The URL can be used to link to this page

Home My WebLink About214-156Guhl, 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. i THE STATE of GOVERNOR SEAN PARNELL D. Venhaus /vTT l� Cl C I D Engineering Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1 G-08AL2-01 ConocoPhillips Alaska, Inc. Permit No: 214-156 Surface Location: 1323' FSL, 590' FWL, Sec. 29, T12N, RIOE, UM Bottomhole Location: 55' FSL, 586' FEL, Sec. 30, T12N, R10E, UM Dear Mr. Venhaus: 333 Wesi Sevenih Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1 A33 Fax: 907276.7E,2 Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 204-101, API No. 50-029- 20849-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. ster Chair DATED this 7 day of October, 2014. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 SEP 3 0 2014 A GG C 9 I3��1 y �w3 1a. Type of Work: 1 b- Proposed Well Class: Development -Oil ❑✓ • Service - Wini ❑ Single Zone ❑✓ Drill ❑ t 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 Lj Single Well Bond No. 59-52-180 . 11. Well Name and Number: KR(k 1 G-08AL2-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10900' TVD: 6692' , 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 1323" FSL, 590' FWL, Sec. 29, T12N, R10E, UM Top of Productive Horizon: 2424' FNL, 1437' FEL, Sec. 30, T12N, R10E, UM Total Depth: 55' FSL, 586' FEL, Sec. 30, T12N, R10E, UM 7. Property Designation (Lease Number): ADL 25640, 8. Land Use Permit: 2571 13. Approximate Spud Date: 10/15/2014 9. Acres in Property: 2459 14. Distance to Nearest Property: 18200 41b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 540361 y- 5981971 Zone- 4 : 10. KB Elevation above MSL: 89 feet GL Elevation above MSL: 63 feet 15. Distance to Nearest Well Open to Same Pool: 1G-15 , 1150' 16. Deviated wells: Kickoff depth: 8100 ft. Maximum Hole Angle: 98' deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3660 psig Surface: 3005 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 3380' 7520' 6574' 10900, 6692' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 7960' Total Depth TVD (ft): 6947' Plugs (measured) none Effective Depth MD (ft): 1 7825' Effective Depth TVD (ft): 6829' Junk (measured) none Casing Length Size Cement Volume MD TVD Conductor/Structural 54' 16" 265 sx AS II 80' 80' Surface 2206' 10.75" 1300 sx AS III, 250 sx AS 1 2232' 2232' Production 4744' 7" 1140 sx Class G, 250 sx ASI 4770' 4538' Liner 3366' 3.5" 398 sx LiteCRETE 7957' 6945' Perforation Depth MD (ft): 7290'-7292', 7306'-7310', 7326'-7328', 7728'-7736' Perforation Depth TVD (ft): 6388'-6390', 6401'-6404', 6416'-6418', 6745'-6752' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Prograrr ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 C 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Ja n Burke @ 265-6097 Email Jason. Burke(c�cop.com Printed Name D. Venhaus Title CTD Engineering Supervisor Signaturey? r Phone:263-4372 Date Commission Use Only Permit to Drill Number: a! 4 ^ 1 S � API Number: 50- 0 Z2 — Q� O C/ , 63 _� Permit Approva Date: m 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: 136P t�'S t 1� 36-0 C /5 . Samples req'd: Yes LYJ No 9 Mud log req'd: Yes❑ No Z /1h � � 10 � H2S measures: Yes No ❑ Directional svy req'd: Yes d No ❑ tc 5 f to 2 $v0 pacing exception req'd: Yes ❑ No I y y q' �'S� LvJ Inclination -only sv req'd: Yes ❑ No [0 Aj 4APPROVED BY THE Approved by: OMMISSIONER I I N Date: Form 10-401 (Rev ed 10/2012) This permit is valid for 24 rrUn 1// /M/2 //ZL t e (20 AAC 25.005(g)) /{E -,ik-1 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 SEP 2 9 2014 611�\ 1a. Type of Work: Drill ❑ Lateral ✓ Redrill ❑ Reentry 1 b. Proposed Well Class: Development - Oil ❑ Service - Wini ❑ 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: ConocoPhillipsAlaska, Inc. 5. Bond: ✓ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1G-08AL2-01 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10900' TVD: 6692' 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 971' FSL, 666' FWL, Sec. 29, T12N, R10E, UM Top of Productive Horizon: 2424' FNL, 1437' FEL, Sec. 30, T12N, R10E, UM Total Depth: 55' FSL, 586' FEL, Sec. 30, T12N, R10E, UM 7. Property Designation (Lease Number): ADL 25640 8. Land Use Permit: 2571 13. Approximate Spud Date: 10/15/2014 9. Acres in Property: 2459 14. Distance to Nearest Property: 18200 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 540361 y- 5981971 Zone- 4 10. KB Elevation above MSL: 89 feet GL Elevation above MSL: 63 feet 15. Distance to Nearest Well Open to Same Pool: 1G-15 , 1150' 16. Deviated wells: Kickoff depth: 8100 ft. Maximum Hole Angle: 98' deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25 035) Downhole: 3660 psig Surface: 3005 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 3380' 7520' 4'` 10900' 6692' slotted liner r' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 7960' Total Depth TVD (ft): 6947' Plugs (measured) none 7ff& Depth MD (ft): 7825' Effective Depth TVD (ft): 6829' Junk (measured) none Casing Length Size ent Volume MD TVD Conductor/Structural 54' 16" 65 sx AS II 80' 80' Surface 2206' 10.75" 1 x AS III, 250 sx AS 1 2232' 2232' Production 4744' 7" sx Class G, 250 sx ASI 4770' 4538' Liner 3366' 3.5" 398 sx LiteCRETE 7957' 6945' Perforation Depth MD (ft): 7290'-7292', 7306'-7310', 7326'-7328', 7728'-7736 Perforation Depth TVD (ft): 6388'-6390', 6401'-6404', 6416'-6418', 6745'-6752' 20. Attachments: Property Plat ❑ BOP Sketcl-Drilling Prograrr ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter SketCl- ❑ Seabed Report ❑ Drilling Fluid Program a 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 @ 26 -60 7 Email Jason. BUrke(L COp.Com Printed Name D. Vephaus / Title CTD Engineering Supervisor Signature �" f '��=7i��__ Phone: 263-4372 Date Commission Use Only Permit to Drill Number: API Number: 50- Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: ❑ Other: Samples req'd: Yes ❑ No ❑ Mud log req'd: Yes[—] No ❑ 112S measures: Yes ❑ No ❑ Directional svy req'd: Yes ❑ No ❑ Spacing exception req'd: Yes ❑ No ❑ Inclination -only svy req'd: Yes ❑ No ❑ ! p ; ,A PR,'VE BY THE Approved by: COr� MI§S10NFyR ti; k C 9Mt'SSION Date: Form 10-401 (Revised 10/2012) This permit is valid for'24 morSth's from the`dMe of approval (20 AAC 25.005(g)) ConocoPs phllli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 24, 2014 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: SE;P 2 9 2014 ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a four lateral well out of the Kuparuk well 1G-08A using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in October 2014. The CTD objective will be to drill four laterals (1G-08AL1, 1G- 08AL1-01, 1 G-08AL2 & 1 G-08AL2-01), targeting the A3 and A4 sand interval. This well will be classified as a development well. Attached to this application are the following documents.- - Permit to Drill Application Form 10-401 for 1G-08AL1, 1G-08AL1-01, 1G-08AL2 & 1G-08AL2-01 — 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 NABpR$Atq 1G-08AL1, AL1-01, AL2 & AL2-01 Application for Permit to Drill Document 2AC 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(o 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.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................6 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 7 16. Attachments.......................................................................................................................................7 Attachment 1: Directional Plans for 1G-08AL1, AL1-01, AL2 & AL2-01......................................................................... 7 Attachment 2: Current Well Schematic for 1 G-08A........................................................................................................ 7 Attachment 3: Proposed Well Schematic for 1 G-08AL1, AL1-01, AL2 & AL2-01........................................................... 7 Page 1 of 7 ORIGINAL 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 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 1G-08AL1, AL1-01, AL2 & AL2-01. All laterals will be classified as "Development - OX 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 1G-08AL1, AL1-01, AL2 & AL2-01. 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 3500 psi. Using the maximum formation pressure in the area of 3660 psi in the 1G-04, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3005 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 1G-08A in August 2014 indicated a reservoir pressure of 2292 psi or 6.7 ppg equivalent mud weight. The maximum down hole pressure in the 1G-08A pattern is at 1G-04 with 3660 psi. It is not expected that reservoir pressure as high as 1G-04 will be encountered while drilling the 1G-08A laterals because of faulting to the southeast. Using the 1G-04 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3005 psi. ✓ Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; no gas injection has been performed on the 1G pad, so no gas should be encountered. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 1G-08A laterals will be low pressure in the parent bore which could create losses. 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 7 ,, I r I p, t A L 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 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 1G-08AL1 7,965' 9,600' 6,760' 6,808' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 1G-08AL1-01 7,535' 9,600' 6,587' 6,768' 2% , 4.7#, L-80, ST-L slotted liner; ran into the 3'/2" liner. 1G-08AL2 8,100, 10,900, 6,703' 6,721' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 1G-08AL2-01 7,520' 10,900, 6,534' 6,693' 23/", 4.7#, L-80, ST-L slotted liner; ran into the 3'/2" liner. Existing Casing/Liner Information Category OD Weight (ppf) Grade Conn. Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.50 H-40 Welded 26' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 26' 2,232' 0' 2,232' 3580 2090 Casing 7" 26 K-55 BTC 26' 4,770' 0' 4,537' 4980 4330 Liner 3'h" 9.3 L-80 SLHT 4,591' 7,957' 4,419' 6,944' 10160 10540 Tubing 3 %" 1 9.3 L-80 EUE 25' 4,642' 0' 1 4,449' 10160 10540 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 Power -Pro mud (9.6 ppg) - Drilling operations: Chloride -based Power -Pro mud (9.6 ppg) This mud weight will hydrostatically overbalance the reservoir pressure. - Completion operations: BHA's will be deployed using standard pressure deployments and 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 (-200 bbl) of at least 13.0 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 7 ORIGINAL 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 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 11.8 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 1 G-08A Window #1 (7,540' MD, 6587' TVD) Usinq MPD Pumps On (1.5 bpm) Pumps Off A -sand Formation Pressure (6.7 ppg) 2295 psi 2295 psi Mud Hydrostatic (9.6 ppg) 3288 psi 3288 psi Annular friction i.e. ECD, 0.065 psi/ft 489 psi 0 psi Mud + ECD Combined 3777 psi 3288 psi (no choke pressure) (overbalanced (overbalanced —1482psi) —993psi) Target BHP at Window 11.8 4042 psi 4042 psi Choke Pressure Required to Maintain 264 psi 754 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Page 4 of 7 ORIGINAL 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 Summary of Operations Background Well 1 G-08A is a Kuparuk A -sand development well equipped with 3'/2" tubing and a 3 %2" liner. Four laterals from well 1 G-08A will be drilled, 2 to the south side of parent well and 2 to the north. These laterals will target the A3 and A4 sands. A mechanical whip -stock will be placed in the 3 %2" liner at the first planned kickoff point of 7540' MD. The 1G-08AL1 lateral will exit through the 3 %2" liner and drill to a TD of 9600', the AL1-01 will be drilled off of this lateral to a depth of 9600'. After liner is run a second window will be milled at 7525' MD. The AL2 lateral will be drilled from this window to a TD of 10900'. The AL2-01 will be drilled off of this lateral to a depth of 10900' MD. The laterals will be completed with 2-%" slotted liner. The final liner of the AL1-01 and the AL2-01 laterals will be rum with the tops located inside the 3'/2" liner. Pre-CTD Work 1. RU slickline — Dummy off GLM 2. RU E-line — Set CBP between the C and A sands, obtain a SBHP of the C sand 3. RU pump — Perform injectivity test on the C sand 4. RU coiled tubing — Cement squeeze the C sand, mill excess cement, mill CBP and mill seal bore nipple in 3 ''/2" liner 5. RU E-line — Dummy drift whip -stock, obtain SBHP of A sand and set whip -stock 6. Prep site for Nabors CDR2-AC, including setting BPV Ria Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test. 2. 1G-08AL1 Lateral (A3 sand - South) i. Mill 2.80" window at 7540' MD ii. Drill 2.74" x 3.25" bi-center lateral to TD of 9600' MD iii. Run 2%" slotted liner with an aluminum billet from TD up to 7965' MD 3. 1G-08AL1-01 Lateral (A4 sand - South) i. Kick off of the aluminum billet at 7965' MD ii. Drill 2.74" x 3.25" bi-center lateral to TD of 9600' MD iii. Run 2%" slotted liner into the liner at 7535' MD 4. 1G-08AL2 Lateral (A3 sand - North) i. Set whip -stock at 7525' MD ii. Mill 2.80" window at 7525' MD iii. Drill 2.74" x 3.25" bi-center lateral to TD of 10900' MD iv. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD Page 5 of 7 ORIGINAL 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 5. 1G-08AL2-01 Lateral (A4 sand - North) ✓ i. Kickoff of the aluminum billet at 8100' MD ii. Drill 2.74" x 3.25" bi-center lateral to TD of 10900' MD iii. Run 2%" slotted liner into the liner at 7520' MD 6. 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, so we will use the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — All the 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 2'/" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 23/" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) Page 6 of 7 ORIGINAL 9/24/2014 PTD Application: 1G-08AL1, AL1-01, AL2 & AL2-01 • 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 1 G-08AL1 17000' 1 G-08AL1-01 17000' 1 G-08AL2 18300' 1 G-08AL2-01 18200' — Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well 1 G-08AL1 1110, 1 G-08 (Abandoned) 1 G-08ALl -01 1110' 1 G-08 (Abandoned) 1 G-08A L2 1100, 1 G-15 1 G-08AL2-01 1150' 1 G-15 16. Attachments Attachment 1: Directional Plans for 1 G-08AL1, AL1-01, AL2 & AL2-01 Attachment 2: Current Well Schematic for 1G-08A Attachment 3: Proposed Well Schematic for 1G-08AL1, AL1-01, AL2 & AL2-01 Page 7 of 7 ORIGINAL 9/24/2014 ti � _^ O to V C � aS E N Q 00 MN N _ - II Q 00 E m N Q Q QQ �� O LO r m N (ham r c0 UO O Om O m v m m cn LO v ova (DVl Q N V m mma) w J 'O m >, (D N `O a O f- N a) -0 U Cn Ol o E _a (D os v p a)O N C 03 cn m O S 3 mCO 0. .9 CM � 'p In NYL corn jN OQ (n U U) v X al 0 C) a o c0 X NLLrn (1) -a 0co U J U 0 U N - - ter" 4-O .C— �? x xm m U m rn U m U m o Lou) F. o a)I Da N N (V N Y N (D (D M2 m �mm(a a) Cl) Cl) m M m J mm Un Q F- U LO 0 Q Y Y Q a _ V 00 N^ N 2 2 rG N ca N� t` V1 V NO.0 O M LO N aN(MM (U) N i Y N "0 U 1� r cmoioio V)UAON 04 CO Cl) U I- n r Q � Q � o O rn O O u 0 � Q Q II (D a co nr o o cL a-- o o CO (L s O co 0 O a O (V + J O I C) Q_c o- C7 o (D F co � N 0 lO a (o O v) -00) a) � 0 O m n _ iL O a) m n.9 II O a � r + J < J co C C 0 — O _ I I (, N y 'll I Y U O n Q L Q 00 3 w S � N V LO N _ � N N O n � V Q A N O n a 006 E� O \� Y co r Conoco`Phillips' Alaska.lrlc. 1G06A 8n 720143:53B a C lama ..._................._.................................................... HANGER; 25.3 CONDUCTOR; 26. �KA.A.A.hN NIPPLE; SURFACE; 26.0.2, GAS LIFT; 2, GAS GAS LIFT; NIPPLE; LOCATOR; SEALASSY; WINDOW; 4.755.0 PRODUCTION F 26.0 IPERF; 7.290D IPERF; 7,306.0 FRAC; IPERF; 7,326.00. KUP PROD 1 G-08A PWell AttributesI Max Angle & MD JTD WNlbare APIIUWI FINtl Name VJeiibore Status ncl (°) MD(RKB) Act 500292084901 KUPARUK RIVER UNIT PR0D 46.90 4,754.99 Btm (ftKB) 7,960.0 comment H2S (ppm) Date SSSV; NIPPLE 35 12/16/2013 Mnohtlon nd ate Last WO: 7!7/2004 KB rtl (Rj Rig Release Date 33.49 1224/1982 Annotation Depth (ftKB) End Date Last Tag: SLM 7,754.0 8/16/2014 Annotation Last Mod By End ate Rev Reason: TAG lehallf 8/1712014 Casing Strings Casing Description CONDUCTOR 5.063 Top (ftKB) Set 26.0 Depth (rtKS) 80.0 Set Depth (TVD)... 80.0 WVLen (L.. 62.50 Grade HA Top Thread WELDED Casing Description SURFACE fOD) ) 9.797 Top (ftKB) Set 26.0 Depth (ftKB) 2,232.0 Set Depth (TVD)... 2,231.9 WULen (I.. 45.50 Grade K-55 op Thread BTC Casing Description PRODUCTION Post S/T ) 6.276 Top (ftKB) Set 26.0 Depth (ftKB) 4,770.0 Set Depm (TVD)... 4,537.5 Vdt L p... 26.00 Grade K-55 Top Thread BTC Casing Description WINDOW (in) 7 6.156 Top (ftKB) Set 4.755.0 Depth (ftKB) 4.767.01 Set Depm (TVD)... 4,535.5 .,an (I... 26.00 Grade L-80 Top Thread SLHT Casing Description LINER A OD (in) 3 12 ID (in) 2.992 Top (ftKB) Set 4,590.9 Depm (ftKB) 7,957.0 SN Depth (TVD)... 6,944.5 Wt1Len (I... 9.30 Grade L-80 Top Threatl SLHT Liner Details Top (ftKB) I Top (TVD) (ftKB) Top Intl (°) Item Des Co. Nominal ID (in) 4,b90.91 4,412.1 43.9E TIEBACK BAKER SEAL BORE TIE BACK EXTENSION 5.250 4,602.E 1 4,420.5 I 44.21 I PACKER BAKER HRD ZXP PACKER 4.340 4,613.5 4,428.3 44.39 HANGER BAKER FLEX -LOCK HANGER" 4.360 4,622.6 4,434.81 44.55 SBE BAKER CASING SEAL BORE EXTENSION 4.030 7,505.8 6,559.2 35.90 NIPPLE I SEAL BORE NIPPLE "' NO LOCKING PROFILE IN 2.750 IT"' 8/7/2006 TUBING 1 31121 2.9921 25.31 4,642.21 4,448.71 9.30IL-80 jEUE8RDMOD Des Perforations & Slots Shot Dens Top (TVD) Btm (ND) (shots/ Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date 11 Depth I Depth I Top(TVDJ I Stm(TVD) I (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 7,728.0 7,736.0 6,745.1 6,751.9 FRAC 8/19/2004 A -SAND FRAC-172,650 # Dn 10 ppa 7,290.0 1,328.0 5,388.1 6,417.9 FRAC 9/22/2004 C-SAND FRAC- 51,000 A 16/20 CERAM IC 1 PROPPANT Mandrel Inserts St atl on No Top (TVD) Valve Latch Port Size TRO Run Top (ftKB) (ftKB) Make Model OD (In) Sery Type Type (In) (psi) Run Date 1 2,651.8 2,651.E CAMCO MMG 1 112 GAS LIFT GLV RK 0.188 1,364.0 528/2014 2 3,838.0 3,810.0 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,337.0 528/2014 3 4,516.9 4,358.1 CAMCO MMG 1 112 GAS LIFT OV RK 0.250 0.0 528/2014 LINER A 4,590.9-7,95TO ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-08 1 G-08AL2-01 Plan: 1 G-08AL2-01 wp03 Standard Planning Report 19 September, 2014 MCA a I BAKER HUGHES ORIGINAL rG.I ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1GPad Well: 1 G-08 Welibore: 1 G-08AL2-01 Design: 1 G-08AL2-01 _wp03 Local Co-ordinate Reference: Well 1 G-08 TVD Reference: Mean Sea Level MD Reference: 1G-08 @ 89.00usft (1G-08) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1G Pad Site Position: Northing: 5,981,540.78 usft Latitude: 70' 21' 37.826 N From: Map Easting: 540,089.12usft Longitude: 149° 40' 27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1 G-08 Well Position +N/-S 0.00 usft Northing: 5,981,970.94 usft Latitude: 700 21' 42.043 N +E/-W 0.00 usft Easting: 540,361.46 usft Longitude: 149' 40' 19.674 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Welibore 1G-08AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BG G M 2014 12/ 1 /2014 19.14 80.95 57,580 Design 1G-08AL2-01_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,099.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) V) 0.00 0.00 0.00 222.73 911912014 12:11:57PM Page 2 COMPASS 5000.1 Build 61 ConocoPhillips Planning Report CART BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-08 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 G-08 @ 89.00usft (1G-08) Site: Kuparuk 1G Pad North Reference: True Well: 1G-08 Survey Calculation Method: Minimum Curvature Welibore: 1 G-08AL2-01 Design: 1G-08AL2-01_wp03 Plan Sections Measured Depth Inclination Azimuth (usft) (°) (°) 8,099.00 96.35 173.44 8,169.00 97.60 168.66 8,239.00 97.57 163.72 8,319.00 92.30 161.81 8,419.00 93.26 154.86 8,509.00 90.19 149.36 8,819.00 88.96 127.69 8,929.00 82.30 123.81 9,049.00 90.01 127.15 9,449.00 90.01 155.15 9,569.00 90.01 146.75 9,869.00 90.01 167.75 10,039.00 95.56 178.29 10,219.00 89.77 167.09 10,499.00 89.45 186.68 10,599.00 89.46 179.68 10,899.00 83.82 159.41 911912014 12.11:57PM TVD Below System +N/-S +El-W (usft) (usft) (usft) 6,612.78 1,185.83 -2,220.93 6,604.28 1,117.22 -2,210.13 6,595.04 1,049.86 -2,193.58 6,588.16 973.77 -2,169.96 6,583.30 881.00 -2,133.12 6,580.59 801.53 -2,091.05 6,582.91 570.66 -1,886.97 6,591.29 506.61 -1,798.04 6,599.33 437.15 -1,700.64 6,599.26 128.71 -1,452.24 6,599.24 23.90 -1,394.03 6,599.19 -251.22 -1,278.68 6,590.91 -419.46 -1,258.06 6,582.50 -597.43 -1,235.19 6,584.41 -875.65 -1,220.05 6,585.37 -975.43 -1,225.60 6,603.14 -1,268.31 -1,171.72 Page 3 Dogleg Build Turn Rate Rate Rate (°/100usft) (°/100usft) (°/100usft) 0.00 0.00 0.00 7.00 1.78 -6.82 7.00 -0.04 -7.06 7.00 -6.58 -2.39 7.00 0.95 -6.94 7.00 -3.41 -6.12 7.00 -0.40 -6.99 7.00 -6.06 -3.52 7.00 6.43 2.78 7.00 0.00 7.00 7.00 0.00 -7.00 7.00 0.00 7.00 7.00 3.27 6.20 7.00 -3.22 -6.23 7.00 -0.12 7.00 7.00 0.00 -7.00 7.00 -1.88 -6.76 TFO Target 0.00 285.00 270.00 200.00 278.00 241.00 266.70 210.00 23.50 90.00 270.00 90.00 62.00 243.00 91.00 270.00 254.00 COMPASS 5000.1 Build 61 I� I ' ConocoPhilli s p Planning Report BpMER HUGHES Database: EDM Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 G Pad Well: 1 G-08 Wellbore: 1 G-08AL2-01 Design: 1G-08AL2-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 G-08 Mean Sea Level 1G-08 @ 89.00usft (1G-08) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) usft (usft) (°/100usft) (°) (usft) (usft) 8,099.00 96.35 173.44 6,612.78 1,185.83 -2,220.93 636.07 0.00 0.00 5,983,144.67 538,134.39 TIP/KOP 8,100.00 96.37 173.37 6,612.67 1,184.85 -2,220.82 636.71 7.00 -75.00 5,983,143.69 538,134.51 8,169.00 97.60 168.66 6,604.28 1,117.22 -2,210.13 679A4 7.00 -75.01 5,983,076.12 538,145.56 Start 7 d is 8,200.00 97.59 166.48 6,600.18 1,087.21 -2,203.52 696.69 7.00 -90.00 5,983,046.16 538,152.33 8,239.00 97.57 163.72 6,595.04 1,049.86 -2,193.58 717.38 7.00 -90.29 5,983,008.86 538,162.47 3 8,300.00 93.55 162.26 6,589.13 991.82 -2,175.82 747.96 7.00 -160.00 5,982,950.92 538,180.54 8,319.00 92.30 161.81 6,588.16 973.77 -2,169.96 757.25 7.00 -160.14 5,982,932.90 538,186.49 4 8,400.00 93.08 156.18 6,584.35 898.26 -2,140.97 793.04 7.00 -82.00 5,982,857.56 538,215.89 8,419.00 93.26 154.86 6,583.30 881.00 -2,133.12 800.39 7.00 -82.26 5,982,840.34 538,223.84 6 8,500.00 90.50 149.91 6,580.64 809.29 -2,095.60 827.60 7.00 -119.00 5,982,768.85 538,261.73 8,509.00 90.19 149.36 6,580.59 801.53 -2,091.05 830.22 7.00 -119.16 5,982,761.11 538,266.32 6 8,600.00 89.83 143.00 6,580.58 725.97 -2,040.43 851.36 7.00 -93.30 5,982,685.83 538,317.35 8,700.00 89.43 136.01 6,581.23 649.97 -1,975.53 863.14 7.00 -93.30 5,982,610.19 538,382.65 8,800.00 89.03 129.02 6,582.58 582.44 -1,901.87 862.76 7.00 -93.26 5,982,543.07 538,456.67 8,819.00 88.96 127.69 6,582.91 570.66 -1,886.97 861.31 7.00 -93.16 5,982,531.36 538,471.63 7 8,900.00 84.05 124.84 6,587.85 522.84 -1,821.81 852.21 7.00 -150.00 5,982,483.91 538,537.03 8,929.00 82.30 123.81 6,591.29 506.61 -1,798.04 848.01 7.00 -149.83 5,982,467.80 538,560.89 8 9,000.00 86.86 125.80 6,598.00 466.27 -1,740.02 838.27 7.00 23.50 5,982,427.78 538,619.12 9,049.00 90.01 127.15 6,599.33 437.15 -1,700.64 832.93 7.00 23.31 5,982,398.88 538,658.65 9 9,100.00 90.01 130.72 6,599.32 405.11 -1,660.98 829.55 7.00 90.00 5,982,367.05 538,698.49 9,200.00 90.01 137.72 6,599.31 335.40 -1,589.36 832.15 7.00 90.00 5,982,297.74 538,770.47 9,300.00 90.01 144.72 6,599.29 257.49 -1,526.77 846.91 7.00 90.00 5,982,220.18 538,833.47 9,400.00 90.01 151.72 6,599.27 172.53 -1,474.14 873.60 7.00 90.00 5,982,135.51 538,886.55 9,449.00 90.01 155.15 6,599.26 128.71 -1,452.24 890.92 7.00 90.00 5,982,091.81 538,908.69 10 9,500.00 90.01 151.58 6,599.25 83.13 -1,429.38 908.89 7.00 -90.00 5,982,046.36 538,931.79 9,569.00 90.01 146.75 6,599.24 23.90 -1,394.03 928.41 7.00 -90.00 5,981,987.32 538,967.46 11 9,600.00 90.01 148.92 6,599.24 -2.34 -1,377.53 936.49 7.00 90.00 5,981,961.17 538,984.10 9,700.00 90.01 155.92 6,599.22 -90.93 -1,331.26 970.16 7.00 90.00 5,981,872.85 539,030.84 9,800.00 90.01 162.92 6,599.20 -184.49 -1,296.14 1,015.05 7.00 90.00 5,981,779.49 539,066.46 9,869.00 90.01 167.75 6,599.19 -251.22 -1,278.68 1,052.22 7.00 90.00 5,981,712.85 539,084.28 12 9,900.00 91.03 169.67 6,598.91 -281.62 -1,272.61 1,070.43 7.00 62.00 5,981,682.49 539,090.51 10,000.00 94.30 175.87 6,594.26 -380.65 -1,260.04 1,134.64 7.00 62.02 5,981,583.54 539,103.61 10,039.00 95.56 178.29 6,590.91 -419.46 -1,258.06 1,161.80 7.00 62.31 5,981,544.75 539,105.80 13 10,100.00 93.61 174.48 6,586.03 -480.13 -1,254.23 1,203.76 7.00 -117.00 5,981,484.11 539,109.96 10,200.00 90.39 168.27 6,582.53 -578.87 -1,239.24 1,266.12 7.00 -117.31 5,981,385.46 539,125.48 10,219.00 89.77 167.09 6,582.50 -597.43 -1,235.19 1,277.01 7.00 -117.52 5,981,366.92 539,129.63 14 10,300.00 89.68 172.76 6,582.89 -677.15 -1,221.02 1,325.94 7.00 91.00 5,981,287.29 539,144.23 10,400.00 89.56 179.75 6,583.56 -776.87 -1,214.49 1,394.76 7.00 90.97 5,981,187.61 539,151.29 91192014 12:11:57PM Page 4 COMPASS 5000.1 Build 61 1"INAL Conocomillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-08 Company: ConocoPhillips (Alaska) Inc -Kupl TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-08 @ 89.00usft (1G-08) Site: Kuparuk 1 G Pad North Reference: True Well: 1 G-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-08AL2-01 Design: 1G-08AL2-01_wp03 Planned Survey Measured TVD Below Depth Inclination Azimuth System +Nl-S +El-W (usft) (1) V) (usft) (usft) (usft) 10,499.00 89.45 186.68 6,584.41 -875.65 -1,220.05 15 10,500.00 89.45 186.61 6,584.42 -876.64 -1,220.16 10,599.00 89.46 179.68 6,585.37 -975.43 -1,225.60 16 10,600.00 89.44 179.62 6,585.38 -976.43 -1,225.59 10,700.00 87.52 172.88 6,588.04 -1,076.12 -1,219.06 10,800.00 85.63 166.13 6,594.03 -1,174.21 -1,200.90 10,899.00 83.82 159.41 6,603.14 -1,268.31 -1,171.72 Planned TD at 10900.00 Vertical Dogleg Toolface Map Map Section Rate Azimuth Northing Easting (usft) (*1100usft) V) (usft) (usft) 1,471.09 7.00 90.93 5,981,088.81 539,146.27 1,471.90 7.00 -90.00 5,981,087.82 539,146.16 1,548.15 7.00 -90.00 5,980,989.01 539,141.26 1,548.88 7.00 -106.00 5,980,988.01 539,141.27 1,617.67 7.00 -106.00 5,980,888.37 539,148.34 1,677.39 7.00 -105.82 5,980,790.39 539,167.03 1,726.71 7.00 -105.42 5,980,696.46 539,196.71 911912014 12:11:57PM Page 5 COMPASS 5000.1 Build 61 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1 G-08 Wellbore: 1 G-08AL2-01 Design: 1 G-08AL2-01 _wp03 Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 G-08 Mean Sea Level 1G-08 @ 89.00usft (1G-08) True Minimum Curvature Target Name hittmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (') V) (usft) (usft) (usft) (usft) (usft) 1G-08AL2-01_T03 0.00 0.00 6,583.00-5,822.661,138,239.41 5,982,283.00 1,678,504.00 plan misses target center by 1139420.23usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08AL2-01_T07 0.00 0.00 6,585.00-7,371.391,138,900.14 5,980,738.00 1,679,173.00 plan misses target center by 1140088.19usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08 CTD Polygon Soi 0.00 0.00 0.00 -4,927.551,138,052.21 5,983,177.00 plan misses target center by 1139248.95usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Polygon Point 1 0.00 0.00 0.00 5,983,177.00 Point 2 0.00 201.49 99.09 5,983,379.00 Point 3 0.00 257.54 -95.64 5,983,434.00 Point 0.00 154.45 -269.21 5,983,329.98 Point 5 0.00 -213.28 -327.18 5,982,961.98 Point 6 0.00 -653.82 -235.52 5,982,521.98 Point 0.00 -1,007.83 133.64 5,982,170.00 Point 8 0.00 -1,224.44 431.51 5,981,955.02 Point 0.00 -1,426.20 569.45 5,981,754.03 Point 10 0.00 -1,760.67 650.68 5,981,420.03 Point 11 0.00 -2,128.89 683.71 5,981,052.03 Point 12 0.00 -2,496.92 681.75 5,980,684.04 Point 13 0.00 -2,773.91 673.27 5,980,407.03 Point 14 0.00 -2,779.82 1,032.28 5,980,403.06 Point 15 0.00 -2,366.99 1,071.49 5,980,816.05 Point 16 0.00 -1,907.69 1,024.93 5,981,275.05 Point 17 0.00 -1,302.71 854.14 5,981,879.04 Point 18 0.00 -989.61 654.79 5,982,191.03 Point 19 0.00 -740.86 332.08 5,982,438.01 Point 20 0.00 -536.55 92.15 5,982,641.01 Point 21 0.00 -242.98 -9.30 5,982,934.00 Point22 0.00 0.00 0.00 5,983,177.00 1, 678, 312.00 1,678, 312.00 1,678,409.99 1,678,214.98 1,678, 041.99 1,677,986.01 1,678,080.03 1,678,451.06 1,678, 750.06 1, 678, 889.07 1, 678, 972.10 1,679, 007.11 1, 679, 007.13 1,679, 000.14 1,679, 359.14 1,679, 396.13 1,679, 347.10 1,679,173.06 1,678, 972.05 1,678,648.04 1,678,407.03 1,678,304.01 1,678,312.00 1G-08AL2-01_T05 0.00 0.00 6,599.00-6,673.061,138,852.90 5,981,436.00 1,679,122.00 plan misses target center by 1140037.43usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08AL2_Faultl 0.00 0.00 0.00-4,829.131,137,977.73 5,983,275.00 1,678,237.00 plan misses target center by 1139174.16usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W420.00 1-10.00 D0.00) 1G-08AL2-01_T08 0.00 0.00 6,603.00-7,661.711,138,953.58 5,980,448.00 1,679,228.00 plan misses target center by 1140143.23usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08AL2_Fault4 0.00 0.00 0.00 -6,666.801,138,805.92 5,981,442.00 1,679,075.00 plan misses target center by 1140009.55usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W325.00 1-11.00 D0.00) 1G-08AL2-01_T06 0.00 0.00 6,583.00 -6,962.261,138,884.34 5,981,147.00 1,679,155.00 plan misses target center by 1140070.28usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08 CTD Polygon Nor 0.00 0.00 0.00 -4,862.71 1,138,084.57 5,983,242.00 1,678,344.00 plan misses target center by 1139281.09usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Polygon Point 1 0.00 0.00 0.00 5,983,242.00 1,678,344.00 Point 0.00 -123.56 -85.67 5,983,117.99 1,678,259.01 Point 0.00 18.18-220.93 5,983,258.99 1,678,123.00 Point 0.00 167.40-258.14 5,983,407.99 1,678,084.99 Point 0.00 393.08-194.92 5,983,633.99 1,678,146.98 Latitude Longitude 700 6' 40.803 N 140' 30' 32.053 W 70' 6' 24.794 N 140' 30' 19.914 W 700 6' 49.769 N 1400 30' 33.519 W 70' 6' 31.644 N 140' 30' 18.239 W I 70' 6' 50.835 N 140' 30' 35.218 W I 700 6' 21.897 N 140° 30' 19.646 W 70' 6' 31.773 N 140' 30' 19.551 W 70' 6' 28.790 N 140' 30' 18.594 W 70° 6' S0.351 N 140' 30' 32.316 W I 911912014 12:11:57PM Page 6 COMPASS 5000.1 Build 61 PIFIGINF\L ConocoPhillips Planning Report Database: EDM Alaska Sandbox Local Co-ordinate Reference Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1G Pad North Reference: Well: 1G-08 Survey Calculation Method: Wel lbore: 1 G-08AL2-01 Design: 1G-08AL2-01_wp03 Well 1 G-08 Mean Sea Level 1G-08 @ 89.00usft (1G-08) True Minimum Curvature Point 0.00 611.61 -101.75 5,983,852.99 1,678,238.97 Point 0.00 803.20 -20.71 5,984,045.00 1,678,318.96 Point 0.00 1,039.52 112.56 5,984,282.01 1,678,450.95 Point 9 0.00 1,195.08 198.40 5,984,438.01 1,678,535.94 Point 10 0.00 1,371.65 281.35 5,984,615.01 1,678,617.93 Point 11 0.00 1,551.22 365.32 5,984,795.01 1,678,700.92 Point 12 0.00 1,748.79 450.39 5,984,993.02 1,678,784.91 Point 13 0.00 1,953.30 546.49 5,985,198.02 1,678,879.90 Point 14 0.00 1,828.79 827.85 5,985,075.05 1,679,161.90 Point 15 0.00 1,622.23 740.74 5,984,868.04 1,679,075.91 Point 16 0.00 1,478.50 685.97 5,984,724.03 1,679,021.92 Point 17 0.00 1,288.90 607.95 5,984,534.03 1,678,944.94 Point 18 0.00 1,089.33 522.87 5,984,334.03 1,678,860.94 Point 19 0.00 892.81 428.81 5,984,137.02 1,678,767.95 Point20 0.00 713.31 330.84 5,983,957.01 1,678,670.96 Point21 0.00 530.79 237.86 5,983,774.01 1,678,578.97 Point22 0.00 293.41 117.58 5,983,536.01 1,678,459.99 Point 23 0.00 150.48 100.81 5,983,393.01 1,678,443.99 Point24 0.00 0.00 0.00 5,983,242.00 1,678,344.00 1G-08AL2-01_T02 0.00 0.00 6,581.00 -5,571.461,138,022.74 5,982,533.00 1,678,286.00 plan misses target center by 1139202.59usft at 10899.O0usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point 1G-08AL2_Fault2 0.00 0.00 0.00-5,142.741,137,898.04 5,982,961.00 plan misses target center by 1139095.48usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W320.00 H1.00 D0.00) 1G-08AL2-01_T04 0.00 0.00 6,599.00-5,952.651,138,420.73 5,982,154.00 -plan misses target center by 1139602.08usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) - Point 1G-08AL2-01_T01 0.00 0.00 6,596.00-5,334.931,137,930.00 5,982,769.00 plan misses target center by 1139108.98usft at 10899.O0usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Point WG.I BAKER HUGHES 70' 6' 43.561 N 140' 30' 37.145 W I 1,678,159.00 70' 6' 47.907 N 140- 30' 38.847 W 1,678,686.00 70' 6' 39.274 N 140' 30' 27.445 W 1,678,192.00 70° 6' 45.994 N 140° 30' 38.767 W 1G-08AL2_Fault5 0.00 0.00 0.00-7,383.371,138,896.07 5,980,726.00 1,679,169.00 70° 6' 24.684 N 140' 30' 20.081 W plan misses target center by 1140103.32usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W380.00 H1.00 D0.00) 1G-08AL1_Faultl 0.00 0.00 0.00-4,789.31 1,138,011.95 5,983,315.00 1,678,271.00 70° 6' 51.171 N 140° 30' 34.069 W plan misses target center by 1139208.25usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W370.00 H1.00 D0.00) 1G-08AL2_Fault3 0.00 0.00 0.00-5,833.701,138,247.35 5,982,272.00 1,678,512.00 70' 6' 40.685 N 140' 30' 31.874 W plan misses target center by 1139447.35usft at 10899.00usft MD (6603.14 TVD,-1268.31 N,-1171.72 E) Rectangle (sides W335.00 H1.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,899.00 6,603.14 2-3/8" 2.375 3.000 911912014 12.11:57PM Page 7 COMPASS 5000.1 Build 61 ConocoPhilli s P Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1 G-08 W el (bore: 1 G-08AL2-01 Design: 1G-08AL2-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/-W (usft) (usft) (usft) (usft) Comment 8,099.00 6,612.78 1,185.83 -2,220.93 TIP/KOP 8,169.00 6,604.28 1,117.22 -2,210.13 Start 7dls 8,239.00 6,595.04 1,049.86 -2,193.58 3 8,319.00 6,588.16 973.77 -2,169.96 4 8,419.00 6,583.30 881.00 -2,133.12 5 8,509.00 6,580.59 801.53 -2,091.05 6 8,819.00 6,582.91 570.66 -1,886.97 7 8,929.00 6,591.29 506.61 -1,798.04 8 9,049.00 6,599.33 437.15 -1,700.64 9 9,449.00 6,599.26 128.71 -1,452.24 10 9,569.00 6,599.24 23.90 -1,394.03 11 9,869.00 6,599.19 -251.22 -1,278.68 12 10,039.00 6,590.91 -419.46 -1,258.06 13 10,219.00 6,582.50 -597.43 -1,235.19 14 10,499.00 6,584.41 -875.65 -1,220.05 15 10,599.00 6,585.37 -975.43 -1,225.60 16 10,899.00 6,603.14 -1,268.31 -1,171.72 Planned TD Well 1 G-08 Mean Sea Level 1 G-08 @ 89.00usft (1 G-08) True Minimum Curvature 911912014 12:11:57PM Page 8 COMPASS 5000.1 Build 61 ORIGINAL �1AW ConocoMillipS Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project; Kuparuk River Unit Reference Site: Kuparuk I Pad Site Error. 0.00usft Reference Well: 1 G-08 Well Error. 0.00usft Reference Welibore 1G-08AL2-01 Reference Design: 1 G-08AL2-01_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 G-08 1 G-08 @ 89.00usft (1 G-08) 1 G-08 @ 89.00usft (1 G-08) True Minimum Curvature 1.00 sigma EDM Alaska Prod Offset Datum Reference 1G-08AL2-01_wp03 Fittertype: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,099.00 to 10,899.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,281.00usft Error Surface: Elliptical Conic Survey Tool Program Date 9/16/2014 From To (usft) (usft) Survey (Welibore) Tool Name Description 100.00 4,700.00 1G-08 (1G-08) FINDER -MS SDC Finder multishot 4,754.00 7,474.08 1G-08A (1G-08A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,474.08 8,099.00 1G-08AL2_wp10 (1G-08AL2) MWD MWD - Standard 8,099.00 10,899.00 1G-08AL2-01_wp03(1G-08AL2-01) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name r1 Cl) 10,899.00 6,692.14 2-3/8" 2-3/8 3 Summary Site Name Offset Well - Wellbore - Design Kuparuk I Pad 1 G-01 - 1 G-01 - 1 G-01 1 G-02 - 1 G-02 - 1 G-02 i G-03 - 1 G-03 - 1 G-03 1 G-04 - 1 G-04 - 1 G-04 1G-04- 1G-04L1 - 1G-04L1_wp02 iG-04-1G-041-1-01-1G-04L1-01 wp01 iG-04 - 1G-04L1-02 - 1G-04L1-02 wp04 1 G-04 - i G-04L1-03 - 1 G-04L1-03_wp02 i G-05 - 1 G-05 - 1 G-05 1 G-06 - 1 G-06 - 1 G-06 i G-07 - 1 G-07 - 1 G-07 1 G-08 -1 G-08 -1 G-08 1 G-08 - i G-08A - 1 G-08A 1 G-08 - 1 G-08AL1 - 1 G-08AL1 wp09 1 G-08 - 1 G-08AL1-01 - 1 G-08AL1-01_wp01 1 G-08 - 1 G-08AL2 - 1 G-08AL2_wp10 1 G-08 - 1 G-08PB1 - 1 G-08PB1 1 G-09 - 1 G-09 - 1 G-09 1G-13-1G-13-1G-13 1 G-14 - 1 G-14 - 1 G-14 1 G-15 - 1 G-15 -1 G-15 1 G-16 - 1 G-16 -1 G-16 1 G-17 -1 G-17 - 1 G-17 Plan: 1 G-18 - Plan 1 G-18 - 1 G-18 (wp02) Plan: 1 G-19 - 1 G-19 - 1 G-19 (wp02) Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 8,131.35 6,850.00 854.33 11.39 8,127.80 6,850.00 853.49 11.28 8,127.80 6,850.00 853.49 11.28 8,100.00 8,100.00 0.00 0.31 9,735.97 7,100.00 362.78 151.18 9,282.89 6,852.90 908.49 135.43 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 845.50 Pass - Major Risk 844.74 Pass - Major Risk 844.74 Pass - Major Risk -0.30 FAIL - Minor 1/10 Out of range Out of range Out of range Out of range 216.67 Pass - Major Risk Out of range Out of range 780.59 Pass - Major Risk Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 911812014 1:52:29PM Page 2 of 12 COMPASS 5000.1 Build 61 IGINAL . V Big o 0 0 o o 0 o 0 0 0 0 O O Q 0 O o 0 0 0 o o o � - o n o •' 0 c o u - z o o �g8 n O � of VFE5 (.Jtigo E E O V c.2 g a O b O � O O M 0 O o O 0 J O r co Fa- pN N <0 U C, O O 0 00 O N c O m F _ (ul/lisn 09Z) (+l4uOw(-)glnoS -- - - 1 N m a � >w U 2 `e m m Fi nQ m- � moo 5 � � E N CC U U C7 Fx q C7 N � a9 A A 9 o.a44� 0 a �y�a°3� In O _ Q a 3¢ O A a 00 p C u O O (ai/ljsn OS) yldoG jeoipoA ants, 0 m 0 o � F I � 0 o r7 Q �o I U o0 CI Q li Foo .� F of Q U i I I a� °'o p a U I I Av - I U p _ I o I Oal � Q N �`"' 0 Q II U O II I I I N _ � wl J O O U N O O O O O p p O O O O O O O 00 N � (fl J O O 0 O_ � C r y Q F• C n M V C C) C D n W O]— — — — — — — d O d O�"MNMNMOQ)O�N W OOr-1� Q] Z (n CG Oi 1�1�C0 W NOpp fV W tO >M1� tAOMtOQMONLt1 Or+n QN -� CO CO I�I� W W pp pp W W OO�NC'Lfi r. O N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V � � co O J O O O O O O 1 OL (i O O O O O O O O " Ci O G C] t O O M G O C f V M O Q N W nO�vm.-Nrnra�cova�u+ N N o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 psi D o � � � r r � r r r� � � � � � � � r �M M W C O N t[ 1 1� C Q D7 � ClJ Q7� 00)OCON O COOS O CO 1, O O M CT C � O + N O� C O M O� W Cl 0 u) 6 t M N N 1� N N O W Il I� Q� N N N N N �-- -� NNNNNNc� JW (U NMNCO I�OM[O r-�A'-ONCO M�OM� zLfl 1�O)M�� OtO 1��M� � L 1.1 O t W � V N N� � Q) I� I� 10 p�OO W W C'� N<Ln ODON � lI) J N W W QCOO T �Q+M tO '7 Tt--O'-1"V' W y1�NO�Mt110�NMNN'-Ott»Mt- C� O O N W M O N � O f O 1 O) O O N� Mi M O O) W W W W O) Q) O> O1 O O) W W W O L � tO CO t0 cO CO f0 tO W t0 W O t0 t0 tD t0 t0 t0 r � z O W CO D7�Cfl CO u7 u7 O)O W W � � Q NCO 1� W W MtO CD e-e-NOt0 10 Y' M CV M � C! O) 1l M r Cn W n Lb I O o 0 V vp O O O O N 0 0 o - p O 0 o o O O o T O m o � O O O O O p R a o O O o 0 c c O N a a �a o � Q � 9 � c o O U F �I 0 + U y CA W O a U � U � I O � o N - � o U - o / _ - O F I -- .- F rN1 ` - - Q O c I 0 v _ � o �y F I a O U - o U p U U 0 O O C O O O O O O C C O J N \)k)k .1 a *0 Q 0 c \ \ � NTT e TRANSMITTAL LETTER CHECKLIST WELLNAME: KR(k PTD: a'N — 15� /Deveiopiiient Service Fxpioratory _JtratigraphlicTest Non Conventional FIELD: &iV POOL: L�C".6 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 s (If last two digits No. o?Dy-JQJ , API No. 50- Ok�_- 0 ?4 -0/- M . v ! 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#:2141560 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 1G-08AL2-01 Program DEV Well bore seg DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025640, entire wellbore 3 Unique well name and number Yes KRU 1G-08AL2-01 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 10/1/2014 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 AS31.05.0300.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in KRU 1 G-08 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 1G-08 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 3660 psi(6600'TVD)10.7 ppg EMW; will drill w/ 9.6 ppg & maintain overbalance w/ MPD VLF 10/3/2014 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3005 psi; will test BOPs to 3500 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_1G-Pad are H2S_ bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 10.36 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 KWF will be available. PKB 10/1/2014 38 Seabed condition survey (if off -shore) NA_ 39 Contact name/phone for weekly progress reports [exploratory only] NA_ - - - Onshore development lateral to be drilled. Geologic Engineering Public Commissioner: Date: Commissio er: Date Commissioner Date brS }o J6rl?- did *- . to 7_1y