948.17 TVD, 2844.55 N,-281.95 E) Rectangle (sides W330.00 H1.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,575.00 5,937.98 2-3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,100.00 5,981.54 3,298.77 -447.96 TIP/KOP 8,185.00 5,973.13 3,228.74 -400.66 Start 10 dls 8,255.00 5,961.23 3,169.34 -365.68 3 8,345.00 5,952.57 3,088.25 -327.82 4 8,470.00 5,950.16 2,968.91 -291.55 5 8,595.00 5,948.17 2,844.55 -281.95 6 8,975.00 5,936.96 2,496.01 -414.54 7 9,275.00 5,930.95 2,226.97 -539.21 8 9,625.00 5,939.68 1,920.97 -697.42 9 9,975.00 5,946.85 1,615.01 -855.77 10 10,225.00 5,943.50 1,385.81 -950.46 11 10,575.00 5,937.98 1,057.11 -1,053.76 Planned TD at 10575.00 101212014 12:54 49PM Page 5 COMPASS 5000.1 Build 61 Company: ConocoPhillips (Alaska) Ir Iup2 Project: Kuparuk River Unit Reference Site: Kuparuk 1 L Pad Site Error: 0.00usft Reference Well: 1L-04 Well Error: 0.00usft Reference Wellbore 1L-04AL3-01 Reference Design: 1 L-04AL3-01_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 L 1 L-04 L .00usft (1 L-04) 1 L-04 @ 116.00usft (1 L-04) True Minimum Curvature 1.00 sigma EDM Alaska Prod Offset Datum Reference _wp I L — (� Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,100.00 to 10,575.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,245.90usft Error Surface: Elliptical Conic Survey Tool Program Date 10/212014 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 7,200.00 1 L-04 (1 L-04) GCT-MS Schlumberger GCT muitishot 7,200.00 8,100.00 1 L-04AL3_wpl 0 (1 L-04AL3) MWD MWD- Standard 8.100.00 10,575.00 1L-04AL3-01_wp02(1L-04AL3-01) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,575.00 6,053.98 2-3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk 1 F Pad 1 F-20 - 1 F-20 - 1 F-20 1F-20- 1F-20P81 - 1F-20PB1 Kuparuk I Pad 1 L-03 - 1 L-03 - 1 L-03 1 L-03 - 1 L-03A - 1 L-03A 1 L-04 - 1 L-04 - 1 L-04 1 L-04 - 1 L-04A - 1 L-04A_wP06 i L-04 - 1 L-04ALl - 1 L-04AL1 wp03 1 L-04 - 1 L-04AL2 - 1 L-04AL2 wp04 1 L-04 - 1 L-04AL3 - 1 L-04AL3 wpl 0 Reference Offset Measured Measured Depth Depth (usft) (usft) 9,900.00 10,200.00 8,249.69 8,249.69 8,249.69 8,249.69 8,100.00 6,550.00 6,550.00 6,550.00 6,550.00 8.100.00 Centre to No -Go Allowable Centre Distance Deviation Warning Distance (usft) from Plan (usft) (usft) 953.03 304.62 648.52 Pass - Major Risk Out of range Out of range Out of range 810.70 20.07 797.53 Pass - Major Risk 810.70 20.07 797.53 Pass - Major Risk 810.70 20.07 797.53 Pass - Major Risk 810.70 20.07 797.53 Pass - Major Risk 0.00 0.22 -0.22 FAIL - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 101212014 11:03:35AM Page 2 of 11 COMPASS 5000.1 Build 61 I L-04 Current CTD Schematic 16" 62# H-40 shoe @ 96' MD 10-3/4" by 9-5/8" 36# J-55 shoe @ 2343' MD C-sand perts (sgz'd) 7201' - 7214' MD KOP @ 7220' MD for southern laterals Whipstock at 7230' MD (slipped downhole) KOP @ 7240' MD for northern laterals A -sand perts (sqz'd) 7316' - 7377' MD _ C Fish: CT under -reamer at 6 7260'-7283' MD. 7" 26# J-55 shoe @ 7625' MD t Modified by JGE 2-2-15 3-1/2" DS Landing Nipple @ 502' MD (2.875" ID) 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 1/2" Camco MMG gas lift mandrel @ 2807, 4387, 5574, 6450, ker 3-1/2" Locator @ 6961' MD ker PBR at 6968' MD ker FHL packer @ 6991' MD (2.96" ID) 3-1/2" Camco DS landing nipple @ 7043' MD (2.812" min ID) Baker 3-1/2" Locator @ 7090' MD Baker FHL packer @ 7106' MD 3-1/2" Camco D landing nipple @ 7128' MD (2.80" min ID) 3-1/2" tubing tail @ 7133' MD 1 AL3-01, Planned TD = 10,575' MD 2%" liner with up into 31/T tail at 7128' MD A5 South =----------=----------------=1 -------------- 1L AgMU, Planned TD = 10,550' MD 21/V liner with billet at 8100' MD A4 South Billet at 8020' MD Unable to get kicked off 1L-04APB1, TD = 10,357' MD No liner, billet at 8,650' MD 1 L-04APB2, TD = 8,850' MD No liner IA A&M_ `b9m lz IL T--I-- - 1- - - T- -- __T- o� o a I I I O 1 I FI I - I I a i i I I I i -r � a _--t-_-�-T— I - I I JO`� N jOy � O - O 1� �[Ii/J3Sll 0S l-F)u �N/�-lulriOs d � � c l� � M O V 0 0 m N ca C) a9i c am ¢E -NMVLn cor W rna O u et L1'%T Mr-tnr co to LO co d LO- cO u7 co et W W m- tT y N Q i f V . 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LL L O W L.7 et n T n n N n N n N M V Lt7TNCOrn NLt7 O D W W W W W rn rn T 0 0 :,I N p g O .-N Met Ln con W McD Z CDv'r + i �^ r ! o I , J J N al I o � o N h I \ P. o ` - _T I � V V T-T I I I f L I _ i > V > I I I . c� J i r < I c — a R F� c F _I _ J - h F I o J - o O o_ O m 0 . . . . . . . . . cl IanaI eaS UeaVy (u?/ljSn 08) gldaQ luoilian acuZ I � N O 00 I i 1 t F NJ E I v/ ! I TRANSMITTAL LETTER CHECKLIST WELL NAME: R('k- I k- o�+Aa ' I PTD: Al,` a a ( Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: K �I,yE,,r POOL: ��`�-j- 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. ) /S' DAO , API No. 50- ®A�- allall7-9 -G- 6b . 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 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 4/2014 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2150210 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 1L-04BL1 Program DEV Well bore seg d❑ DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^, Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025659, entire wellbore 3 Unique well name and number Yes KRU 1 L-04BL1 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes CO 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes CO 432C has no interwell spacing restrictions 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 2/3/2015 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Conductor set in KRU 1 L-04 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 1L-04 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 complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 4135 psi(13.1 ppg EMW); will drill w/ 9.6 ppg EMW and maintain overbalance w/ MPD VTL 2/4/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3631 psi; will test BOPs to 4000 psi 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 112S 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 Wells on IL -Pad are H2S-bearing. H2S measues required. Geology 36 Data presented on potential overpressure zones Yes Max expected reservoir pressure is 13.1 ppg EMW; will be drilled using 9.6 ppg mud and Appr Date 37 Seismic analysis of shallow gas zones NA MPD technique. Two wellbore volumes of 13.1 ppg KWF will be available. PKB 2/3/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development well to be drillied. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner /� Date
