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HomeMy WebLinkAbout214-170Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,968' 9,806' Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Pkrs; TRSSSV See Schematic; 357' MD/TVD 9,046' 9,037' 8,116' North Fork Tyonek Gas 20" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 North Fork Unit (NFU) 42-35CO 720 Same 9,026'7" ~2,718psi 9,948' 9,037' Length November 26, 2025 2-7/8" 9,948' Perforation Depth MD (ft): See Attached Schematic 5,750psi 120'120' 2,920' Size 120' 2,920' MD Hilcorp Alaska, LLC Proposed Pools: 6.5# / N-80 TVD Burst 9,504' 7,240psi 2,750' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0391210|ADL0391211 214-170 50-231-20046-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t _ c N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.11.13 17:05:35 - 09'00' Noel Nocas (4361) 325-698 By Grace Christianson at 8:32 am, Nov 14, 2025 10-404 TS 11/18/25 BJM 11/18/25 DSR-11/19/25JLC 11/19/2025 11/20/25 Well Prognosis Well Name:NFU 42-35 API Number:50-231-20046-00-00 Current Status:Producing Gas Well Permit to Drill Number:214-170 Regulatory Contact:Donna Ambruz (907) 777-8305 First Call Engineer:Scott Warner (907) 564-4506 (O)(907) 830-8863 (C) Second Call Engineer:Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Maximum Expected BHP:3517 psi @ 7993’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2718 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient:0.785 psi/ft using 15.1 ppg EMW FIT at the 9-5/8” surf casing shoe Shallowest Allowable Perf TVD:MPSP/(0.785-0.1) = 2718 psi / 0.685 = 3968‘ TVD (Will not perforate above top of pool @ 4776’ TVD) Top of Applicable Gas Pool:5373’ MD/ 4776’ TVD Well Status:Online Gas Producer – 211 mcfd, 0 bwpd, 47 psi FTP Well Summary North Fork 42-35 was drilled and completed in 2015. Multiple zones from the T-2 through T-47 were perforated before running tubing and tested post drilling which IP’d at ~ 350 mscfd. A plug was set in 2015 to isolate the T- 47. Tubing punches and through tubing perforations were added in March of 2020 which increased rate by ~100 mcfd. The purpose of this Sundry is to add additional perforations in the T-1 through T-39. Notes Regarding Wellbore Deviation o Max deviation: 38° @ 3363’ MD Min ID o 2.31”: TRSSSV, chemical injection mandrel & sliding sleeve profiles (See Schematic) Recent Tags o 6/7/25: SL RIH w/2.25” DD bailer to 9022’. RIH with PT gauges for survey. RDMO E-line Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,000 psi high 3. RIH and perforate T-2 – T-39 sands from bottom up: Zone Top MD Btm MD Top TVD Btm TVD Footage T2 5,542' 5,572' 4,914' 4,939' 30' T3 5,658' 5,668' 5,009' 5,018' 10' T3 5,684' 5,709' 5,031' 5,051' 25' T3A 5,780' 5,794' 5,110' 5,121' 14' T4 5,858' 5,868' 5,174' 5,182' 10' T7 6,383'6,397'5,606'5,619'14' T11 6,874' 6,880' 6,020' 6,026' 6' T13 6,950' 6,960' 6,089' 6,097' 10' Well Prognosis T15 7,076'7,086'6,205'6,212'10' T16 7,121'7,131'6,244'6,254'10' T39 8,877'8,883'7,956'7,961'6' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. f. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current schematic 2. Proposed Schematic Updated by JKO 7/10/25 CURRENT SCHEMATIC North Fork Unit NFU 42-35 PTD: 214-170 API: 50-231-20046-00-00 PBTD = 9,858’ / TVD = 8,936’ TD = 9,968’ / TVD = 9,046’ RKB to GL = 21’ JEWELRY DETAIL No. Depth ID OD Item 1 357’2.313”TRSSSV @ 357’ 2 2,521’2.313”Chemical Injection Sub 3 5,489’2.31”Sliding Sleeve 4 5,538’2.875”6.276”Tripoint Hydraulic Set Packer 5 5,588’2.31”Sliding Sleeve – Zone 1 6 5,829’2.875”6.276”Tripoint Hydraulic Set Packer 7 5,877’2.31”Sliding Sleeve – Zone 2 8 7,158’2.875”6.276”Tripoint Hydraulic Set Packer 9 7,206’2.31”Sliding Sleeve – Zone 3 10 8,107’2.875”6.276”Tripoint Hydraulic Set Packer 11 8,155’2.31”Sliding Sleeve – Zone 4 12 8,961’2.875”6.276”Tripoint Hydraulic Set Packer 13 9,004’2.313”2.875”X Nipple 14 9,037’2.205”2.875”XN Nipple w/PXN PLUG (set 2-14-15) 15 9,394’2.875”RA Marker 16 9,806’Fish – spent TCP guns? OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Lead - 241 bbl 12 ppg cement. Tail - 56 bbl 13 ppg cement. 105 bbls cement to surface. 8-3/4”CBL TOC @ 4,520’. 30 bbl 10.5 ppg spacer followed by 254 bbl 13.5 ppg lead cement and 28 bbl 13.5 ppg tail cement. PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T2 5,590 5,606 4,954 4,967 16' 2/1/2015 Zone 1 - OPEN T3 5,737 5,760 5,093 5,089 23' 2/1/2015 Zone 1 - OPEN T5 5,974 6,000 5,269 5,291 26' 2/1/2015 Zone 2 - OPEN T5 6,080 6,090 5,357 5,365 10' 3/31/2020 Zone 2 - OPEN T6 6,190 6,198 5,448 5,454 8' 3/31/2020 Zone 2 - OPEN T6 6,278 6,286 5,520 5,527 8' 3/31/2020 Zone 2 - OPEN T7 6,467 6,488 5,676 5,693 21' 2/1/2015 Zone 2 - OPEN T8 6,576 6,586 5,766 5,774 10' 3/31/2020 Zone 2 - OPEN T-17 7,200 7,220 6,317 6,336 20' 2/1/2015 Zone 3 - OPEN T-25 8,160 8,178 7,240 7,258 18' 2/1/2015 Zone 4 - OPEN T-39 8,898 8,914 7,977 7,993 16' 2/2/2015 Zone 4 - OPEN CIBP 9,037’ 2/14/15 T-47 9,502 9,518 8,581 8,597 16' 2/10/2015 Isolated (TCP) T-47 9,527 9,541 8,606 8,620 14' 2/10/2015 Isolated (TCP) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20”Conductor – Driven to Set Depth 120 L-80 Weld 19” Surf 120’ 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,920’ 7"Intermediate Csg 26 L-80 GeoCon 6.276”Surf 9,948’ 2-7/8”Production Tubing 6.5 L-80 EUE BTC 2.441”Surf 9,504’ 20” Conductor 7” Csg 12-1/4” hole 1 9-5/8” Csg 8-3/4” hole 3 2 4 & 5 6 & 7 8 & 9 10 & 11 12 13 14 15 16 Tubing Punch: 8,910’ – 8,920’ Max Deviation – 38 deg @ 3,427’ MD All sleeves open DOWN. Zones 1-4 OPEN as of 3/10/2020. Updated by SRW 11-10-25 Proposed SCHEMATIC North Fork Unit NFU 42-35 PTD: 214-170 API: 50-231-20046-00-00 PBTD = 9,858’ / TVD = 8,936’ TD = 9,968’ / TVD = 9,046’ RKB to GL = 21’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20”Conductor – Driven to Set Depth 120 L-80 Weld 19” Surf 120’ 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,920’ 7"Intermediate Csg 26 L-80 GeoCon 6.276”Surf 9,948’ 2-7/8”Production Tubing 6.5 L-80 EUE BTC 2.441”Surf 9,504’ 20” Conductor 7” Csg 12-1/4” hole 1 9-5/8” Csg 8-3/4” hole 3 2 4 & 5 6 & 7 8 & 9 10 & 11 12 13 14 15 16 Max Deviation – 38 deg @ 3,427’ MD JEWELRY DETAIL No. Depth ID OD Item 1 357’2.313”TRSSSV @ 357’ 2 2,521’2.313”Chemical Injection Sub 3 5,489’2.31”Sliding Sleeve 4 5,538’2.875”6.276”Tripoint Hydraulic Set Packer 5 5,588’2.31”Sliding Sleeve – Zone 1 6 5,829’2.875”6.276”Tripoint Hydraulic Set Packer 7 5,877’2.31”Sliding Sleeve – Zone 2 8 7,158’2.875”6.276”Tripoint Hydraulic Set Packer 9 7,206’2.31”Sliding Sleeve – Zone 3 10 8,107’2.875”6.276”Tripoint Hydraulic Set Packer 11 8,155’2.31”Sliding Sleeve – Zone 4 Tubing Punches from 8910’ – 8920’ MD (3/9/2020) 12 8,961’2.875”6.276”Tripoint Hydraulic Set Packer 13 9,004’2.313”2.875”X Nipple 14 9,037’2.205”2.875”XN Nipple w/ PXN PLUG (set 2-14-15) 15 9,394’2.875”RA Marker 16 9,806’Fish – spent TCP guns? All sleeves open down. Zones 1-4 are open as of 3/10/2020. OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Lead - 241 bbl 12 ppg cement. Tail - 56 bbl 13 ppg cement. 105 bbls cement to surface. 8-3/4”CBL TOC @ 4,520’. 30 bbl 10.5 ppg spacer followed by 254 bbl 13.5 ppg lead cement and 28 bbl 13.5 ppg tail cement. PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T2 5,542' 5,572' 4,914' 4,939' 30' TBD Proposed T2 5,590 5,606 4,954 4,967 16' 2/1/2015 Zone 1 - OPEN T3 5,658' 5,668' 5,009' 5,018' 10' TBD Proposed T3 5,684' 5,709' 5,031' 5,051' 25' TBD Proposed T3 5,737 5,760 5,093 5,089 23' 2/1/2015 Zone 1 - OPEN T3A 5,780' 5,794' 5,110' 5,121' 14' TBD Proposed T4 5,858' 5,868' 5,174' 5,182' 10' TBD Proposed T5 5,974 6,000 5,269 5,291 26' 2/1/2015 Zone 2 - OPEN T5 6,080 6,090 5,357 5,365 10' 3/31/2020 Zone 2 – OPEN Shot through tbg T6 6,190 6,198 5,448 5,454 8' 3/31/2020 Zone 2 – OPEN Shot through tbg T6 6,278 6,286 5,520 5,527 8' 3/31/2020 Zone 2 – OPEN Shot through tbg T7 6,383' 6,397' 5,606' 5,619' 14' TBD Proposed T7 6,467 6,488 5,676 5,693 21' 2/1/2015 Zone 2 - OPEN T8 6,576 6,586 5,766 5,774 10' 3/31/2020 Zone 2 – OPEN Shot through tbg T11 6,874' 6,880' 6,020' 6,026' 6' TBD Proposed T13 6,950' 6,960' 6,089' 6,097' 10' TBD Proposed T15 7,076' 7,086' 6,205' 6,212' 10' TBD Proposed T16 7,121' 7,131' 6,244' 6,254' 10' TBD Proposed T-17 7,200 7,220 6,317 6,336 20' 2/1/2015 Zone 3 - OPEN T-25 8,160 8,178 7,240 7,258 18' 2/1/2015 Zone 4 - OPEN T39 8,877' 8,883' 7,956' 7,961' 6' TBD Proposed T-39 8,898 8,914 7,977 7,993 16' 2/2/2015 Zone 4 - OPEN CIBP 9,037’2/14/15 T-47 9,502 9,518 8,581 8,597 16'2/10/2015 Isolated (TCP) T-47 9,527 9,541 8,606 8,620 14'2/10/2015 Isolated (TCP) T-47 T39 T17 - T25 T4 – T16 T2 – T3A Updated by SRW 11-10-25 Proposed SCHEMATIC North Fork Unit NFU 42-35 PTD: 214-170 API: 50-231-20046-00-00 PBTD = 9,858’ / TVD = 8,936’ TD = 9,968’ / TVD = 9,046’ RKB to GL = 21’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20”Conductor – Driven to Set Depth 120 L-80 Weld 19” Surf 120’ 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,920’ 7"Intermediate Csg 26 L-80 GeoCon 6.276”Surf 9,948’ 2-7/8”Production Tubing 6.5 L-80 EUE BTC 2.441”Surf 9,504’ 20” Conductor 7” Csg 12-1/4” hole 1 9-5/8” Csg 8-3/4” hole 3 2 4 & 5 6 & 7 8 & 9 10 & 11 12 13 14 15 16 Max Deviation – 38 deg @ 3,427’ MD JEWELRY DETAIL No. Depth ID OD Item 1 357’2.313”TRSSSV @ 357’ 2 2,521’2.313”Chemical Injection Sub 3 5,489’2.31”Sliding Sleeve 4 5,538’2.875”6.276”Tripoint Hydraulic Set Packer 5 5,588’2.31”Sliding Sleeve – Zone 1 6 5,829’2.875”6.276”Tripoint Hydraulic Set Packer 7 5,877’2.31”Sliding Sleeve – Zone 2 8 7,158’2.875”6.276”Tripoint Hydraulic Set Packer 9 7,206’2.31”Sliding Sleeve – Zone 3 10 8,107’2.875”6.276”Tripoint Hydraulic Set Packer 11 8,155’2.31”Sliding Sleeve – Zone 4 Tubing Punches from 8910’ – 8920’ MD (3/9/2020) 12 8,961’2.875”6.276”Tripoint Hydraulic Set Packer 13 9,004’2.313”2.875”X Nipple 14 9,037’2.205”2.875”XN Nipple w/ PXN PLUG (set 2-14-15) 15 9,394’2.875”RA Marker 16 9,806’Fish – spent TCP guns? All sleeves open down. Zones 1-4 are open as of 3/10/2020. OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Lead - 241 bbl 12 ppg cement. Tail - 56 bbl 13 ppg cement. 105 bbls cement to surface. 8-3/4”CBL TOC @ 4,520’. 30 bbl 10.5 ppg spacer followed by 254 bbl 13.5 ppg lead cement and 28 bbl 13.5 ppg tail cement. PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T2 5,542' 5,572' 4,914' 4,939' 30' TBD Proposed T2 5,590 5,606 4,954 4,967 16' 2/1/2015 Zone 1 - OPEN T3 5,658' 5,668' 5,009' 5,018' 10' TBD Proposed T3 5,684' 5,709' 5,031' 5,051' 25' TBD Proposed T3 5,737 5,760 5,093 5,089 23' 2/1/2015 Zone 1 - OPEN T3A 5,780' 5,794' 5,110' 5,121' 14' TBD Proposed T4 5,858' 5,868' 5,174' 5,182' 10' TBD Proposed T5 5,974 6,000 5,269 5,291 26' 2/1/2015 Zone 2 - OPEN T5 6,080 6,090 5,357 5,365 10' 3/31/2020 Zone 2 – OPEN Shot through tbg T6 6,190 6,198 5,448 5,454 8' 3/31/2020 Zone 2 – OPEN Shot through tbg T6 6,278 6,286 5,520 5,527 8' 3/31/2020 Zone 2 – OPEN Shot through tbg T7 6,383' 6,397' 5,606' 5,619' 14' TBD Proposed T7 6,467 6,488 5,676 5,693 21' 2/1/2015 Zone 2 - OPEN T8 6,576 6,586 5,766 5,774 10' 3/31/2020 Zone 2 – OPEN Shot through tbg T11 6,874' 6,880' 6,020' 6,026' 6' TBD Proposed T13 6,950' 6,960' 6,089' 6,097' 10' TBD Proposed T15 7,076' 7,086' 6,205' 6,212' 10' TBD Proposed T16 7,121' 7,131' 6,244' 6,254' 10' TBD Proposed T-17 7,200 7,220 6,317 6,336 20' 2/1/2015 Zone 3 - OPEN T-25 8,160 8,178 7,240 7,258 18' 2/1/2015 Zone 4 - OPEN T39 8,877' 8,883' 7,956' 7,961' 6' TBD Proposed T-39 8,898 8,914 7,977 7,993 16' 2/2/2015 Zone 4 - OPEN CIBP 9,037’2/14/15 T-47 9,502 9,518 8,581 8,597 16'2/10/2015 Isolated (TCP) T-47 9,527 9,541 8,606 8,620 14'2/10/2015 Isolated (TCP) Superseded by updated proposed schematic - TS 11/17/25 1 Starns, Ted C (OGC) From:Starns, Ted C (OGC) Sent:Monday, November 17, 2025 9:53 AM To:'Scott Warner' Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC) Subject:RE: [EXTERNAL] NFU 42-35 (Permit 214--17; Sundry 325--69) - Request Thank you Scott. I will include the updated schematic in the sundry. Ted From: Scott Warner <scott.warner@hilcorp.com> Sent: Monday, November 17, 2025 9:46 AM To: Starns, Ted C (OGC) <ted.starns@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: Re: [EXTERNAL] NFU 42-35 (Permit 214--17; Sundry 325--69) - Request Ted, Attached is the updated proposed schematic with the proposed perfs in the diagram. Let me know if you need anything else. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Starns, Ted C (OGC) <ted.starns@alaska.gov> Sent: Friday, November 14, 2025 3:58:46 PM To: Scott Warner <scott.warner@hilcorp.com> You don't often get email from scott.warner@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL] NFU 42-35 (Permit 214--17; Sundry 325--69) - Request Hi Scott, I’m nearly complete with my review of the NFU 42-35 add perf sundry. Could you please send an updated proposed schematic (p.5) that shows proposed perf’s? We’ve been asking for these to help us maintain clear records. Thanks in advance for your help. Ted Ted Starns Petroleum Geologist AOGCC 907-793-1225 (office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9968 feet None feet true vertical 9046 feet 9806 feet Effective Depth measured 9858 feet see schematic feet true vertical 8936 feet see schematic feet Perforation depth Measured depth 5590 - 9541 feet True Vertical depth 4594 - 8620 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# N80 EUE 9504' MD 8583' TVD Packers and SSSV (type, measured and true vertical depth)SSSV, 357' MD/TVD Pkrs - see schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Stephen Ratcliff Contact Name:Stephen Ratcliff Authorized Title:VP of Drilling Contact Email:sratcliff@glacieroil.com 5/4/2020 Contact Phone:907-433-3808 9948 WINJ WAG 198 Water-Bbl MD 120 2920 TVD Tubing Pressure 0 Oil-Bbl measured true vertical Packer 7" Plugs Junk measured 188 W NORTHERN LIGHTS BLVD, ANCHORAGE, AK, 99503 3. Address: 0 Representative Daily Average Production or Injection Data 1410 North Fork Unit 42-35 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-170 50-231-20046-00-00 4. Well Class Before Work: ADL 391210, ADL 391211 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-026 141 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 20 Authorized Signature with date: Authorized Name: 20 Casing Pressure Liner 5. Permit to Drill Number: 307 North Fork Undefined GasNone measured 9948 Conductor Surface Intermediate Production Casing Structural 20" 9 5/8" Length 120 2920 120 2750 9026 5410 Burst N/A 5750 7240 COOK INLET ENERGY LLC 2. Operator Name Senior Engineer:Senior Res. Engineer: Collapse N/A 3090 Plugg ug Perfora nttttttttttt Oil Stratigrap G er work: Deve tk 4 O 5P y 214-170 5. Permit to e 6. API Numb 50 231 2004 y efore Work: G bS G LL G E g Sta k: PLL Wk a Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Stephen Ratcliff DN: cn=Stephen Ratcliff, o=Glacier Oil & Gas, ou, email=sratcliff@glacieroil.com, c=US Date: 2020.05.05 10:32:07 -08'00' By Samantha Carlisle at 3:32 pm, May 05, 2020 May 4th, 2020 Mr. Jeremy M. Price, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit 42-35 Permit to Drill NO: 214-170 API No: 50-231-20046-00-00 Dear Mr. Price, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for NFU 42-35. The work performed was covered under Approved Sundry 320-026 for adding perforations. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 10-404 Digitally signed by Stephen Ratcliff DN: cn=Stephen Ratcliff, o=Glacier Oil & Gas, ou, email=sratcliff@glacieroil.com, c=US Date: 2020.05.05 10:30:25 -08'00' NFU 42-35 Daily Operations Summary API: 50-231-20046-00-00 PTD#: 214-170 Date Activity 09 March 2020 RU Slickline. RIH w/2.3” GR to 8200’. Fluid level at 6500’. POH w/GR. RIH w/shifting tool to 7206’ and attempt to shift sleeve closed – unsuccessful. RIH w/brush below shifting tool. Clean sliding sleeve at 7206’, unable to shift. Clean sliding sleeves at 5877’ and 5588’. POH. Change shifting tool to positive keys and RIH to 7206’ and attempt to shift sleeve. POH and confirm keys/pin sheared. Sleeve at 7206’ closed. RIH and close sleeve at 5588’ and 5829’. No change in flow rate or pressure. Monitor production rate from Zone 4 tubing punches (8910’ – 8920’) over night. Secure well. 10 March 2020 No change to rate/pressure. RU Slickline. RIH w/shifting tool and open sleeve at 7206’. POH. Monitor rate/pressure – no change. RIH and open sleeve at 5877’. Observe increase in pressure and rate. POH. Monitor flow rate and pressure until stabile. RIH and open sleeve at 5588’. Monitor rate/pressure – no additional change. RIH with J-latch and locate fluid level at 8000’. POH. RD Slickline. Secure well. 31 March 2020 RU Eline. RIH with gun run #1: 10ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6576’-6586’– all shots fired. RIH with gun run #2: 8ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6278’-6286’– all shots fired. RIH with gun run #3: 8ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6190’-6198’ – all shots fired. RIH with gun run #4: 10ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6080’-6090’ – all shots fired. RIH and check fluid level – 8150’. RD Eline. Turn well over to Production. Version: Final 20" 120# L-80 120' MD 19" Welded 120' TVD TRSSSV @ +/-357' MD - 2.313" ID 2 7/8" Chemical Injection Mandrel @ +/- 2521' MD - 2.313" ID 9 5/8" 40# L-80 2,920' MD ID 8.835" BTC 2,750' TVD CBL TOC @ 4520' Zones 1 through 4 Open as of Date 3-10-2020 Sliding Sleeve @ 5489' MD - 2.31" ID Tripoint Hydraulic Set Packer @ 5538' Sliding Sleeve @ 5588' MD - 2.31" ID MD TVD Zone #1 5590-5606 4954-4967 Zone 1 5737-5760 5093-5089 Zone 1 Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 Sliding Sleeve @ 5877' MD - 2.31" ID 6080-6090 5357-5365 Zone 2 New Zone #2 6190-6198 5448-5454 Zone 2 New 6278-6286 5520-5527 Zone 2 New Tripoint Hydraulic Set Packer @ 7158' 6467-6488 5676-5693 Zone 2 Sliding Sleeve @ 7206' MD - 2.31" ID 6576-6586 5766-5774 Zone 2 New Zone #3 7200-7220 6317-6336 Zone 3 8160-8178 7240-7258 Zone 4 Tripoint Hydraulic Set Packer @ 8107' 8898-8914 7977-7993 Zone 4 Sliding Sleeve @ 8155' MD - 2.31" ID 9502-9518 8581-8597 Zone 5 Tubing punch 8910'-8920' MD 9527-9541 8606-8620 Zone 5 Zone #4 Tripoint Hydraulic Set Packer @ 8961' X Nipple @ 9004' MD - 2.313" ID Plug in XN Nipple XN Nipple @ 9037' MD - 2.205" ID RA marker @ 9394' MD Zone #5 Tubing 2 7/8"6.5#L80 EUE 9,504' MD ID - 2.441" BTC 8,583' TVD Est. TOF @ 9,806' MD 7" 26# L-80 9,948' MD ID - 6.276" GeoCon 9,026' TVD TD at 9,968' MD / 9,046' TVD Perforations 8 3/4" Hole PBTD @ 9,858' MD 8,936' TVD NFU 42-35 Actual Schematic April 27, 2020 20" Conductor 12 1/4" Hole All Sleeves Open Down T X PP X X P THE STATE °fALAS-KA GOVERNOR MIKE DUNLEAVY Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 188 W Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: North Fork Field, Undefined Gas Pool, NFU 42-35 Permit to Drill Number: 214-170 Sundry Number: 320-026 Dear Mr. Ratcliff: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogc c.al asko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J e y rice r DATED this %day of January, 2020. 3BDMS 64 JAN 2 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 naC 25 280 JAN 17 2020 OT-OC-CCs OC-CG Zo 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑� • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: I -I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development ❑� - Stratigraphic ❑ Service ❑ 214-170 3. Address: 6. API Number: 188 W NORTHERN LIGHTS BLVD, ANCHORAGE, AK, 99503 50-231-20046-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A North Fork Unit 42-35 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 391210, ADL 391211 1 North Fork Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9968 - 9046 9858 8936 2870 None 9806 Casing Length Size MD TVD Burst Collapse Structural Conductor 120 20" 120 120 N/A N/A Surface 2920 95/8" 2920 2750 5750 3090 Intermediate Production 99487" 9948 9026 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5590'- 9541' 4594' - 8620' 2-7/8" 6.5# N80 EUE 9504' Packers and SSSV Type: TRSSSV Packers and SSSV MD (ft) and TVD (ft): 357' MD/TVD, Hydraulic Set Packers (5) 5538' MD/4911' WD; 5829MD/5156' WD; 7158' MD/6278' WD; 8107' MD/718T WD: 8961' MD/ 8046' WD 12. Attachments: Proposal Summary ❑� Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory p ry ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/1/2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑� WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 120 Authorized Signature: Date: %I 11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3Lo-0z�e Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: JAN 2 4 2020 Post Initial Injection MIT Req'd? Yes ❑ NoRBDMS«- Spacing Exception Required? Yes ❑ No Subsequent Form Required: I d y®Y APPROVED BY /J Approved by: COMMISSIONER THE COMMISSION Dale: 1/l• O /ZZ zj9 F. 0-403 Re ised o17 Approved application is valid for 12 months from the date of appO R I G A /♦� / u ZA> ' \� (,� Ln'D'u'rm and h n Duplicate /S✓ // /111 >— 0110 GLACIER January 171h, 2020 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 42-35 API: 50-231-20046-00-00 Dear Commissioner, Cook Inlet Energy (CIE) hereby submits a Sundry Application for NFU 42-35, PTD: 214-170 to add perforations. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas owned company) 188 W Northern Lights Blvd, Suite 510 Anchorage, AK 99503 1 GLACIER WELL NAME — NFU 42-35 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. Scope of Work: • Rig Up Eline. • Add Perforations. / • Rig down. General Well Information• Reservoir Pressure / TVD: MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 3732 psi @ 9541' MD / 8620' TVD 2870 psi Vetco Gray -5M - Wellhead Assembly Eline WLV Gas Producer February 1, 2020 2 GLACIER 1. Operational Procedure Requirements of 20 AAC 25.005 (c)(13) 1. Rig up Eline. 2. RIH with 2-1/4" gauge ring to 9000' MD. Note fluid level. 3. RIH with 1-3/4", 4 spf, 60 deg phase perforating guns and perforate the following intervals from bottom to top: Rig down Eline. Turn well over to Production. 3 NFU 42-35 — Perf Intervals Top MD Base MD Footage Top TVD Base TVD Notes 6080 6090 10 5357 5365 New Interval 6190 6198 8 5448 5454 New Interval 6278 6286 8 5520 5527 New Interval 6576 6586 10 5766 5774 New Interval Total = 36 ft Rig down Eline. Turn well over to Production. 3 _ Cook Inlet Energy_ 20" Conductor 12 7/4" Hole CBL TOC @ 4520' NFU 42-35 Final Completion Schematic Version: FINAL March 15, 201 20" 120# L-80 120' MD 19" Welded I 120' ND TRSSSV @ +/-357' MD - 2.313" ID 2 7/8" Chemical Injection Mandrel +/-2521'MD-2.313"ID 9 5/8" 40# L-80 2,920' MD ID 8.835" 1 BTC I 2,750' ND All Sleeves Open Down Zones 1 through 4Open as of Date 3-30-2015 Sliding Sleeve @ 5489' MD- 2.31" ID !F, Tripoint Hydraulic Set Packer, 5538' Sliding Sleeve @ 5588' MD - 2.31" ID Zone#1 Tripoint Hydraulic Set Packer@ 5829' Sliding Sleeve @ 5877' MD- 2.31" ID =31t Sliding #2 TrIPOInt Hydraulic Set Packer8] @DSliding Sleeve @7206'MD-2.3 i ZY Zone#3 TO at 9,968' MD 19.046' ND 8 3/4" Hole Tripoint Hydraulic Set Packer @ 8107' Sliding Sleeve @ 8155' MD - 2.31" ID Punch 8910'-8920' MD f =9394 - Hydraulic Set Packer @ 8961' 4' MD - 2.313" ID 37' MD- 2.205" ID 394' MD Tubing 2 7/8., 6.5#L80 EU 9,504' MD ID - 2.441"1 BTC I 8,583' ND Es4 TOF @ 9,806' MD PBTD @ 9,858' MD 8,931-' ND 7" 26# L4S0 9,948' MD ID - 6.276" Ge E 9,026' ND erforations ND 606 760 4954-4967 5093-5089 Zone 1 Zone 1 00 88 5269-5291 5676-5693 P7977-7993 Zone 2 Zone 2 20 6317-6336 Zone 3 78 14 7240-7258 7977-7993 Zone4 Zone418 8581-8597 8606-8620 Zone 541 Zone 5 NFU 42-35 Final Completion Schematic Version: FINAL March 15, 201 20" 120# L-80 120' MD 19" Welded I 120' ND TRSSSV @ +/-357' MD - 2.313" ID 2 7/8" Chemical Injection Mandrel +/-2521'MD-2.313"ID 9 5/8" 40# L-80 2,920' MD ID 8.835" 1 BTC I 2,750' ND All Sleeves Open Down Zones 1 through 4Open as of Date 3-30-2015 Sliding Sleeve @ 5489' MD- 2.31" ID !F, Tripoint Hydraulic Set Packer, 5538' Sliding Sleeve @ 5588' MD - 2.31" ID Zone#1 Tripoint Hydraulic Set Packer@ 5829' Sliding Sleeve @ 5877' MD- 2.31" ID =31t Sliding #2 TrIPOInt Hydraulic Set Packer8] @DSliding Sleeve @7206'MD-2.3 i ZY Zone#3 TO at 9,968' MD 19.046' ND 8 3/4" Hole Tripoint Hydraulic Set Packer @ 8107' Sliding Sleeve @ 8155' MD - 2.31" ID Punch 8910'-8920' MD f =9394 - Hydraulic Set Packer @ 8961' 4' MD - 2.313" ID 37' MD- 2.205" ID 394' MD Tubing 2 7/8., 6.5#L80 EU 9,504' MD ID - 2.441"1 BTC I 8,583' ND Es4 TOF @ 9,806' MD PBTD @ 9,858' MD 8,931-' ND 7" 26# L4S0 9,948' MD ID - 6.276" Ge E 9,026' ND NFU 42-35 Proposed Schematic Version: V1 Cook Inlet Energy_ January 10, 20" Contluctor 12 114" Hole CBL TOC @ 4520' Plug in XN Nipple 8 314" Hole 20" 120# L-80 120' MD 19" 1 Welded 120' TVD 2 7/8" Chemical Injection Mandrel A +/- 2521' MD - 2.313" ID 95/8" 1 40#L.80 I2,920' MD ID 8.835" 8TC 2,750' ND All Sleeves Open Down Zones 1 through 4 Open as of Date 3-30-2015 Sleeve Perforations ID -2.441" MD TVD Zane#1 >� 31CC 5590-5606 4954-4967 Zone 1 ID - 6.276" 1i 5737-5760 5093-5089 Zone 1 4*� 59746000 5269-5291 Zone 2 7S� T3 � 6080-6090 5357-5365 Zone 2 New 6190-6198 5448-5454 Zone 2 New 6278-6286 5520-5527 Zone 2 New 6467-6488 5676-5693 Zone 2 6576-6586 5766-5774 Zone 2 New 7200-7220 5317-6336 Zone 3 8160-8178 7240-7258 Zone 4 8896-8914 7977-7993 Zone 4 9502-9518 8581-8597 Zone 5 9527-9541 8606-8620 Zone 5 Plug in XN Nipple 8 314" Hole 20" 120# L-80 120' MD 19" 1 Welded 120' TVD 2 7/8" Chemical Injection Mandrel A +/- 2521' MD - 2.313" ID 95/8" 1 40#L.80 I2,920' MD ID 8.835" 8TC 2,750' ND All Sleeves Open Down Zones 1 through 4 Open as of Date 3-30-2015 Sleeve F�p TD at 9,968' MD 19,046' TVD ' Tubing 2 7/r Tripoint Hydraulic Set Packer @ 5538' ID -2.441" Sliding Sleeve @ 5588' MD - 2.31" ID a a Zane#1 >� 31CC 7" 26# L-80 Tripoint Hydraulic Set Packer @ 5829' ID - 6.276" 1i Sliding Sleeve @ 5877' MD -2.31" ID i r Zone #2 4*� Tripoint Hydraulic Set Packer @ 7158' I Sliding Sleeve @ 7206' MD - 2.31" ID 7S� T3 � Zone#3 F�p TD at 9,968' MD 19,046' TVD ' Tubing 2 7/r Tnpoint Hydraulic Set Packer @ 8107' ID -2.441" Sliding Sleeve @ 8155' MD - 2.31" ID m � PBTD @ 9,858' MD 8,936' ND 7" 26# L-80 Tubing punch 8910'-8920' MD ID - 6.276" 1i Zone #4 i r - t---� Tripoint Hydraulic Set Packer @ 6961' I XNipple @ 9004'MD-2.313"ID XN Nipple @ 9037' MD -2.205" ID RA marker @ 9394' MD Zone #5 F�p TD at 9,968' MD 19,046' TVD ' Tubing 2 7/r 6.5#0 EU 9,504' MD ID -2.441" BTC 8,511 Est. TOF @ 9,806' MD PBTD @ 9,858' MD 8,936' ND 7" 26# L-80 9,948' MD ID - 6.276" 1i GeoCon 9,026' TVD 0 0 RECEIVED STATE OF ALASKA JUN 01 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon U Plug Perforations❑ Fracture Stimulate u Repair Well uOp. -tions shutdownu Suspend Perforate Other Stimulate Pull TubingChar.eA roved Prora Plug for Redrill ❑ Perforate New Pool B Re-enter Susp Well Alter Casing e !cher: Install Capillary Stri • 2.Operator Name: 4.Current Well Class: 5.Permit to Dri umber: Cook Inlet Energy,LLC Exploratory Development 0• 214-170 ' 3.Address: Stratigraphic Service ■ `. ''I N ber: 601 W.5th Avenue,Suite 310,Anchorage,AK,995010 '1-20046-00-00 • 7.If perforating: 8. - ,'-and Number: What Regulation or Conservation Order governs well spacing in this pool? * North Fork Unit 42-35 • Will planned perforations require a spacing exception? Yes u No El 9.Property Designation(Lease Number): 10.Field/Pool(s): -c. 4. �� ADL391210ADL391211 Fork J. ed Gas '4, s.11 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP .s Plugs(MD): Junk(MD): 9968 9046 Casing Length Size MD ` TV; Burst Collapse Structural \I Conductor 120 20" ' Surface 2920 9 5/8" 2' • ' \\ 275 r 5750 3090 Intermediate Production 9948 7" 99 : V9026 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubin. - . Tubing rade: Tubing MD(ft): 5590-9541 4594-8620 2 7:Lr 6.5#L80 EUE 9504 Packers and SSSV Type: — \ Packer nd SSSV MD(ft)and TVD(ft): 5 Tripoint Packers+TRSSSV 5 Packers 5538'MD,5829'MD,7155'MD,8107'MD,8961'MD 12.Attachments: Proposal Summary 101 Wellbore s e atic I01 13.Well Class after proposed work: Detailed Operations Program I I BOP Sketch I Exploratory I I Stratigraphic I I Development XI . Service I I 14.Estimated Date for 1-Jun-17 " 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ WDSPL Suspended 1116.Verbal Approval: Date: GAS ® . WAG B GSTOR SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. I hereby certify that the foregoing is true a d the procedure approved herein will not be deviated from without prior written approval. Authorized Name: favid Kumar David Kumar Contact Name: Authorized Title: 'production I,tanager Contact Email: dkumar(G�glacieroil.com �` Contact Phone: 907 433 3822 Authorized Signature: 0, 1 ^ Date: Il 'X COMMISSION USE ONLY Conditions of approval: Notify C mm.sion so that a re resent tive may witness Sundry Number: 3 - 2_11 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 17, Post Initial Injection MIT Req'd? Yes El No El c__ JUN3 2U Spacing Exception Required? Yes ElNo Subsequent Form Required: /o —416 I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ye 4. -6--t7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate oRIGIN AL RBDMS �� 1±� _ 71017 -l' • • RECEIVED Cook Inlet Energy_ JUN 01 2017 AOGCC May 31, 2017 Mr. Guy Schwarz, Alaska Oil and Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage,Alaska 99501 Subject: Sundry Application for Capillary String Installation Cook Inlet Energy, LLC: North Fork Unit 42-35 API: 50-231-20046-00-00 Permit to Drill: 214-170 Dear Mr. Schwartz, Cook Inlet Energy (CIE) proposes to install a 3/8" capillary string in the production tubing of North Fork Unit 42-35 well. A foamer will be periodically pumped through the string to assist in unloading produced water from this well, which currently hampers productivity of this well. We anticipate performing this work in the second week of June 2017. The capillary string will be run inside the production tubing and will extend from 9,000' MD through the wellhead and out of the swab valve at the top of the tree where it will be packed off. Should an emergency arise that requires the well to be shut in, one of the master valves would be closed, severing the capillary string. In accordance with 20 AAC 25.265 (d) (4), CIE requests that the subsurface safety valve be locked out and remain inactive due to the capillary string. c` a `— 7Sidj7 i( €-*'✓< • If you have any questions., please contact me at (907) 433-3822. c - s« ) Sincerely, 0-1 (6.\ Davi I mar Pro• ction Manager Coo Inlet Energy Attachments: Sundry Application •NFU 42-35 Final Completion Schematic • Version: FINAL Cook Inlet Energy_ March 15,2017 20"Conductor i "7- x 20" 120#L-80 120'MD 1., �' 19" Welded 120'TVD •1 +r• -__. ,....--- TRSSSV @+/-357'MD-2.313"ID #., - 2 7/8"Chemical Injection Mandrel @+/-2521'MD-2.313"ID 12 1/4"Hole 9 5/8" 40#L-80 2,920'MD A ID 8.835" BTC 2,750'ND CBL TOC©4520' All Sleeves Open Down Zones 1 through 4 Open as of Date 3-30-2015 Sliding Sleeve©5489'MD-2.31"ID Perforations ( Tripoint Hydraulic Set Packer @ 5538' Sliding Sleeve©5588'MD-2 31"ID MD NDZone#1 5590-5606 4954-4967 Zone 1 I -I , 5737-5760 5093-5089 Zone 1 ( Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 sat iF:C Zone#2 C:G 7200-7220 6317-6336 Zone 3 8160-8178 7240-7258 Zone 4 t Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 3 Sliding Sleeve @ 7206'MD-2.31"ID 9502-9518 8581-8597 Zone 5 Zone#3 9527-9541 8606-8620 Zone 5 Tripoint Hydraulic Set Packer @ 8107' , Sliding Sleeve @ 8155'MD-2.31"ID I'' Tubing punch 8910'-8920'MD Future Perfs Thru Tbg . Zone#4 MD ND 9296-9300 8375-8379 ... rmmi Tripoint Hydraulic Set Packer @ 8961' 9808-9816 8886-8894 I IX Nipple @ 9004'MD-2.313"ID 9894-9896 8972-8974 A, ,� �: XN Nipple @ 9037'MD-2.205"ID Plug in XN Nipple ( _ ,._.._,_.,,„ RA marker @ 9394'MD .= Zone#5 =. ril 9r =i _ 'Tubing 2 7/8" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'ND Est TOF @ 9,806'MD PBTD @ 9,858'MD 8,936'ND TD at 9,968'MD/9,046'ND 7" 26# L-80 9,948'MD 8 3/4"Hole ID-6.276" GeoCon 9,026'ND • • NFU 42-35 Proposed Schematic Cook Inlet Energy_ [P 20"Conductor .i,".. " 20" 120#L-80 120'MD »* k;^ 19" Welded 120'TVD TRSSSV @+/-357'MD-2.313"ID ,+tit p t.. . .' 4^ _ 2 7/8"Chemical Injection .^a� 0 $„ Mandrel @+/-2521'MD-2.313"ID 12 1/4"Hole - 9 5/8" 40#L-80 2,920'MD ID 8.835" BTC 2,750'TVD CBL TOC @ 4520' !, r, C All Sleeves Open Down :.' Zones 1 through 4 Open 1,4 as of Date 3-30-2015 " Sliding Sleeve @ 5489'MD-2.31"ID ` Perforations ? • _ Tripoint Hydraulic Set Packer @ 5538' Sliding Sleeve @ 5588'MD-2.31"ID MD TVD Zone#1 5590-5606 4954-4967 Zone 1 i 5737-5760 5093-5089 Zone 1 ' - Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 ._. 4 Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 Zone#2 7200-7220 6317-6336 Zone 3 t 8160-8178 7240-7258 Zone 444 � Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 r11! Sliding Sleeve @ 7206'MD-2 31"ID 9502-9518 8581-8597 Zone 5 Zone#3 9527-9541 8606-8620 Zone 5 - Tripoint Hydraulic Set Packer @ 8107' : Sliding Sleeve @ 8155'MD-2.31"ID Tubing punch 8910'-8920'MD Future Perfs Thru Tbg Zone#4 , MD TVD 4. HIM. (3/8"_Capillary Tube to 9,000'MD 9296-9300 8375-8379 *W Tripoint Hydraulic Set Packe i./.961' 9808-9816 8886-8894 fr i. ;I. X Nipple @ 9004'MD-2.313"ID 9894-9896 8972-8974 XN Nipple @ 9037'MD-2.205"ID Plug in XN Nipple 1+, rc. RA marker @ 9394'MD g I Zone#5 -- _ Tubing 2 7/8" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'TVD Est.TOF @ 9,806'MD PBTD @ 9,858'MD 8,936'TVD TD at 9,968'MD/9,046'ND 7" 26# L-80 9,948'MD 8 3/4"Hole ID-6.276" GeoCon 9,026'ND • • NFU 42 35 Capillary String Installation Procedure Wireline Work 1. Rig up wireline 2. Run into production tubing with gauge ring and verify tubing is open and confirm ID of tubing station /of (1' , cr .,c, � <.- Capillary String Work 5 s5 Le 1. Perform onsite Safety/Job site review meeting and review/update HRA �} 2. Capillary crew to set up ground protection for truck location .l 3. Rig up truck to wellhead 4. Safety check of crane,hydraulics and truck operational systems 5. Safety check of fall protection equipment 6. Test cycle/inspect man-lift 7. Test cycle/inspect crane 8. Obtain flowing well pressure and bottom hole pressure 9. Test and set fluid control valve (FCV) to pressure and well depth set pressure 10. Install capillary string into injector head and well head pack-off 11.Install FCV to capillary tubing - pull test to 500 pounds to verify ferrule is secure 12.Verify that swab valve is closed and that there is zero pressure between night cap and swab valve, remove Otis 6.5" night cap from wellhead 13.Using crane to install 6.5" Otis x 2 7/8" (wellhead adapter) eight round EUE well head adapter (wellhead adapter) on wellhead 14.Using the capillary crane with a shiv assembly and crane install the injector head and pack-off assembly on the wellhead adapter while passing through , the well house roof 15.Wrap pack-off assembly with absorbent pads (for drip protection) 16. Pressure hydraulic rams on top of WPA to 3,000 psi 17. Pressure test well wellhead assembly to 2,500 psi -hold for three minutes 18.Once pressure test is achieved, open swab valve to enter the well head and tubing 19.Zero truck depth counter 20.Using capillary truck and capillary injector on wellhead run capillary tubing co I • • a downhole fluid control valve to the desired bottom hole depth of 9,000' D 21.Once .pi ary tubing bottom hole fluid control valve is set at desired depth, set slips in wellhead pack-off- set rattigans to engage secondary slips 22. Pressure hydraulic rams on top of WPA to 3,000 psi, close needle valve and insert bull plug 23. Remove capillary injector from wellhead 24. Remove capillary tubing from injector head 25. Remove capillary tubing and spool from capillary truck setting in semi- permanent location for foamer injection 26. Load string with foamer using capillary triplex pump 27. Install injection/filter/check valve manifold to capillary string 28. Connect the Continuous Injection Chemical Module (CICM) to the chemical injection manifold 1 • • 29. Place foamer injection on line and set calculated quarts per day rate using the CICM rate gauge 30. Rig down the capillary truck and containment equipment, move away from wellhead 31. CIE roustabouts replace well-house roof trap door 32.Attach capillary notification signs ("Do not close valves" unless emergency) to all impacted valves 33. Inspect well site and return operations to CIE personnel 2 Schwartz, Guy L (DOA) From: David Kumar <dkumar@glacieroil.com> Sent: Tuesday, June 06, 2017 3:11 PM To: Schwartz, Guy L(DOA) Subject: Re: NFU 42-35 Cap string install. (PTD 214-170) Attachments: NFU 24-26 Tree 1001107-1CD[1].pdf *2.-1 Guy, f'i�� ! t ( t' 7 Appreciate the call.We would like to rescind the sundry on 42-35 as discussed.However we would like to proceed with 24-26.Apologies for the confusion. . C. 1/ On 24-26 attached is the wellhead diagram.The SSV is above the master and will be affected.We would like to move it to the horizontal run of the tree to keep it operational.As per my understanding according to 20AAC 25.265 (c)(1),we would require an waiver from this requirement would require a which I haven't included in the sundry.How do you want me to proceed on the request Thanks and Regards David Kumar Production Manager 1 Glacier Oil and Gas Corporation Email: dkumar@glacieroil.com From: "Schwartz, Guy L(DOA)"<guy.schwartz@alaska.gov> Date:Tuesday,June 6, 2017 at 1:14 PM To: David Kumar<dkumar@glacieroil.com> Subject: NFU 42-35 Cap string install. (PTD 214-170) David, Just to be clear the SSV is in the wing side of production tree on this well and will still be operational? Only SSSV will be locked out. There wasn't wellhead diagram with the sundry. If you could please email me one also. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 - • • Schwartz, Guy L (DOA) From: Regg,James B (DOA) Sent Tuesday,June 06, 2017 3:49 PM To: Schwartz, Guy L(DOA) Subject: NFU 24-26(PTD 2141660) I met with David Kumar and Don Jones(CIE/Glacier)on 5/18/17 to discuss failed SSSV(NFU 24-26, not 42-35). - Failed SVS test 4/13/17 (leak);granted them an extension to install insert SSSV;could not pressure against the valves(control line seals?) - Well was SI 5/4/17 - Options suggested by CIE for discussion: o Install K-valve;5-8 wks before could install; design concerns and venting gas during testing—I did not encourage the K-valve for performance reasons but reminded it requires pre-approval o Grant extension to continue flowing well until can get rig(they said 6 months)—gave a definitive NO WAY o Install capillary string; apparently this well has been on a CIE list for installing cap string to improve lifting water;said they are leaning toward this option; reminded them that AOGCC addressed cap string in regulations(SSSV not required for cap string wells; needs sundry for approval;don't recall if I mentioned anything about required passing LPS/SSV to flow well—regardless the regulations are clear. No mention during the meeting about the tree configuration. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 .t.,OF ? • • 4, 1//7,\�� �4. THE STATE Alaska Oil and Gas-s� �, of Conservation Commission ; 7IN ALAS <.At S t333 West Seventh Avenue 'lt GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .. 1... Main: 907.279.1433 FA' :8* Fax: 907.276.7542 www.aogcc.alaska.gov May 25, 2017 Mr. David Kumar Production Manager Cook Inlet Energy 601 West 5th Avenue, Suite 310 � �� Anchorage, AK 99501 �����0 Re: Docket Number: OTH-17-009 Closeout-Notice of Violation Sustained Casing Pressure Monitoring North Fork Unit 42-35 (PTD 2141700) The Alaska Oil and Gas Conservation Commission(AOGCC)issued a notice of violation to Cook Inlet Energy dated March 7, 2017 for the inability to document wellhead pressures in North Fork Unit 42-35. Cook Inlet Energy responded on March 14, 2017 acknowledging that it has not been monitoring the casing-casing annulus pressure, and that the wellhead pressure gauges for monitoring both the tubing-casing and casing-casing annuli on North Fork Unit 42-35 were inaccessible at the time of AOGCC's inspection. Corrective actions taken in response to the notice of violation were summarized in Cook Inlet Energy's letter. In addition to notifying its lead operators about monitoring all casing annuli,Cook Inlet Energy will install a well house on North Fork Unit 42-35 to prevent snow and ice accumulation surrounding the well. The AOGCC does not intend to pursue any further enforcement action regarding the violation of sustained casing pressure monitoring requirements on North Fork Unit 42-35. Sincerely, Pae..,44,-,---- Cathy . Foerster Chair, Commissioner • • RECEIVED MAR 162017 GLACIER AOGCC March 14, 2017 Mr. Jim Regg, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Ste. 100 Anchorage, Alaska 99501 Subject: Docket Number: OTH-17-009 Notice of Violation Sustained Casing Pressure Monitoring North Fork Unit 42-35 (PTD 2141700) Dear Mr. Regg, Glacier Oil and Gas Corporation as Owner/Operator of Cook Inlet Energy, LLC acknowledges Docket Number: OTH-17-009 sent by the Alaska Oil and Gas Conservation Commission (AOGCC) dated March 09, 2017 related to casing pressure monitoring on well North Fork Unit 42-35 Cook Inlet Energy, as the Commission is aware, has maintained a successful Safety Valve program on all North Fork Wells since transfer of ownership from Armstrong Energy in Feb 2014. Unfortunately, during the transfer of ownership Conservation Order 649 related to `Regulating Sustained Casing Pressure in Development Wells within the North Fork Unit' dated June 21, 2011 was not realized and therefore not fully captured on the Daily Production Reports. Although the pressure gauges on the inner and outer annulus are available for monitoring on all wells, on the day of the Safety Valve Testing, recent heavy snowfall and abnormal freezing conditions caused the gauges on well North Fork Unit 42-35 to remain inaccessible. The tubing and inner annulus pressures are being recorded on a daily basis for all North Fork wells. The outer casing pressures were not (Attachment 1). S GLACIER Cook Inlet Energy is taking the following corrective actions comply with the regulations outlined in the docket: 1. A memorandum was sent out to the lead operators (on the same day the Docket was received) to start recording outer annulus pressures on Daily reports (Attachment 2). Please note that NFU 14-25 and 32-35 have the outer annulus cemented to surface. A copy of the Daily Production Report incorporating this change is submitted (Attachment 3) 2. A well-house will be placed on Well North Fork Unit 42-35 (all other wells on the pad have well houses with the exception of North Fork Unit 23-25 which has been shut-in since 1/19/2014) during the summer construction season to prevent snow accumulation surrounding the well in the future Cook Inlet Energy is committed to following all regulations and making quick corrections when we fall short. Maintaining a close working relationship with AOGCC is important to us in order to maintain high standards of compliance. If any questions arise in this matter please contact me at(907) 433-3822 Sincerely, 3 : It' \11 ' D.vid Kumar Production Manger Glacier Oil and Gas Corporation Attachments Attachment 1: Tubing and inner annulus pressures for North Fork wells Attachment 2: Memorandum to leads on Pressure Reporting Requirements Attachment 3: Copies of North Fork Daily Production Reports reflecting change • Attachment 2 GLACIER March 09,2017 Production Leads Alaska Operations Glacier Oil and Gas Corporation Subject: Pressure Reporting Requirements Dear Leads, Effective immediately,all pressure reporting related to individual wells,should include tubing,tubing-casing and casing-casing pressures. These pressures should be reported via the Morning Reports on a Daily basis. Thank you for your cooperation D id Kumar P oduction Manger Glacier Oil and Gas Corporation Signatures Redoubt Unit West McArthur River Unit North Fork Unit • 0 G LACIER March 09,2017 Production Leads Alaska Operations Glacier Oil and Gas Corporation Subject: Pressure Reporting Requirements Dear Leads, Effective immediately,all pressure reporting related to individual wells,should include tubing,tubing-casing and casing-casing pressures.These pressures should be reported via the Morning Reports on a Daily basis. Thank you for your cooperation , 1k- d Kumar P oduction Manger Glacier Oil and Gas Corporation Si etudes Redoubt n \j _ Cl‘ n r ` `3 1 West McArthur River Unit North Fork Unit • • GLACIER March 09,2017 Production Leads Alaska Operations Glacier Oil and Gas Corporation Subject: Pressure Reporting Requirements Dear Leads, Effective immediately,all pressure reporting related to individual wells,should include tubing, tubing-casing and casing-casing pressures. These pressures should be reported via the Morning Reports on a Daily basis. Thank you for your cooperation • \ � '31 D'vid Kumar Production Manger Glacier Oil and Gas Corporation Signatures Redoubt Unit West McArthur River Unit e' Wttt 417/411"'t /o all oat rc4ivfei ted Oae ?Oa, rirm we,i( ��eSjo.ict i t eva 17 5/i5/17 North Fork Unit • GLACIER March 09,2017 Production Leads Alaska Operations Glacier Oil and Gas Corporation Subject: Pressure Reporting Requirements Dear Leads, Effective immediately,all pressure reporting related to individual wells,should include tubing,tubing-casing and casing-casing pressures.These pressures should be reported via the Morning Reports on a Daily basis. Thank you for your cooperation l_ ey,---„ ... j. ,1,4 - David Kumar Production Manger Glacier Oil and Gas Corporation Signatures Redoubt Unit West McArthur River Unit North Fork Unit l '‘75 171A/75 3/?/ I -i • • .1ImF.- c N I ? o - o � c a , W c m 4LL.P- g. , U - ° 2 E a o5 ' Iy Ni Z.'" 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O is C R I _2 o� aLL A�B-J� 3 ' a C d i ' ? 1 w gg x33lEg ill 1 3I 3 �. g I o ti� .- u m —I I CO o / n u�'.V a a� g a 6 _ LI: .1 A 3 C ` p R g � ~ t ry - C 3 _ 8 0 2s . . 10,-9L-. >3 3� a i a g � = 21 . s W c o o f- g e E c o C a Vw aaaLL oT-. . ; u a a r a >c 3 of o 0 v 5 0 g 1204 Iu s u w 3 f - Y" ' of 33.3,03" 3 LL 3 3 = F" >" j : 4 4 • • VOFTIt \� I//7:s THE STATE Alaska Oil and Gas °fALA KA Conservation Commission ==- 333 West Seventh Avenue 4111* C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.1433 SFA :5� Fax: 907.276.7542 www.aogcc.alaska.gov March 7, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7241 Leland Tate Chief Operating Officer Cook Inlet Energy 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: Docket Number: OTH-17-009 Notice of Violation Sustained Casing Pressure Monitoring North Fork Unit 42-35 (PTD 2141700) Dear Mr. Tate: On March 1, 2017, the Alaska Oil and Gas Conservation Commission (AOGCC) witnessed a safety valve system test on North Fork Unit (NFU) well 42-35 operated by Cook Inlet Energy (CIE). As part of the safety valve system inspection,AOGCC checked NFU 42-35 for appropriate wellhead equipment', and for compliance with sustained casing pressure rules2. The safety valve system performance tests passed but AOGCC was unable to verify the tubing-casing and casing- casing annuli pressures. A copy of the inspection report is attached. The facts reported by the AOGCC Inspectors indicate a violation of State regulations. Inspection revealed that NFU 42-35 is equipped with tubing and tubing-casing pressure gauges. The tubing-casing annulus gauge is located in the well cellar,below grade, and the well cellar has been fitted with a cover that was observed to be mostly buried by snow and ice. The actual pressures for the tubing-casing and casing-casing annuli were not able to be confirmed. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with the following: 120 AAC 25.200 2 Conservation Order 649—Regulating Sustained Casing Pressures in Development Wells within the North Fork Unit;June 21,2011. • • Docket Number:OTH-17-009 Notice of Violation March 7,2017 Page 2 of 2 - Records verifying that the tubing, tubing-casing annulus, and casing-casing annulus pressures for all NFU wells have been physically checked each day; and - Corrective actions to prevent recurrence of this violation at CIE-operated fields. Failure to comply with this request will be an additional violation, subject to an enforcement action. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, P4t4i --- Cathy . Foerster Chair, Commissioner Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • al c 60 , 006, o 0 6, °a'i on p .a a_ a , a e,, aim Oa > cct . o •� oLu3t Y E a tEi 4- ?v a3 a o `° cc 2 .2 ai o ° d 0 T O y o d 0 y' 1. t soF y L 3 -O a s g ° o ° o i ✓ x ° Q v' co6 bv op te = o W N O 71, ma by •O 3 C . a ,- G Wu a a z y a) "10 zu. o N a 3 V 4.Q 44 ct -4--) C a O. :nom ° E c oyi F" a U h C h V L' Cl) CQV 7a E y -' ham cl io It a � a Cl) 0 N a) o, ti 7) • o aC7yU, 9 a 33 " - I) �- W A U W C7 a 4. V "0 o a 0• O F U ,—.1 ami U , " v ct CCL H U a O161 4. VI ,, t, .. ec l CAI - t F- Ct y r/� M y C. v C i o E � N a z `1 o • O44 N 1. tt OI z ,. • 44 d 0 H ` wan 0CIZ d e M Z d = N E 0 R z o U.S. Postal Service"' CERTIFIED MAIL° RECEIPT Domestic Mail Only .i- III For delivery information,visit our website at www.usps.com . `, f i F Al , t r- 43 Certified Mail Fee .7 $ r-4 Extra Services&Fees(check box,add fee as appropriate) ['Return Receipt(hardcopy) $ CI ❑Return Receipt(electronic) $ Postmark 0 El Certified Mail Restricted Delivery $ Here O0 Adult Signature Required $ D Adult Signature Restricted Delivery$ E3 Postage ...0 $ Total Postage and Fees ,a Leland Tate 14 Sent To Chief Operating Officer a Cook Inlet Energy O Street and Apt.No.,or PO Sox No. r.- 601 W.5th Ave.,Ste. 310 City,State,zrP+0 Anchorage,AK 99501 I , SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3. A. • Print your name and address on the reverse Xl 0 Agent so that we can return the card to you. .� /�A.) i 0 Addressee II Attach this card to the back of the mailpiece, 3. ec/�l,_• b r Name) C. pate of Delivery or on the front if space permits. If t / 1 D. Is delivery a.dress different from item 1? 0 Yes If YES,enter delivery address below: 0 No Leland Tate Chief Operating Officer .. L i lit t Cook Inlet Energy . 601 W. 5th Ave.,Ste. 310 MAR 1 0 2017 Anchorage,AK 99501 Mil i r III 111111 Ilii 11 1111 I' III 3. Service Type ❑PriorityeiMail Express® ❑Adult Signature ❑Regis4ered MaiIT'" o Adult Signature Restricted Delivery 0 Registered Mail Restricted O Certified Mail® Delivery 9590 9402 1823 6104 6489 79 0 Certified Mail Restricted Delivery 0 Return Receipt for ❑Collect on Delivery Merchandise 0 Collect on Delivery Restricted Delivery 0 Signature Confirmation,"' 2. Article Number(Transfer from service /aheDed Mail 0 Signature Confirmation 7 015 1660 0000 1487 7241 ed Mail Restricted Delivery Restricted Delivery _ - _ __ , $500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Regg, James B (DOA) From: Regg,James B (DOA) Sent: Monday, March 06, 2017 2:17 PM To: Carlisle, Samantha J (DOA) Subject: Notice of Violation - NFU 42-35 Attachments: NFU_nov_SCP_monitoring_3-3-17.docx; NFU 42-35 SVS 3-1-17.pdf Letter attached. Please final. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. 1 1, 0 • i i >. f tO fir, , gy, L LC. : . N F U # d4 2- 3 5 o n e ner API # : 231 -200 .4 ,; - Dcation : lhIs :3 ' FEL,I FEL, SEC . 26, T4S, R14WY Sil • • no , se a .1 . 1 , , v k • 1 i - .S y i� • � r, T. . -- c- Ivy O "l P1' ''''7 kilt '\riii ' 1 -''''t•.N. . ''''::: ',. - ''1., r r ii('- ' - ' (1 , ,.. I . ,,.. . - rs)1,,, „, ,, • f 4, _ Att fr ,, lt. N1,-, , \ ,.• ,. , ,..,,, ..: , .,„ ',a: ...., v. ..' -44, ., Ir."... • • x 1 lOP , , , ' -., : , isAilh,.. 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( ✓ . „lilt.% 4 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: Regulating Sustained Casing Pressures in ) Docket Number: CO-11-17 Development Wells within the North Fork ) Conservation Order No. 649 Unit. ) ) North Fork Unit ) Kenai Peninsula Borough, Alaska ) June 21, 2011 IT APPEARING THAT: 1. On its own motion, the Alaska Oil and Gas Conservation Commission (Commission) proposed to adopt rules regulating sustained annulus pressures in North Fork Unit development wells. 2. Notice of opportunity for a public hearing on the proposal was published in the Peninsula Clarion on May 5, 2011 and was provided to the operator of the field, Armstrong Cook Inlet LLC (Armstrong). 3. No protests to the application or requests for a hearing were received. 4. No written comments on the proposal were received. FINDINGS 1. Armstrong is the operator of the North Fork Unit gas field, located approximately 7 miles east of Anchor Point, Kenai Peninsula, Alaska. 2. In considering proposed rules regulating sustained casing pressures in North Fork Unit development wells, the Commission reviewed files for wells in the North Fork Unit, the Halliburton Cementing Tables, information on well pressures provided by the operator, and the records of annular pressure rules for other fields in the state. 3. Annulus pressure is common in development wells. Pressures may be purposely imposed, thermally induced or the result of leaks in tubing, casing, packer or other well components. 4. Excessive annular pressure can develop in wells as a result of thermal effects. Well startup can involve significant annular pressure increases due to fluid expansion as a well heats above ambient temperature. Changing produced fluid characteristics and production mechanisms can also create thermal conditions that affect annular pressures. • • Conservation Order No 649 June 21, 2011 Page 2 of 4 5. Commission regulations require all producing wells capable of unassisted flow to be completed with suitable tubing and packer that effectively isolates the tubing-casing annulus from fluids being produced. Wellhead equipment must include appropriate gauges and valves on the tubing, casing-tubing annulus and casing-casing annuli to show surface pressures and control flow for the range of conditions expected (20 AAC 25.200(c) and (d)). 6. No current AOGCC regulation or order for the North Fork Unit establishes annular pressure management requirements for producing wells, similar to those for injection wells. However, such requirements for producing wells in other Alaska fields have been established by Commission order. 7. Several practicable techniques are available to manage annular pressures including manual pressure bleeding and engineered solutions such as pressure controls and pressure relief systems. 8. Values of"burst pressure rating" and "minimum internal yield pressure" of well tubulars are numerically equal. 9. Pertinent characteristics of well construction in the North Fork Unit are similar to those in other Alaska fields. 10. Pressure in an active North Fork Unit well not exceeding 45% of the burst pressure rating, or minimum internal yield pressure, of well tubulars is within the range of pressure that will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. CONCLUSIONS 1. There is a need for regulatory oversight of the management of North Fork Unit wells that exceed specific pressure thresholds by administering rules regulating annular pressures. This methodology is consistent with similarly intended efforts by other regulatory agencies. 2. The objectives of rules regulating sustained annular pressures in North Fork Unit development wells are to conserve Alaska petroleum resources and protect human safety and the environment through proper management of annular pressures. Proper annular pressure management aims to prevent failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 3. North Fork Unit annular pressure rules should recognize the well completion design and development well characteristics in the North Fork Unit. 4. The annular pressure rules adopted in this order are practicable and appropriate to the objectives stated in Conclusion 2. 5. Data provided by Armstrong indicate flowing and shut in temperatures are not significantly different, with the well actually cooling when on production. Therefore, • • Conservation Order No 649 June 21,2011 Page 3 of 4 there is no need to include requirements to address the potential for significant annular pressure increases due to fluid expansion as a well heats above ambient temperature. NOW THEREFORE IT IS ORDERED that the following rules apply to development wells within the North Fork Unit, as the unit boundaries exist on the date of this order: 1. The operator shall conduct and document a pressure test of tubulars and completion equipment in each development well at the time of installation or replacement that is sufficient to demonstrate that planned well operations will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 2. The operator shall monitor each development well daily to check for sustained pressure, except if' prevented by extreme weather conditions, emergency situations, or similar unavoidable circumstances. Monitoring results shall be made available for Commission inspection. 3. The operator shall notify the Commission within three working days after the operator identifies a well as having (a) sustained inner annulus pressure that exceeds 2000 psig or (b) sustained outer annulus pressure that exceeds 1000 psig. 4. The Commission may require the operator to submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action or increased surveillance for any development well having sustained pressure that exceeds a limit set out in paragraph 3 of this rule. The Commission may approve the operator's proposal or may require other corrective action or surveillance. The Commission may require that corrective action be verified by mechanical integrity testing or other Commission-approved diagnostic tests. The operator shall give the Commission at least twenty-four (24) hours notice for opportunity to witness diagnostic testing, refer to Industry Guidance Bulletin 10-001 for proper contacts. 5. If the operator identifies sustained pressure in the inner annulus of a development well that exceeds 45% of the burst pressure rating of the well's production casing for inner annulus pressure, or sustained pressure in the outer annulus that exceeds 45% of the burst pressure rating of the well's surface casing for outer annulus pressure, the operator shall notify the Commission within three working days and take corrective action. Unless well conditions require the operator to take emergency corrective action before Commission approval can be obtained, the operator shall submit in an Application for Sundry Approvals (Form 10-403) a proposal for corrective action. The Commission may approve the operator's proposal or may require other corrective action. The Commission may also require that corrective action be verified by mechanical integrity testing or other Commission-approved diagnostic tests. The operator shall give the Commission at least twenty-four (24) hours notice for opportunity to witness diagnostic testing, refer to Industry Guidance Bulletin 10-001 for proper contacts. . • • Conservation Order No 649 June 21, 2011 Page 4 of 4 6. For purposes of these rules, "inner annulus" means the space in a well between tubing and production casing; "outer annulus"means the space in a well between production casing and surface casing; "sustained pressure" means pressure that (a) is measurable at the casing head of an annulus, (b) is not caused solely by temperature fluctuations, and (c) is not pressure that has been applied intentionally. DONE at Anchorage,Alaska and dated June 21, 2011. Daniel T. S- oun t, Jr., Commissioner, Chair 0. a.: a Conservation Commission dir..„..,..,,,,,,,,,,.. , ..„,...„ SS ` ° s 41 AL .v w. T. a - , Co nussloner A as ` and Gas Con -- ion Commission 44-2 ---e--"\- Cathy P. F.erster, Commission r Alaska Oi and Gas Conservation Commission RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the Commission grants for good cause shown,a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FiNAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration,this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission,and it may appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p,mon the next day that does not fall on a weekend or state holiday, 0 • North Fork Unit 42-35 PTD 2141700 Data from AK RBDMS Production History Report Date Oil Produced Water Produced Gas Produced Producing Days 01-Jan-17 0 10 5199 31 01-Dcc-16 l 0 1 19 6528 1 31 I 1_,.. 01-Nov-16 ____1 ®_ 0 10 7255 30 4 01-Oct-16 0 15 6754 25 01-Sep-16 0 il0 5375 25 01-Aug-160 20 8097 - 31 01-Jul-16 1 0 16 8129 i 31 01-Jun-16 0 20 8515 30 01-May-16 0 i 8 6705 31 1 01-Apr-l6 0 l0 4046 30 . . mom_ 01-Mar-16 1 0 44 8255 31 01-Feb 16 0 34 8475 29 01-Jan-16 0 1 33 8961 1 31 4--. . — e 01-Dec-15 0 I 27 8190 31 01-Nov-15 056 8644 30 $ r_ 01-Oct-15 0 30 ` 8087 31 01-Sep-15 0 i 0 7821 30 1 01-Aug 15 0 I 19 L 9530 31 01-Ju115 1 0 17 i 8657 31 01-Jun-15 0 18082 30 01-May-15 0 2 i 10214 31 € 01-Apr-15 0 i 6 6301 18 1--[ O1-Mar-15 0 63 i 2440 7 01-Feb-14 0 0 0 ' 0 STATE OF ALASKA AL. OIL AND GAS CONSERVATION CO Y, ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑✓ SPLUG ❑ Other ❑ Abandoned ❑ Suspended EI lb.Well Class: 20AAC 25.105 20AAC 25110 Development 0 - Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Dab Comp.,-$usp.,or 12. Permit to Drill Number: Cook Inlet Energy,LLC Abd-- 2/3/2015- 214-170 3.Address: 6. Date Spudded: 13.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 1/2/2015. 50-231-20046-00-00 • 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 588'FSL& 1453'FEL Sec 26 4S 14W • 1117/2015' North Fork Unit 42-35 . Top of Productive Horizon: 1310'FNL&919'FEL Sec 35 4S 14W 8. KB(ft above MSL): 6l8•$.om 15. Field/Pool(s):- „t GL(ft above MSL): ° g 5 4. North Fork Total Depth: 2502'FNL&582'FEL Sec 35 4S 14W 9. Plug Back Depth(MD+TVD): tjt,cJ/el-t. ` „ 015 N/A b'i'�'p'c7../y,.� L 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation;.. Surface: x- 199,958 ' y- 2121128 ' Zone- 4 • .9968'+9046' ADL 3912101 Al)° 3i'4rt..; `t' - TPI: x- 200435.21 y- 2119032.03 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: ,/- Total Depth: x- 200686.45 y- 2117976.74 Zone- 4 357'+357' LOCI 10-004 18. Directional Survey: Yes El No 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC?5,971): 22.Re-drill/Lateral Top Window MD/TVD: LWD, Realtime log,Resistivity,compensated Neutron,Compensated Density,Gamma Ra CBL, J N/A 23. CASING, LINER AND CEMENTING I EGO• D WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 84 N/A 0 120 0 120 Driven N/A NONE 9 5/8" 40#SD L-80 0 2920 0 2750 12 1/4" 12ppg Lead 546 SXS+13ppg Tail 162 S NONE 7" 26 L-80 0 9948 0 9026 8 3/4" 13.5ppg Lead 816 SXS+13 5ppg tall 92 SX NONE 24.Open to production or injection? Yes O . No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): Total Perfs 185' 2 7/8"6.5#L-80 9,504'MD 1.5538/4911 Cont.2.5829/5149 3.7158/6278 4.8107/7187 5.8961/8045 4954-4967 TVD 5590-5606 MD rwm 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. 5093-5089 TVD 5737-5760 MD ` 7,.i f _ Was hydraulic fracturing used during completion? Yes El No ❑✓ 5269-5291 TVD 5974-6000 MD '1,11 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 5676-5693 TVD 6467-6488 MD 6317-6336 TVD 7200-7220 MD 7240-7258 TVD 8160-8178 MD 7977-7993 TVD 8898-8914 MD 8581-8597 TVD 9502-9518 MD 8606-8620 TVD 9527-9541 MD 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 3/24/2015 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 3/24/2015 3 Test Period .......N/A 47 0 11/128 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(carr): Press. 274 0 24-Hour Rate -► N/A 375 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ . Sidewall Cores Acquired? Yes El , No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. See attached sheet for Core Depths ' Form 10-407 Revised 19/2912 CONTINUED ON REVERSE U 2mi f incl only /2 7-/5"-/ -.-V_:_,-, RBDMS . 1L APR 1 A 9�f11; ,n, _ ,'i l' • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 7, Yes No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top N/A N/A and submit detailed test information per 20 AAC 25.071. Permafrost-Base N/A N/A Beluga 1390 1326 Tyonek 5304 4720 Formation at total depth: 31. List of Attachments: 10-407,Wellbore Schematic,Daily Drilling Summaries, Direction Surveys,Casing and Cement Report,and Core Depths 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Conrad Perry Email: Conrad.PerrVC se jr�let.rlet Printed Name: Conrad PA'7 riai= Title: Drilling Manager Signature: Phone: (907)727-7404 Date: 3/26/2014 INSTRUCTIONS General: This form is designed for sub fitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • 1 42-35 Final Completion Schematic • Version: FINAL _ Cook Inlet Energy / r-X0 a; February 23,2015 1.\ ' 1 i.... 20"Conductor I 20" L-80 120'MD . L 19" Welded 120'TVD .,t, . I ,„ .,.._ 1.,,,. . .. _ TRSSSV @+/-357'MD-2.313"ID 4 2 7/8"Chemical Injection ' 1 i Mandrel i+1-2521'MD-2.313"ID 12 1/4"Hole ,.. l 9 5/8" 40#L-80 2,920'MD ' i Ft ID 8.835" BTC 2,750'TVD tAll Sleeves Open Down i ,!•,, ',,, .T Sliding Sleeve @ 5489'MD-2.31"ID Perforations1 l' . Tripoint Hydraulic Set Packer @ 5538' 1Sliding Sleeve @ 5588'MD-2.31"ID MD TVD Zone#1 a " 5590-5606 4954-4967 Zone 1 i` 7 5737-5760 5093-5089 Zone 1 ' Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 ,' - - Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 Zone#2 7200-7220 6317-6336 Zone 3 =It it zajc, 8160-8178 7240-7258 Zone 4 _ Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 Sliding Sleeve @ 7206'MD-2.31"ID 9502-9518 8581-8597 Zone 5 Zone#3 9527-9541 8606-8620 Zone 5 Tripoint Hydraulic Set Packer @ 8107' Sliding Sleeve @ 8155'MD-2.31"ID ...r =01 .- ,,:1 . mmi 1- i a= , Tubing punch 8910'-8920'MD Future Perfs Thru Tbg Zone#4 MD TVD 9296-9300 8375-8379o., Tripoint Hydraulic Set Packer @ 8961' 9808-9816 8886-8894 Ir. a Nipple @ X 9004'MD-2.313"ID 9894-9896 8972-8974 rt ' .m., .,e. ,,.,,..a XN Nipple @ 9037'MD-2.205"ID ® ' ; ,. , , _- RA marker @ 9394'MD Zone#5 =IC ,, t - Tubing 2 7/8" 6.5#L80 EUE 9,504'MD I ID-2.441" BTC 8,583'TVD Est,TOF @ 9.806'MD IPBTD @ 9,858'MD 8,936'TVD TD at 9,968'MD 1 9,046'TVD 7" 26# L-80 9,948'MD 8 3/4"Hole ID-6.276" GeoCon 9,026'TVD ` J ,,p March 7/, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 9 Leland Tate Chief Operating Officer Cook Inlet Energy 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: Docket Number: OTH-17-00x Notice of Violation Sustained Casing Pressure Monitoring North Fork Unit 42-3 5 (PTD 2141700) Dear Mr. Tate: On March 1, 2017, the Alaska Oil and Gas Conservation Commission (AOGCC) witnessed a safety valve system test on North Fork Unit (NFU) well 42-35 operated by Cook Inlet Energy (CIE). As part of the safety valve system inspection, AOGCC checked NFU 42-35 for appropriate wellhead equipment', and for compliance with sustained casing pressure rules2. The safety valve system performance tests passed but AOGCC was unable to verify the tubing-casing and casing- casing annuli pressures. A copy of the inspection report is attached. The facts reported by the AOGCC Inspectors indicate a violation of State regulations. Inspection revealed that NFU 42-35 is equipped with tubing and tubing-casing pressure gauges. The tubing-casing annulus gauge is located in the well cellar, below grade, and the well cellar has been fitted with a cover that was observed to be mostly buried by snow and ice. The actual pressures for the tubing-casing and casing-casing annuli were not able to be confirmed. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with the following: ' 20 AAC 25.200 2 Conservation Order 649—Regulating Sustained Casing Pressures in Development Wells within the North Fork Unit;June 21,2011. • S Notice of Violation North Fork Unit--- March--,2017 Page 2 of 2 - Records verifying that the tubing, tubing-casing annulus, and casing-casing annulus pressures for all NFU wells have been physically checked each day; and - Corrective actions to prevent recurrence of this violation at CIE-operated fields. Failure to comply with this request will be an additional violation, subject to an enforcement action. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, 9 Chair, Commissioner Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. . S • R E CETE • STATE OF ALASKA FEB0 T 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 () 1.Type of Request: Abandon U Plug PerforationsLi uuFracture Stimulate Repair Well Operations shutdownu Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill • Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name: 4.Current Well Class: 5.P it to Drill Number: Cook Inlet Energy,LLC Exploratory El Development 214-170 3.Address: Stratigraphic Service 6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20046-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A / North Fork Unit 42-35 . Will planned perforations require a spacing exception? Yes I__I No V, ' 9.Property Designation(Lease Number): 10.Field/Pool(s): NN 391210/11 , l L 39%Z./(� �G-3V/Z-1/ north Fork s r/) ,n 11. l -1./,PRESENT WELL CONDITION SUM • - die' Total Depth MD(ft): Total Depth TVD O: Effective Depth MD: Effective Depth TV r' -SP(psi): Plugs(MD): Junk(MD): 9W--6r � z.z:1. , 3&/2 P i Casing Length /- Size MD TVD Burst Collapse Structural - - 1 - - - Conductor 120 20" ,`i4 120 - - Surface 2920 9 5/8" • 920 2750 5750 3090 Intermediate - - 11'' - - - Production 9948 7" 0 9948 9026 7240 5410 Liner - - I r - - - - Perforation Depth MD(ft): Perforation Depth TVD(ft): .mg,8'(ze3 Tubing Grade: Tubing MD(ft): 5590'-9541' 4594'-8620' - \ 2 7/8" 6.5#L80 EUE 9,504' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV:357'MD 5 Tripoint Hydraulic Set Packe +TRS V (5) Packers-5538'MD;5829'MD;7155'MD;8107'MD;8961'MD 12.Attachments: Proposal Summary N W=.. -schematic IN 13.Well Class after proposed work: Detailed Operations Program DI BOP S r I I Exploratory I I Stratigraphic I I Development D(I •Service I I 14.Estimated Date for , 15.Well Status after proposed work: /�;� at•61/ Commencing Operations: 41Apr-16 OIL ID WINJ WDSPL ' p nd Sus ended 16.VerbalApproval: • ': GAS 0 WAG GSTOR SPLUG ■ Commission Representative: GINJ Op Shutdown Abandoned 17.I hereby certify that the foregoing is true a •the procedure approved herein ►u • will not be deviated from without prior wri ..proval. .. -`''fiL Contact Stephen Ratcliff 907-433-3808 Email stephen.ratcliff@cookinlet.net Printed Name C—^� Title 1-Feb-16 Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Co ission so that a representative may witness SundryT1umber.'" -.• \ le — °( '�'�...�s Plug Integrity i BOP Test [] Mechanical Integrity Test [J Location ClearanceEl Other: ,- 1. 5.00 p 5 i. ec (GS t SCANNED Post Initial Injection MIT. eq'd? Yes ❑ No MA617 Spacing Exception R=•uired? Yes 0 No Subsequent Form Required: / 0 — ( O 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ' 'Submit-Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ' `� A RBDMS 1L- OCT 3 1 2016 iS z-z,r • • Cook Inlet Energy_ February 1, 2016 RECEIVED FEB 0 1 2016 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application to plug/abandon for sidetrack Cook Inlet Energy, LLC: North Fork Unit 42-35 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby applies for a sundry to plug back the North Fork Unit 42-35 well, located on ADL 391210/11 and land use permit: LOCI 10-004, in the North Fork Unit. A new PTD will be submitted for the upcoming sidetrack of the well. Please find attached for review of the Commission the 10-403 Form, Abandonment Procedures,Well Information, and Proposed Well Schematics,as required by 20 ACC 25.005. Abandonment work will commence approximately April 1, 2016. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling&Completions Engineer Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 • • Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 42-35 Requirements of 20 MC 25.005(f) Well Summary Current Status: Development Well, but not performing up to its believed potential Scope of Work: • Plug and abandon current wellbore • Prepare for sidetrack General Well Information: Reservoir Pressure/TVD: 3,917 psi @ 9,968'MD/ 9,046'TVD . MASP: 3,012 psi • Wellhead Type/Pressure Rating: 11" Multi-bowl 5K GE Wellhead Well Type: Gas Producer Estimated Start Date: April 1, 2016 Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Stephen Ratcliff (907) 433-3808 Stephen.Ratcliff@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 3 • Cook Inlet Ener gY- 2. Location Summary Requirements of 20 AAC 25.005(c)(2) • General Location Kenai Peninsula Borough,Alaska • Ground Elevation 657.8' above MSL • KB Elevation 678.5' above Ground Elevation • RKB 20.7' above GL I X-Coordinate ! Y-Coordinate FNL/FSL FEL/FWL Sec/T/R Surface Location 199958.04 , 2121128.25 588'FSL 1453'FEL Sec 26 T4S R14W S.M Bottom Hole Location 200686.45 2117976.74 2502'FNL 582'FEL y Sec 35 T4s R14W k S.M See Attachment 1: As-Staked Site Survey 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) Operations will not include utilizing a drilling rig. Work performed will be through the production tree and a lubricator when applicable. See Attachment 2: Wellhead / Tree Schematic 4. Drilling Hazard Analysis Requirements of 20 AAC 25.005(c)(4) Maximum Down Hole Pressure: Normal Pressure Expected Reservoir Pressure: = (Formation pressure gradient)*(TVD) = (0.433 psi/ft)*(9,046') = 3,917 psi Maximum Anticipated Surface Pressure: = (Max Pore Pressure - (GasGRD X TVD) = (3,917 psi) - (0.10 psi/ft X 9,046') = 3,012 psi 5. Formation Integrity Test Procedure Requirements of 20 AAC 25.005 (c)(5) • Not applicable for this portion of the project 6. Casing and Cementing Program Requirements of 20 AAC 25.005 (c)(6) 4 • Cook Inlet Energy_ Cementing Summary: Utilizing the down squeeze method, CIE will ensure sufficient volumes of cement for covering from 100' below the bottom perforation to the packer for each of the four intervals. For the exceptions where the 100' mark is limited by another production packer the cement interval will go from packer to packer. See Attachment 3: Cement Program 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Not Applicable 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) Not Applicable 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) Only applicable for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f) 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) Only applicable for an exploratory or stratigraphic test well, a seismic refraction, or reflection analysis as required by 20 AAC 25.061(a) 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) Only applicable for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of conditions as required by 20 AAC 25.061(b) 12. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of Bonding is on file for Cook Inlet Energy with the Commission 5 • • Cook Inlet Energy_ 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) Abandonment Procedure- NFU 42-35 1. Note -Abandonment Work Performed will be with out a Drilling Rig a. Plan to Utilize Pollard Wireline for Shifting Sleeves b. Plan to Use SLB Pressure Pumping Unit for Cement Operations 2. AOGCC must be notified 48 hours in Advance of Plugging the Perforations 3. Rig Up Pollard Slick Line Unit for Opening&Closing Sleeves 4. Pressure Test Lubricator to 2,500 psi 5. RIH with Shifting Tool a. Plan to Close all Sleeves with the Exception of Zone 1 b. Confirm that Zone 1 Sliding Sleeve is Open for Abandonment 6. Rig Up and Test Cementing Head and Lines, per SLB Procedure 7. Establish Injection Rate into Zone 1 Perforations a. If Injection is Established then Prep to Pump Cement 8. Mix and Pump 10.5 bbls of 15.8 ppg Class G Cement (5,829'-5,538') 9. Bullhead Down Tubing to Zone 1 using Down Squeeze Method a. AOGCC Requires Cement from 100' Below Bottom Perfs to Packer b. Chase with Wiper Plug 10. R/U Slickline &Prep to Open Sleeve above Zone 1 11. RIH with Shifting Tool and Open Sliding Sleeve above Zone 1 12. Rig Up&Prep for Cementing 13. Mix and Pump 2.5 bbls of 15.8 ppg Class G Cement (5,538'-5,470') a. Set Cement on Top of Zone 1 Packer b. Chase with a Wiper Plug / Zocor s 14. Rig Down Cements &Equirent +-c- T S 15. R/D Slick Line Unit 16. R/U E-Line Unit&Prep for Tubing Cut C/9)6 --' a. Utilize Gamma/CCL to Confirm Cut Location 17. RIH with Severing Tool to 5,460' 18. Correlate to Depth and Confirm with CIE Engineer prior to Firing 19. Fire Severing Tool 20. POH and Confirm Tools Functioned 21. R/D E-Line 22. Prepare to Move Rig over Well for Sidetrack Operation See Attachment 4: Current Wellbore Schematic See Attachment 5: Proposed Abandonment Schematic 14. Drilling Waste Storage Requirements of 20 AAC 25.005(c)(14) Not Applicable 6 ! • Cook Inlet Energy_ 15. Geological Formation Tops Requirements of 20 AAC 25.071 FORMATION TOPS Formation MD TVD SSTVD Potential 4900 SD 5,414' 4,803' (-4,124') Gas 5300 SD 5,833' 5,171' (-4,492') Gas 5450 SD 6,033' 5,353' (-4,674') Gas 5600 SD 6,191' 5,501' (-4,822') Gas 6000 SD 6,632' 5,913' (-5,234') Gas 6100 SD 6,729' 6,021' (-5,342') Gas 6700 SD 7,370' 6,652' (-5,973') Gas 6800 SD 7,460' 6,741' (-6,062') Gas 7800 SD 8,611' 7,874' (-7,153') Gas 7950 SD 8,670' 7,933' (-7,233') Gas 8050' SD 8,728' 7,989' (-7,310') Gas Total Depth* 8,891' 8,150' (-7,471') 16. Logging Plan Requirements of 20 AAC 25.071 (a) Not Applicable 17. Regulatory Waiver and Special Procedures Requests Not Applicable Attachments 1. As-Staked Site Survey 2. Wellhead/Tree Schematic 3. Cement Program 4. Current Wellbore Schematic 5. Proposed Abandonment Schematic 7 • 11111_________. 11, EDGE OF R.O.W. ROAD ®®®®®®\®1 k \ NORTH FORK � _ 4...4� �F A4q �i® h6 ` — — 100RNV N 2121143.9950 =' P..• .,�.•. ,�®� I CP-1 E 1340068mO° C.).• TH%\ .'� N 2121137.2190 ELEV 666.07 /11' ow*:•49— * O' E 1339704.6100 EDGE OF R.O.W_-__ �� 1_,ELEV 656.55.._ •. D :,;tom � , �� - ip�L .%/� ya. TZr s! / , �, •..ST/AN A. McLANE . ,, of r - f/I yX ��I I O m 1/� pESSIONP�LP®®® ii;;AA m a b�� Tract 18 6- ‘5` GATEo S VD w 1 i ❑ a o o 34-26 WELL 32-35 WELL 14-25 WELL Ili 23-25 WELL ' m Ix NFU 42-35 WELL L� 1453' _ N:2121128.246 ' I > FEL E:199958.041 ; CIi I o LATITUDE: 59°47'46.358"N ' I ❑ LONGITUDE: 151°37'44.913"W CC? ❑ NAD 27 ASP ZONE 4 ,41.'"►� OHE— w ELEV. 657.8'NAVD88 00 e Tract 19 in I o 0 I I =North Fork Acres Subd. No. ® 1- o CO o L-----=_=X X x x — .\ W tee® =-- ® i — -, II _re o k"....NCS \ \\ _` \ — TOP OF BERM U y \\ I a N 2120505.98 Section 26,TO4S,R14W,S.M.,AK. _ ' — —— E 201396.26 S26 S25 S35 S36 -=--_-...- -- ... ........ c NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N OR T H BASE STATIONS"KEN5°,'TSEA°AND'KOD5'OBSERVED DEC.13,2007 ON NF1 312°ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.89' 11-4= • 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. SCALE 0 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0 200 I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 FEET AND NOT THE PROTRACTED SECTION CORNER VALUES. PROJECT REVISION: - NORTH FORK 42-35 WELL DATE: 102114 k` Cook Inlet Energy_ AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BOB NAD27 FOR INFORMATIONAL PURPOSES SSE: 1°=1007 ONLY PROJECT NO. 143135 ENGINEERING/MAPPING/SURVEYING I TESTING BOOK NO. - Consulting Inc P.O.BOX 468 SOLOOTNA,AK.99669 LOCATIONWial SW 1/4 SE 1/4 SKEET VOICE:1907)2834218 FAX:(907)283-3285 EMAIL:BAMCLANE@MCLANECG.COM S26 745 R14W SEWARD MERIDIAN,ALASKA 1 OF 1 • 0 COvEDGE OF R.O.W. ®®K ROAD — ®"Ika.. \®�16 NORTH h \ 1 0® R� N 2921143.9950 ® (� �0 A-•.....,„e_ -er l® CP E 1340068.0700 * 49 TH i * • N 2121137.2190 EL=868:07 /� E 1339704.6100 EDGE OF R.P.W.—_ f /I/�6Zefl� �� ELEV 656 291 . • --- ' �C/ 60 ���- ��a._ �- -t� e I �, STAN A. McLANE : ,�i T by3 `�_ sr •. 4637-S u" ,7 i ••. ••• 4) '`, X �' 1-- -1 11,11E�FSSIONA� ®� /(1 656 O a� • \®®®®®® re 6 Tract 18 s9 GATE �, X D Z 0 ND 34-26 WELL 32-35 WELL 14-25WELL 23-25 WELL �� D Q_. 'r I x o �, x J I NFU 42-35 WELL �, • I > FEL' I L� N:2120883.406 i 1 ' g E:1339983.463 LATITUDE:59°47'44.156"N1:: C9 ,, 0 LONGITUDE: 151°37'52.681"W i 1111NAD 83 ASP ZONE 4 .4;.' 'HE w 'Co e I x ELEV.657.8'NAVD88 op u i y Tract 19 o / ( c North Fork Acres Sub/i. No. 2 ® o X X CD �_ X X — ® 2 Q ��� 11� I I N®N 6p <\ b I 1.1. h LO 6 \ bt TOP OF BERM U t \\\ k 1 \ \ t I /ma. I N 2120261,15 Section 26,TO4S,R14W,S.M.,AK. E 1341421.67 — — J — — S26 S25 S35 S36 NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N OR TH BASE STATIONS°KEN5°,-TSEA°AND•KOD5'OBSERVED DEC.13,2007 ON NF1 3 1/2'ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' C 1 1 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.160.84 FT. 0 SCoGLE aoo 3)SOUTHEAST VD88 DATUM. 3)STHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT I I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 FEET I AND NOT THE PROTRACTED SECTION CORNER VALUES. \ / PROJECT REVISION: - (, NORTH FORK 42-35 WELL DATE: 10'3/14 Cook Inlet Energy AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BOB SCALE: 1'=100' NAD83 PROJECT NO. 143135 it ENGINEERING/MAPPING/SURVEYING/TESTNG BOOK NO. - GonwlBny Inc P.o.Box 468 SOLOOTNA aK 98869 LOCATION S W 1/4 SE 1/4 SHEET =42F#17 VOICE:(901)2834218 FAX:(907)2833265 1 �yr��V EMAIL 6AMCLANE®MCUWECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA 1 OF ill 41111 . 01-6 0 GE Oil & Gas 1 47.7' O 30.2" 411111 ) 28/18'SM illi ,) 2-9/18'SM -f ,,4° 2-9/1r SM 2-0/16'5M Ill 1 45.6" 411. ) 28/18'5M ,27.2' Ilk I I 11'5M "-. t. f , + I •t. 26.5°to I 16.0° • 'r -' • 11'SM —"' �.: 9 ='A 2-1/16°5M 1P 285 to 1, r ' 11:13:1;g , L I iif - i�ru r 31.7° Li tili r'1 2-1/16°5M Al 11111111111111i I I -111.1111111111128°O.D.Base Plate 95/8°Casing I,7"Casing 2-7/8°Tubing IL_ 1/4°Control Line ALL DIMENSIONS ARE APPROXIMATE This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in waiting, COOK INLET ENERGY42-35 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE DI&Gas Pressure Control LP. 9-5/8" x 7" x 2-7/8" 5M SH2 Wellhead Assembly, DRAWN CR 080CT14 APPRV KN 080CT14 With T-M40-CCL Tubing Hanger and Adapter Flange FOR REFERENCE ONLY DRAWING NO. 1001107-2 • 0 klikelargi- Laboratory Cement Test Report NFU 42-35 Abandonment Plan Com position Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fluid 5.107 gal/sk Solid Vol.Fraction 41.183% Porosity 58.817% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number G 94 lb of CEMENT Blend 3.20 SG Fresh water 5.067 gal/sk Base Fluid D046 0.200%BWOC Antifoam CW4M0615A1 D065 0.300%BWOC Dispersant 6108 D167 0.200%BWOC Fluid loss ESD0900677 D177 0.040 gal/sk Retarder 2015061AL Rheolo 80 de!F 148 de!F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 84.0 84.0 84.0 63.0 63.0 63.0 200 65.0 63.0 64.0 45.0 46.0 45.5 100 45.0 41.0 43.0 26.0 25.0 25.5 60 36.0 32.0 34.0 20.0 18.0 19.0 30 31.0 25.0 28.0 10.0 16.0 13.0 6 25.0 16.0 20.5 4.0 3.0 3.5 3 18.0 14.0 16.0 2.0 1.0 1.5 10 sec Gel I 18 deg-19.21 Ibf/100ft2 I 2 deg-2.13 Ibf/100ft2 10 min Gel 36 deg-38.42 Ibf/100ft2 9 deg -9.61 Ibf/100ft2 tGr Rheo.computed Viscosity 62.737 cP Yield Point:21.73 Ibf/100ft2o I y Viscosity:55.816 cP Yield Point:7.54 Ibf/100ft2 Thickenin Time ilii"iilency ` ,,.,. ime'ry *%I E 30 Bc 06:14 hr:mn Z 50 Bc 06:39 hr:mn 70 Bc 06:53 hr:mn 100 Bc 07:11 hr:mn Free Fluid (74 �u Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Fluid Loss API Fluid Loss 119 mL 50 mL in 23 min at 148 degF and 1000 psi Note: This is a pilot test. Field blend may differ after testing. Please read field blend report carefully and compare to pilot report and load out. Contact the laboratory with any questions or concerns. Page 1 • i NFU 42-35 Final Completion Schematic Version: FINAL Cook Inlet Energy_ March 30,2015 1 I. i ! ,?, 20" 120#L-80 120'MD 20"Conductor 19" Welded 120'ND A, ITRSSSV 0+/-35T MD-2.313"ID � r : 2 7/8"Chemical Injection • Mandrel @+/-2521'MD-2.313"ID " -. • 9 5/8" 40#L-80 2,920'MD 12 1/4"Hole ID 8.835" BTC 2,750'ND i. All Sleeves Open Down Zones 1 through 4 Open k as of Date 3-30-2015 71 -'^ '°r-4".."' 1Sliding Sleeve @ 5489 MD-2.31"ID Perforations .y -.-. Tripoint Hydraulic Set Packer @ 5538' Sliding Sleeve @ 5588'MD-2.31"ID MD ND Zone#1 5590-5606 4954-4967 Zone 1 5737-5760 5093-5089 Zone 1 Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 & Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 4044 i Xit { 7200-7220 6317-6336 Zone 3 , Zone#2 8160-8178 7240-7258 Zone 4 _ _ _ Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 2 4 t Sliding Sleeve @ 7206'MD-2.31"ID 9502-9518 8581-8597 Zone 5 Zone#3 9527-9541 8606-8620 Zone 5 - it • Tripoint Hydraulic Set Packer @ 8107' 11r Sliding Sleeve @ 8155'MD-2.31"ID I Mt Tubing punch 8910'-6920'MD EMEMTM MIN Zone#4 MD ND 9296-9300 8375-8379 XTripoint Hydraulic Set Packer a 8961' 9808-9816 8886-8894 k. 111, - X Nipple a 9004'MD-2 313"ID 9894-9896 8972-8974 ti, - XN Nipple @ 9037'MD-2.205"ID Plug In XN Nip•leami--. 1 - RA marker @ 9394'MD Zone#5 i Tubing 2 7/8" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'ND Est.TOF @ 9,806'MD 8 3/4"Hole (PBTD IID 9,858'MD 8,936'ND I I TD at 9,968'MD/9,046'TVD 1 7" 26# L-80 9,948'MD ID-6.276" GeoCon 9,026'TVD .NFU 42-35 Proposed Abandonment Schematic s Version: 2.0 Cook Inlet Energy_ 2/1/2016 r 20" _ 120#L-80 120'MD 20"Conductor JL 19" Welded 120'ND R' • • 1 1, •• 9 5/8" 40#L-80 2,920'MD 12 1/4"Hole ID 8.835" BTC 2,750'TVD a LY (21 Whipstock Top @ 5414' eJ 7"Bridge Plug 5,430'MD O- Tubing Cut 5,450'MD I J, t Top of Cement 5,470'MD •l,•, • `4!il• i Sliding Sleeve @ 5489'MD-2.31"ID Tripoint Hydraulic Set Packer @ 5538' • 1 Sliding Sleeve @ 5588'MD-2.31"ID Abandoned Perforations Zone#1 Tripoint Hydraulic Set Packer @ 5829' MD NDI' 5590-5606 4954-4967 Zone 1 I ,r Sliding Sleeve @ 5877'MD-2.31"ID Zone#2 5737-5760 5093-5089 Zone 1 a II 113C I 5974-6000 5269-5291 Zone 2 "' Tripoint Hydraulic Set Packer @ 7158' 6467-6488 5676-5693 Zone 2 Sliding Sleeve @ 7206'MD-2.31"ID 7200-7220 6317-6336 Zone 3 Zone#3 8160-8178 7240-7258 Zone 4 I 1 71=t 8898-8914 7977-7993 Zone 4 "?�—...n Tripoint Hydraulic Set Packer @ 8107' 9502-9518 8581-8597 Zone 5 Sliding Sleeve @ 8155'MD-2.31"ID 9527-9541 8606-8620 Zone 5 — SC I Tubing punch 8910'-8920'MD IZone#4 - •- Tripoint Hydraulic Set Packer @ 8961' II ,. X Nipple @ 9004'MD-2.313"ID ' XN Nipple @ 9037'MD-2.205"ID 11. RA marker @ 9394'MD Zone#5 U 7t 3:C Tubing j, 2 7/8" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'TVD Est.TOF @ 9,806'MD 8 3/4"Hole i L.k PBTD @ 9,858'MD 8,936'ND TD at 9,968'MD/9,046'ND 7" _ 26# L-80 9,948'MD ID-6.276" GeoCon 9,026'TVD • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the"Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and V initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the"Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, October 27, 2016 9:13 AM To: Conrad Perry; Stephen Ratcliff Cc: Carlisle, Samantha J (DOA) Subject: RE: NFU 42-35A status (PTD 216-017) P &A sundry 316-062 Conrad, The AOGCC will withdraw both the P&A request sundry 316-062 for well NFU 42-35 and the PTD application for the sidetrack#216-017 as requested. Neither application was processed to approval status. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Conrad Perry [mailto:cperry@glacieroil.com] Sent:Wednesday,October 26,2016 4:18 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>;Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RE: NFU 42-35A status Please retract. Thank, conrad From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Wednesday,October 26, 2016 3:58 PM To:Stephen Ratcliff<sratcliff@glacieroil.com>; Conrad Perry<cperry@glacieroil.com> Subject: NFU 42-35A status Have you decided if you are following through or would you like to retract the PTD and P&A sundry for now?? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 1 0 • ECEIVE STATE OF ALASKA JAN 2 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A ertt", 20 AAC 25.280 1.Type of Request: Abandon UPlug Perforations I=1 Fracture Stimulate U Repair Well U Or-rations shutdownU Suspend Perforate Other Stimulate Pull Tubing Cha•.eApproved Program Plug for Redrill ® El, Perforate New Pool Re-enter Susp Well Alter Casing ■ th- . 2.Operator Name: 4.Current Well Class: 5.Per " I..7 umber: Cook Inlet Energy,LLC Exploratory Development ` 214-170 • 3.Address: 6 tr. Stratigraphic B Service ber: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20046-00-00 - 7.If perforating: 8.Well N-,Pe and Number What Regulation or Conservation Order governs well spacing in this pool? N/A . North Fork Unit 42-35 Will planned perforations require a spacing exception? Yes U No I01 b 9.Property Designation(Lease Number): 10.Field/Pool(s): -, 391210/11 .'i L•31/Z--/D/-,11 DL /Z1/W/J/,27.//, No 'o r \/ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TV (ft): Effective Depth MD: Effective Depth TVD: MPSP tili.$ Plugs(MD): Junk(MD): Casing Length Size MD TVD Burst Collapse Structural - - - - - Conductor 120 20" 120 120 - - Surface 2920 9 5/8" 2920 2750 5750 3090 Intermediate - - - - - - Production 9948 7" 994: 9026 7240 5410 Liner - - ' - - - Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Si. Tubing Grade: Tubing MD(ft): 5590'-9541' 4594'-8620' V.2 7/8" 6.5#L80 EUE 9,504' Packers and SSSV Type: .p Packers and SSSV MD(ft)and TVD(ft): SSSV:357'MD 5 Tripoint Hydraulic Set Packer +T PP (5) Packers-5538'MD;5829'MD;7155'MD;8107'MD;8961'MD 12.Attachments: Proposal Summary N Wellbore sche ti I01 13.Well Class after proposed work: Detailed Operations Program W BOP Sketch Exploratory I I Stratigraphic I I Development AXI Service 14.Estimated Date for 15.Well Status after proposed work: }(.;. ^—r s±r Commencing Operations: 1-Apr 6 OIL El WIND WDSPL Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG B GSTOR B ❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ,_;.:.:Z-- 17.I hereby certify that the foregoing is true and the pro •dure approved herein A /4 will not be deviated from without prior written approval.. Contact Stephen Ratcliff 907-433-3808 ���;� 9 Email stephen.ratcliff@cookinlet.net Printed Name ': Title L ��' i 4 QL 1 V Signature 4 Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commissi so that a representative may witness Sundry Number: Plug Integrity ❑ OP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Post Initial Injection MIT Req'd? Yes ❑ No m, Spacing Exception Required? Yes U No Subsequent Form Required: %C;,_ Lit iv 1, �NED y 6 2016 APPROVED BY FEBD J Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 1 ORIGINAL FRBDMS LL- FEB 0 4 2016 ,XP /z.7 • • Cook Inlet Energy_ RECEIVED JAN 2 6 2016 January 26, 2016 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application to plug/abandon for sidetrack Cook Inlet Energy, LLC: North Fork Unit 42-35 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby applies for a sundry to plug back the North Fork Unit 42-35 well, located on ADL 391210/11 and land use permit: LOCI 10-004, in the North Fork Unit. A new PTD will be submitted for the upcoming sidetrack of the well. Please find attached for review of the Commission the 10-403 Form, Abandonment Procedures,Well Information, and Proposed Well Schematics,as required by 20 ACC 25.005. Abandonment work will commence approximately April 1, 2016. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling&Completions Engineer Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 111 • Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 42-35 Requirements of 20 AAC 25.005(f) Well Summary Current Status: Development Well, but not performing up to its believed potential Scope of Work: • Plug and abandon current wellbore • Prepare for sidetrack General Well Information: Reservoir Pressure/TVD: 3,917 psi @ 9,968'MD/9,046'TVD MASP: 3,012 psi Wellhead Type/Pressure Rating: 11" Multi-bowl 5K GE Wellhead Well Type: Gas Producer Estimated Start Date: April 1, 2016 �r Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Stephen Ratcliff (907) 433-3808 Stephen.Ratcliff@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 3 • NFU 42-35 Proposed Abandonment Schematilib Version: 1.0 _ Cook Inlet Energy 12/16/2015 20" 120#L-80 120'MD 20"Conductor iL 19" Welded 120'ND •` ,x et J• 9 5/8" 40#L-80 2,920'MD 12 1/4"Hole ID 8.835" BTC 2,750'TVD .......... l'' ,. Whipstock Top @ 5414' i 'Y ',Jet-illik .M .+ d , t) 7"Bridge Plug 5,430'MD J ` f S Tubing Cut 5,450'MD Top of Cement 5,470'MD ;d S" . `yj ,I """�""""" Sliding Sleeve @ 5489'MD-2.31"ID Y 1 4w*–• Tripoint Hydraulic Set Packer @ 5538' ,._- Sliding Sleeve @ 5588'MD-2.31"ID Abandoned Perforations I. Zone#1 w. Tripoint Hydraulic Set Packer @ 5829' MD ND ' Sliding Sleeve @ 5877'MD-2.31"ID 5590-5606 4954-4967 Zone 1 aa,, 'IZone#2 5737-5760 5093-5089 Zone 1 =le,. c', a 5974-6000 5269-5291 Zone 2lesuramoommompoR Tripoint Hydraulic Set Packer @ 7158' 6467-6488 5676-5693 Zone 2 i f ;? F' Sliding Sleeve @ 7206'MD-2.31"ID 7200-7220 6317-6336 Zone 3 - � ' Zone#3 8160-8178 7240-7258 Zone 4 fits Me 8898-8914 7977-7993 Zone 4 "1 41111=111mmullmollo" Tnpoint Hydraulic Set Packer @ 8107' 9502-9518 8581-8597 Zone 5 fISliding Sleeve @ 8155'MD-2.31"ID 9527-9541 8606-8620 Zone 5 — ;�I Q Tubing punch 8910'-8920'MD Zone#4 Tripoint Hydraulic Set Packer @ 8961' II I X Nipple @ 9004'MD-2.313"ID j4:, ii,y 1,1 XN Nipple @ 9037'MD-2.205"ID H ,. )L. RA marker @ 9394'MD Zone#5 3s 3mic Tubing 2 7/8" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'TVD I j Est.TOF @ 9,806'MD 8 3/4"Hole PBTD @ 9,858'MD 8,936'ND TD at 9,968'MD/9,046'ND 7" 26# L-80 9,948'MD ID-6.276" GeoCon 9,026'TVD • • Cook Inlet Energy_ 2. Location Summary Requirements of 20 AAC 25.005(c)(2) • General Location Kenai Peninsula Borough,Alaska • Ground Elevation 657.8' above MSL • KB Elevation 678.5' above Ground Elevation • RKB 20.7' above GL X-Coordinate Y Coordinate FNL/FSL Sec'/T/ R MMINMEW1166 4.1116. Surface Location 199958.04 • 2121128.25 • 5� 88'FSL . 4....L'EL/FWL 1453'FEL • Sec 26 T4S R14W S.M Bottom Hole Location 200686.45 2117976.74 2502'FNL 582'FEL Sec 35 T4S R14W S.M See Attachment 1: As-Staked Site Survey 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) Operations will not include utilizing a drilling rig. Work performed will be through the production tree and a lubricator when applicable. See Attachment 2: Wellhead/Tree Schematic 4. Drilling Hazard Analysis Requirements of 20 AAC 25.005(c)(4) Maximum Down Hole Pressure: Normal Pressure Expected Reservoir Pressure: = (Formation pressure gradient)*(TVD) = (0.433 psi/ft)*(9,046') = 3,917 psi Maximum Anticipated Surface Pressure: = (Max Pore Pressure - (GasGRD X TVD) = (3,917 psi) - (0.10 psi/ft X 9,046') = 3,012 psi 5. Formation Integrity Test Procedure Requirements of 20 AAC 25.005(c)(5) • Not applicable for this portion of the project 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) 4 . • _ Cook Inlet Energy_ Cementing Summary: Utilizing the down squeeze method, CIE will ensure sufficient volumes of cement for covering from 100' below the bottom perforation to the packer for each of the four intervals. For the exceptions where the 100' mark is limited by another production packer the cement interval will go from packer to packer. See Attachment 3: Cement Program 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Not Applicable 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) Not Applicable 9. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) Only applicable for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f) 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) Only applicable for an exploratory or stratigraphic test well, a seismic refraction, or reflection analysis as required by 20 AAC 25.061(a) 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) Only applicable for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of conditions as required by 20 AAC 25.061(b) 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) Evidence of Bonding is on file for Cook Inlet Energy with the Commission 5 • _ Cook Inlet Energy_ 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) Abandonment Procedure- NFU 42-35 1. Note -Abandonment Work Performed will be with out a Drilling Rig. a. Plan to Utilize Pollard Wireline for Shifting Sleeves b. Plan to Use SLB Pressure Pumping Unit for Cement Operations 2. AOGCC must be notified 48 hours in Advance of Plugging the Perforations 3. Rig Up Pollard Slick Line Unit for Opening&Closing Sleeves 4. Pressure Test Lubricator to 2,500 psi 5. RIH with Shifting Tool a. Plan to Close all Sleeves with the Exception of Zone 4 • b. Confirm that Zone 4 Sliding Sleeve is Open for Abandonment 6. Rig Up and Test Cementing Head and Lines, per SLB Procedure 7. Establish Injection Rate into Zone 4 Perforations a. If Injection is Established then Prep to Pump Cement 8. Mix and Pump 31 bbls of 15.8 ppg Class G Cement (8,961'-8,107') • 9. Bullhead Down Tubing to Zone 4 using Down Squeeze Method • a. AOGCC Requires Cement from 100' Below Bottom Perfs to Packer b. Chase with Wiper Plug 10. R/U Slickline &Prep to Open Zone 3 11. RIH with Shifting Tool and Open Sliding Sleeve in Zone 3 12. Rig Up&Prep for Cementing 13. Establish Injection Rate into Zone 3 Perforations 14. If Injection is Established then Prep to Pump Cement 15. Mix and Pump 34 bbls of 15.8 ppg Class G Cement (8,107'-7,158') 16. Bullhead Down Tubing to Zone 3 using Down Squeeze Method a. Chase with Wiper Plug 17. R/U Slickline&Prep to Open Zone 2 18. RIH with Shifting Tool and Open Sliding Sleeve in Zone 2 19. Rig Up & Prep for Cementing 20. Establish Injection Rate into Zone 2 Perforations 21. If Injection is Established then Prep to Pump Cement 22. Mix and pump 28 bbls of 15.8 ppg Class G Cement (6,588'-5,829') • 23. Bullhead Down Tubing to Zone 2 using Down Squeeze Method a. Chase with Wiper Plug 24. R/U Slickline & Prep to Open Zone 1 25. RIH with Shifting Tool and Open Sliding Sleeve in Zone 1 26. Rig Up&Prep for Cementing 27. Establish Injection Rate into Zone 1 Perforations 28. Mix and Pump 10.5 bbls of 15.8 ppg Class G Cement (5,829'-5,538') 29. Bullhead Down Tubing to Zone 1 using Down Squeeze Method a. Chase with Wiper Plug 30. R/U Slickline&Prep to Open Sleeve above Zone 1 31. RIH with Shifting Tool and Open Sliding Sleeve above Zone 1 32. Rig Up&Prep for Cementing 6 • i i _ Cook Inlet Energy_ 33. Mix and Pump 2.5 bbls of 15.8 ppg Class G Cement (5,538'-5,470') a. Set Cement on Top of Zone 1 Packer b. Chase with a Wiper Plug F363 . Rig Down Cements &Equipment 35. R/D Slick Line Unit . R/U E-Line Unit&Prep for Tubing Cut a. Utilize Gamma/CCL to Confirm Cut Location 37. RIH with Severing Tool to 5,460' ' poll"--38. Correlate to Depth and Confirm with CIE Engineer prior to Firing 39. Fire Severing Tool '� - 40. POH and Confirm Tools Functioned 1,4y 41. R/D E-Line 42. Prepare to Move Rig over Well for Sidetrack Operation fic kL See Attachment 4: Current Wellbore Schematic ••See Attachment 5: Proposed Abandonment Schematic 14. Drilling Waste Storage 301' Requirements of 20 AAC 25.005(c)(14) Not Applicable 15. Geological Formation Tops Requirements of 20 AAC 25.071 FORMATION TOPS Formation MD TVD SSTVD Potential 4900 SD 5,414' 4,803' (-4,124') Gas 5300 SD 5,833' 5,171' (-4,492') Gas 5450 SD 6,033' 5,353' (-4,674') Gas 5600 SD 6,191' 5,501' (-4,822') Gas 6000 SD 6,632' 5,913' (-5,234') Gas 6100 SD 6,729' 6,021' (-5,342') Gas 6700 SD 7,370' 6,652' (-5,973') Gas 6800 SD 7,460' 6,741' (-6,062') Gas 7800 SD 8,611' 7,874' (-7,153') Gas 7950 SD 8,670' 7,933' (-7,233') Gas 8050' SD 8,728' 7,989' (-7,310') Gas Total Depth* 8,891' 8,150' (-7,471') 16. Logging Plan Requirements of 20 AAC 25.071 (a) Not Applicable 7 • • Cook Inlet Energy_ 17. Regulatory Waiver and Special Procedures Requests Not Applicable Attachments 1. As-Staked Site Survey 2. Wellhead/Tree Schematic 3. Cement Program 4. Current Wellbore Schematic 5. Proposed Abandonment Schematic 8 I i b \ — EDGE OF R.O.W. ```V1\\\li 1 I NORTH FORK _ROAD — _ \ _ �� � .•• A�-9 SSI 6 \ -- OO RI • • N 2121143.9950 (��. �1 i 57,� CP 1 E 1340068.0700 N 2121137.2190 ELEV 666.07'_ / * 4g TF-I E 1339704.6100 EDGE OF R O W• __ --__ ELEV 656 A9' ----- / C-ZOP&I2 / i �� /— :40. = QH mu =��I e� 0° STAN A. McLANE : ,� as s 65'3 � _....• /. , JJ, 4 637—S j oho - — •'_ F1PF •.10/3/14 • 50 a X O�� _._ O m �,I I I I OFESS I(>10-;``�` 1 j'� 656 !� • t %X%S.� 1�' Trach 18 6s °� :� 9 GATE e Ix ill! AIM ' WI0 El 34-26 WELL 32-35 WELL 14-25 WELL Ir r- ____ m 23-25 WELL '� x I ^ El= NFU 42-35 WELL ( J _ N:2121128.246 I 5 1EL E:199958.041 LATITUDE: 59°47'46.358" N • J 'i CI El LONGITUDE: 151°3744.913" ... ❑ NAD 27 ASP ZONE 4 �,l HE— W ELEV. 657.8'NAVD88 ao Q Tract 19 CO� I' o North Fork Acres Subd. No. o 0 X — X X 21 X — 0 a o--- -F,-s;-rr-`- .m _ i I I 0 i� �6� ... 665- e''' Ce TOP OF BERMU W __ --/-7:7,7—._____________: b\...._______ ________________' \ J 0) N 2120505.98 Section 26,TO4S,R14W,S.M.,AK. _ - I — E 201396.26 S26 S25 I — S35 S36 --..... r ..„\ i NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N OR TH BASE STATIONS"KENS,"TSEA"AND"KOD5"OBSERVED DEC.13,2007 ON NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' 'IIIIIIIII�W 41111011w 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. 0 SCALEA200 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT I i I I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 IFEET AND NOT THE PROTRACTED SECTION CORNER VALUES. J PROJECT REVISION: - NORTH FORK 42-35 WELL DATE: 10/2/14 _^ �?COOk Inlet ETlei"�7 AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BGB t�iy NAD27 FOR INFORMATIONAL PURPOSES SCALE: 1"=100' ONLY PROJECT NO. 143135 AENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. CanSuLting Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET VOICE:(907)283-4218 FAX:(907)2833265 SW 1/4 SE 1/4 EMAIL:SAMCLANE©MCLANECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA 1 OF 1 • • yo \ . . - EDGE OF R.O.W. ``�����\ NORTH FORK ROAD _ OFA hi i �- — _ -- - �,^`' CP-2 �? 1�•.S`�°/i ooRI • • N2121143.9950 i C9,- ..-57 , CP-1 E 1340068.0700 sw* '49 TH /\ * Ot • N 2121137.2190 ELEV 666:07 /` 0 E 1339704.6100 EDGE OF R.O.W•— 1 �_ ELEV 656.6g, . . 00 /"����� �Lv///L!L / q _ 0H –__.,____ .. 47411. I STAN A. McLANE ,3 ao • O �, 4 • �, F��O •.10/3/14 .o' X �I I' ot-% m ,,I11I1\\\\S ``� /I o a 0 w �� Tract 18 `s.9 GATE t0It n V) x0 Q MI •n• n61- 34-26 WELL 32-35 WELL 14-25 WELL 23-22 WELLoN di PWXxNFU 42-35 WELL \ et � 1453' FEL N:2120883.406 C° 1 E:1339983.463 Ell LATITUDE: 59°47'44.156" N ' ri iii 0 1 f"1 LONGITUDE: 151°37'52.681"W 1 NAD83ASPZONE4 ` 'HE X ELEV. 657.8' NAVD88 co u) I v Tract 19 Io o O North Fork Acres Sub4. No. 2 b c) la 0 islc _s__ X x 2 � X X — w MOM I4 0 MU C..7----......\:° `\ �� Ct U \ 'O TOP OF BERM UIll tai 1 cril I L 1 • I N 2120261.15 Section 26,TO4S,R14W,S.M.,AK. E 1341421.67 — ' — I — S26 S25 S35 S36 (/2", I NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N OR TH BASE STATIONS"KEN5",'TSEA"AND"KOD5"OBSERVED DEC.13,2007 ON _ NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' "TTII1V911VF7 IIII III 0111112)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. SCALE 200 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0 100 SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 I IFEET AND NOT THE PROTRACTED SECTION CORNER VALUES. \ / PROJECT REVISION: - k NORTH FORK 42-35 WELL DATE: 10/3/14 Cook Inlet Energy AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BGB NAD83 SCALE: 1,100' PROJECT NO. 143135 ENGINEERING/MAPPING I SURVEYING/TESTING BOOK NO. - CansuL4ing Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET MSC. VOICE(907)283-4218 FAX:(907)283-3265 SW 1/4 SE 1/4 EMAIL:SAMCLANE®MCLANECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA OF 1 0 ® GE Oil & Gas I 47.7' O Ai 1. 30.2' or iii 2-9/16'5M IIIIII 1 2-9/16"5M ' f ' 2-9/18'SM - - 1 . 2-9/16'5M % ) ilk., 1...t. 45.8" 2-9/16"5M 111111 127.2" 1 – ®�� 11 t 11"5M rip i" f 7 = --"u r J1✓ i Ll- 28.5"to c 19.0" —I 0 O 11'56" t .. 1e`; `agai— l. YTT- [ i ,28.5'to e 2-1/16"5M AL1 rU_. ■ 0 oil eel If • o I .o«u, 31.7 e __ p I...:-1 ■ ! `— 2-1/18'5M diI , , f— 26'O.D.Base Plate - 9-5/8"Casing 1'1��r Casing 2-7/6'Tubing 1l_ 1/4'Control Line ALL DIMENSIONS ARE APPROXIMATE This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, COOK INLET ENERGY42-35 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. 9-5/811 x 7" x 2-7/811 5M SH2 Wellhead Assembly, DRAWN - CR , 080CT14 APPRV KN 080CT14 With T-M40-CCL Tubing Hanger and Adapter Flange FOR REFERENCE ONLY DRAWING NO. 1001107-2 • • • Schlumberger Laboratory Cement Test Report NFU 42-35 Abandonment Plan Composition Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fluid 5.107 gal/sk Solid Vol. Fraction 41.183% Porosity 58.817% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number G 94 lb of CEMENT Blend 3.20 SG Fresh water 5.067 gal/sk Base Fluid D046 0.200%BWOC Antifoam CW4M0615A1 D065 0.300%BWOC Dispersant 6108 D167 0.200%BWOC Fluid loss ESD0900677 D177 0.040 gal/sk Retarder 2015061AL Rheology Tem.erature 80 de.F 148 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 84.0 84.0 84.0 63.0 63.0 63.0 200 65.0 63.0 64.0 45.0 46.0 45.5 100 45.0 41.0 43.0 26.0 25.0 25.5 60 36.0 32.0 34.0 20.0 18.0 19.0 30 31.0 25.0 28.0 10.0 16.0 13.0 6 25.0 16.0 20.5 4.0 3.0 3.5 3 18.0 14.0 16.0 2.0 1.0 1.5 10 sec Gel I 18 deg-19.21 Ibf/100ft2 I 2 deg-2.13 Ibf/100ft2 10 min Gel 36 deg-38.42 Ibf/100ft2 9 deg -9.61 Ibf/100ft2 Rheo.computed I Viscosity:62.737 cP Yield Point:21.73 Ibf/100ft2 I Viscosity:55.816 cP Yield Point:7.54 Ibf/100ft2 (-) E. Thickenin. Time Consistency Time c 30 Bc 06:14 hr:mn tz 50 Bc 06:39 hr:mn c. 70 Bc 06:53 hr:mn "U 100 Bc 07:11 hr:mn ct Free Fluid a Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation : None Fluid Loss API Fluid Loss 119 mL 50 mL in 23 min at 148 degF and 1000 psi Note: This is a pilot test. Field blend may differ after testing. Please read field blend report carefully and compare to pilot report and load out. Contact the laboratory with any questions or concerns. Page 1 • Client : Well : Schlvm rgcr Formation: District . Country . Rough Cement PlanNolumes: Cement 100-ft below bottom perf of the zone to previous Set Packer(Packer to packer where 100-ft below bottom perf is greater depth than the next Set Packer) Stage 1, Zone 4: 31 bbls 15.8 ppg Class G Cement(8961'-8107') Stage 2, Zone 3: 34-bbls 15.8ppg Class G Cement(8107'-7158') Stage 3, Zone 2: 28-bbls 15.8ppg Class G Cement (6588'-5829') Stage 4, Zone 1: 10.5-bbls 15.8ppg Class G Cement(5829'-5538') Stage 5, Top of Set Packer 1: 2.5-bbls 15.8ppg Class G Cement(5538'-5470') Page 2 • • NFU 42-35 Final Completion Schematic Version: FINAL Cook Inlet Energy_ March 30, 2015 20" 120#L-80 120'MD 20"Conductor 19" Welded 120'TVD ' -- TRSSSV @+/-357'MD-2.313"ID i. Y - 2 7/8"Chemical Injection , il 1 Mandrel @+/-2521'MD-2.313"ID 9 5/8" 40#L-80 _ 2,920'MD 12 1/4"Hole „ ID 8.835" BTC 2,750'TVD • All Sleeves Open Down • Zones 1 through 4 Open as of Date 3-30-2015 • Sliding Sleeve @ 5489'MD-2.31"ID Perforations Tripoint Hydraulic Set Packer @ 5538' 1 ISliding Sleeve @ 5588'MD-2.31"ID MD TVD =I 1 ..„........111111111111111111111111111111r. Zone#1 5590-5606 4954-4967 Zone 1 5737-5760 5093-5089 Zone 1 l' Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 1_I per„ Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 a 31:=C Zone#2 7200-7220 6317-6336 Zone 3 a 11 a 8160-8178 7240-7258 Zone 4 Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 t i ,,,N.0., Sliding Sleeve @ 7206'MD-2.31"ID 9502-9518 8581-8597 Zone 5 - f I a Zone#3 9527-9541 8606-8620 Zone 5e. >; ...w .Tripoint Hydraulic Set Packer @ 8107' Sliding Sleeve @ 8155'MD-2.31"ID ' :lam ,,. Tubing punch 8910'-8920'MD Future Perfs Thru Tbg . Zone#4 MD TVD 7777 9296-9300 8375-8379 -- - Tripoint Hydraulic Set Packer @ 8961' 9808-9816 8886-8894 1 -. X Nipple @ 9004'MD-2.313"ID 9894-9896 8972-8974 ,. .!la..,.�.._,,.,.:._..... XN Nipple @ 9037'MD-2.205"ID 11 Plug in XN Nipple RA marker @ 9394'MD Zone#5 ... ri .. Zs a Tubing 2 7/8" _6.5#L80 EUE 9,504'MD_ ID-2.441" BTC 8,583'TVD , Est.TOF @ 9,806'MD 8 3/4"Hole ",.aikPBTD @ 9,858'MD 8,936'TVD .. I TD at 9,968'MD/9,046'TVD 7" 26# L-80 9,948'MD ID-6.276" GeoCon 9,026'TVD • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsib 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist/ / in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist/SO work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, February 02,2016 10:08 AM To: Stephen Ratcliff Cc: Conrad Perry;Carlisle, Samantha J (DOA) Subject: RE: NFU 42-35 (PTD 214-170) Stephen, AOGCC will withdraw sundry 316-054 as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Stephen Ratcliff[mailto:Stephen.Ratcliff@cookinlet.net] � Sent: Tuesday, February 02, 2016 10:01 AM To: Schwartz, Guy L(DOA) Cc: Conrad Perry Subject: Re: NFU 42-35 (PTD 214-170) Guy, Please cancel sundry 316-054 (original request). We have modified the procedure and would like to use the most recent submittal. Let me know if this is acceptable or if you have any further questions. Thanks! Stephen Ratcliff Sent from my iPhone On Feb 2, 2016, at 9:23 AM, Schwartz, Guy L(DOA)<guy.schwartz(«@alaska.gov>wrote: Also ..send email requesting to cancel sundry 316-054. Original plan. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 w w 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 Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Tuesday, February 02, 2016 9:21 AM To: 'Stephen Ratcliff Subject: NFU 42-35 (PTD 214-170) Please send me the rig P&A steps up to drilling off the whipstock. Email is fine..steps after number 22. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793- 1226) or(Guy.schwartz@alaska.gov). 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c! `J- - 170 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: p4o r Items: ❑ Maps: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other:BY: Maria Date: T/51 lc 1st liA P Project Proofing BY: alb Date: g 5 5' /s/ IA • Scanning Preparation Li— x 30 = )),C1 + c'7 = TOTAL PAGES 1 II-7 (Count does not include cover sheet) BY: (MariaDate: CtilEl is- /s/ V yil Production Scanning Stage 1 Page Count from Scanned File: I 1 Q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: AC> Date: U S I S /s/ vvi p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: ill, NO TOTAL PAGES:54 Digital version appended by: Meredith Michal Dateg(to,( 5 /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: ao 7 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked • o I • • • o o O N o 1 \ vtri U ,,,- (0 0 ZI Oci,I > • in' • c_ c_ r. w C o Z to o) O)co 0I N N N iiis= LLI • T M U NI E co M -cr �I M in M • '`� } to _co WI LI N LL LL LL N N N V• V [•i to 0 0 �I Z Z Z �I �I �I 3 3 O > N 6 i NLL N N ai LL LL LL LLLL LLLL E z E E Z Z Z zla zla Z E E C C C I c C coN c I I I t` • n • CT. N N N y N O N N N@ N co 0 co 0 M M M m H CT i- Q o it U LL o W it to LL Z LL m 7 CO - R R �l�I �l wI U) 'V N I- ) I N Z N Z N< N w_ W . w_ 0 W LL w LL Q N O U) I U)m �W N �Q �� �6 N U U - U > U2 U2 C.) c 0 m� m m I m m� m C I p _o c coLL co U1 co @o @NI @Z ai _ ui ai Z aid aim 'E w0 .4. 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LL U } } \ -' N c O • �iNG/ T N 5 E v E vi 1 .c % 'g in CD Z C zo Eoc3 rn c k w Z N X (c d O I L L • O r` 0 a mNs Q ch 00) 0)) m > W N N a O O 3.—Lo CO 13 co O U U J 1 `r U 4 U U11 N• N N a) N N X 0 1 1 LL X it I.L H LL ll X C 1 Q Q T I y lU_y U Ute,• U EU d II Z 1 ' V C X E •C E % 1 ii J co o O L6 O O• O 2g ti ti P 11 t, I .6 @ ci Ce 0 y W N W W V) W W S. m N CC 0To co aO `U6 12 CL W NNN N N E w E to E m_ co W w 1 v a v v v (A Z aS N N N N N a m Z r- ,n iL E W 0 U) m N m rn a V 0 d M � J co Z d m c co To- Q +, CL O O w to J a C d 3 'O E = 1 CL o �, C 2 0 0 HH in 2o a) O C-1 a E V Nel" o U m o ti >- I E QJ I c I E11 so M1 co O 1 U 11 0. NO. (o f0 S.), E r H co �O co • m m Y c•-) = m E N 5 0 I' E _ w LL a) 0 N C (n d 0 y� U -c 0 co I lb 0 ce ▪ o = a7 1 O @ N I— Z .O O C d 1 Q C a - fa Z E O Uo .c > l iv 0 0 M 0 w Z 3 0 0 0 0 0 0 1 C Q N N 1 O a m m m m C (� ch )0 is. ~ 0 0 0 0 0 c > f6 N Ce CO CD W E a o m ;i7 N CO CO N N m y W O O N m N O. N m 1I O = N co O ,> a a) F. a0 co D) 0 O FO-• `- III 0 LLI 0 a) c I ami O rn yr Z Q o c 2 Q 2 0 c if; c C.) '7' 0 U U U U o 0 - I J .� a� .a aa, '6 U E 0 O Z. v o a o CD E ° O 0 0 00 00 ) LL o 2 aa' 0 o 5 m E o a , W W W w w 3 3 0 a C7 0 0 c G 0 0 RECEIVED APR 2 8 2015 Cook Inlet Energy, LLC AOGCC 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 2 1 4 1 7 0 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA LOGGED 5 iZ �2ots M.K.BENDER 2 5 7 3 8 DATA TRANSMITTAL Date: April 28, 2015 To: Meredith Guhl From: Barb Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Ave, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433-3802 FAX: (907) 334-6735 TRANSMITTAL DESCRIPTION Well data for North Fork Unit (NFU) 42-35, API#50-231-20046-00-00 Item # Qty Description 1 1 Paper Copy- Lat/Long coordinates for Surface and Bottom Hole Locations - 1 page 2 1 Paper Copy- List of Formations and other Geologic Markers Encountered - 1 page 3 1 Paper Copy- List of Oil and Gas Shows - 1 page 4 1 Paper Copy- List of Abnormal Pressure Zones- 1 page 5 1 Paper Copy- List of Logs Run - 1 page 6 1 CD - Digital data for directional survey(pdf and excel); CBL Logs in las and pdf; Halliburton Triple Combo Logs in las and pdf; Baker Triple Combo logs in las and pdf; Borehole Volume Log in pdf; Deterministic Volumetrics Log in las and pdf; Perf Record Log in pdf; Sidewall Core Log in pdf and las; total 27 files 1 Printout of above listed CD - 3 pages 7 1 Paper Copy- Directional Survey NFU 42-35-3 pages 8 1 Paper Copy- NFU 42-35 CBL Logs 9 1 Paper Copy- Baker Triple Combo Log 1", 2", 5", MD &TVD 10 1 Paper Copy- NFU 42-35 Borehole Volume plot 2" MD 11 1 Paper Copy- NFU 42-35 Deterministic Volumetrics log 2"& 5" MD 12 1 Paper Copy-CanRig Well Report binder including mudlogs with data CD 15 1 Paper Copy- Halliburton Triple Combo Log 5" MD 16 1 Paper Copy- Halliburton Sidewall Percussion Cores 17 1 Paper Copy-Schlumberger Perf Record Log To submit emailed signed transmittals send to: barb.kruk@cookinlet.net Please sign below to acknowledge receipt. Received By: Date: Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC NFU 42-35/NFU 42-35 Date Modified:4/28/2015 bk 25738 214170 NFU #42-35, API# 50-231-20046-00 RECEIVED Location APR 2 8 2015 AOGCC Depth MD Depth TVD Type of Coordinate Coordinate Surface 0' 0' Latitude,decimal minutes seconds 59 47' 46.358"N Longitude, decimal minutes seconds 151 37' 44.913"W Coordinate System Datum: NAD27(NADCON); Ellipsoid: Clarke 1866 TD 9,968' 9,046' Latitude,decimal minutes seconds 59 47' 15.505"N Longitude,decimal minutes seconds 151 37' 29.173"W Coordinate System Datum: NAD27(NADCON); Ellipsoid: Clarke 1866 15738 114170 4/24/2015 NFU 42-35, API# 50-231-20046-00 RECEIVED Geologic Markers APR 282015 AOGCC Name Measured Depth TVD Beluga 1,390' 1,326' Tyonek- Upper 5,304' 4,720' Tyonek- Middle 8,521' 7,600' 25 738 t 7 41 70 4/24/2015 NFU#42-35,API#50-231-20046-00 RECEIVED Oil and Gas Shows APR 2 8 2015 AOGCC Name Measured Depth TVD Fluid Show#1 5,975'-6,002' 5,270'-5,292' Gas Show#2 6,390'-6,403' 5,612'-5,623' Gas Show#3 6,455'-6,499' 5,666'-5,702' Gas Show#4 7,532'-7,556' 6,628'-6,650' Gas Show#5 8,165'-8,200' 7,245'-7,280' Gas 25738 z14170 4/24/2015 NFU#42-35,API#50-231-20046-00 RECEIVED APR 282015 Abnormal Pressure Zones AOGCC Name Measured Depth TVD Fluid NONE NONE NONE Z5738 [ 14170 E .2• N O ON M ^O O O to to TrtD to V .w Ol O Ol 01 00 Ol Ol 'C Ol O Ol O Ol O Ol 0 m6 6 6 6 o o 00 m 6 O1 Ol' Ol' Ol' Ol Ol' 01 CI N �, ^ o0000 = oiootooiobZo N N Cl 00 00 C Ln O Cl N Ol N Cl N Cl N uj CV � N N Cr; N N � N N N N N N N N nMONF 0 W fill C.') 0f0 . * L• fl .. a Q V N N N .' iJ'f i1'f iJ'f N N N N N N N Il+ � N cu C o eM�, eM�,• ,--1 .-i ,-l ,--I ,--1 r. ,--I •--I i--I .-1 ,--I e-i e-1 .--1 00 0 T >" T O (0 (0 (0 O z o: °C iO mm m E E E o EE E O cum (0 N 0 0 w m"I 5= 52. A M a_ 0 ;AM rA O (^ C c c N in '47)• c c 0 ›.. c - - Y Y Y 0 00 Q 0 .N co c0 CO CO V 0 0 2 0 2 {J1 J JO E N 0A 0p n H O lJ U_ (0 a U, O O N O O 2 . (.9 O 0J u0 to J J EE WW It a s do a a U o 0 0 - o o c c D c c ° E .§ c c o o E E o o 0 0 0 o o L r+ 0 0 ++ .4= LI. Z z = E > 1 = o CO CO 0 E E o o cc `c =U CO c0 te c z oc o J J 0 0z � zLLLL 77 0 0 5te — T0- Oi i . . i i i i a+ 01 a. VIH N H N �01 C L v co 0 0 0 0 0 0 0 0 mmttommtomm NN0JEN 42 "0 "0 "0 "0 "10 "0D10 L l LIlL(1 V1 Ln LIl U U 1 L(1 L(1 ,--1 ,--1 .-1 .-1 ,--1 ,--1 .-1 .-i .--1 ,--1 \ \ \ \ \ \ \ \ \ \ ^ ^ ^ ^ ^ ^ ^ ^_ eie- LLnL1L1 (1Ln -1 ,i ,-1 ,4 )-1e-1e-1 \ \ e-1 ,-1 ,-I ,-1 .-I ei \ \ \ \ \ \ \ \ .-1 `1 \ eei 11 r-1 r-1 r-1 r-1 r-1QO 0 r-1OO �\ 1 LnL( NNMNN ` ulL(1lP1fL1L(1LflL(1 11111 00 i--1 ,--1 \ \ \ \ \ \ )--1 i--1 N--1 ,-1 )--I )--1 )--1 )--1 o i i i\ \ eeeI-I e I N \ ".... \ \ \ \ \ \ 1 e-1 e-1 ei ei e-I e-I e 1 e-I e-1 ei ei ei ei ei e-1ei ei ei ei ei e\i e\-1 e\-1 e\-1 e\-1 e\-1 e\-1 e\-I e\i e\i i 0)v L L C C � C C `0 C 0 0 m 0 0 m w = = 7 E 3 7 E Do oD 00 00 00 00 00 0o 4-'_ _ _y• N v L L = L L 7 E 2 E E 2 2 E L L C C C CC C C C 0 m m 1 2 (n 1 1 (n U U 0 U U U U U 2 5 °i 6 3 z 1 4 1 7 0 CEIVED APR 282015 EMI KER Cook Inlet Energy_ ADVANTAGE Final Survey Listing /� �±�^+ HUGHES AOGCC INTEQ Operator Cook Inlet Energy Fields North Fork API No 231200460000 Well North Fork Unit#42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Well Origin Latitude 59.7962 deg Longitude -151.6291 deg North Reference True Drill Depth Zero Rig Floor Vertical Datum is Ground Level Vertical Datum to DDZ 20.80 ft Vertical Section North 0.00 ft Vertical Section East 0.00 ft Vertical Section Azimuth 165.8700 deg Vertical Section Depth 0.00 ft Grid Convergence 0.0000 deg Magnetic Declination 16.4400 deg Total Correction 16.4400 deg TVD Calculation Method Minimum Curvature D-Raw Calculation None Local Magnetic Field 55056 nT Local Magnetic Dip Angle 72.8580 deg Local Gravity Field 9.819 m/s^2 Tie In MDfI Incl 1 deg deg North I East ft TVD I VSfTemperature CRSft EN IDLS deg/100ftlBuild deg/100ftlTurn deg/100ft T 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20.80 0.00 0.00 0.00 0.00 20.80 0.00 20.80 0.00 0.00 0.00 175.00 0.59 0.89 0.79 0.01 175.00 -0.77 68.9 154.20 0.38 0.38 0.58 233.00 0.81 352.61 1.50 -0.04 232.99 -1.46 74.3 58.00 0.42 0.38 -14.28 295.00 0.99 354.40 2.47 -0.14 294.99 -2.43 85.1 62.00 0.29 0.29 2.89 358.00 0.94 345.84 3.51 -0.32 357.98 -3.48 90.5 63.00 0.24 -0.08 -13.59 419.00 1.00 356.47 4.53 -0.48 418.97 -4.51 93.2 61.00 0.31 0.10 17.43 484.00 0.99 354.45 5.65 -0.57 483.96 -5.62 96.0 65.00 0.06 -0.02 -3.11 545.09, 1.06 351.27 6.73 -0.70 544.95 -6.70 98.7 61.00 0.15 0.11 -5.21 608.00 0.56 6.32 7.62 -0.76 607.94 -7.57 104.1 63.00 0.86 -0.79 23.89 6 1i. 0.43 60.23 8.04 -0.52 670.94 -7.92 63.00 0.74 -0.21 85.57 733.00 0.39 50.43 8.29 -0.16 732.94 -8.08 106.8 62.00 0.13 -0.06 -15.81 798.00 0.45 35.43 8.64 0.16 797.94 -8.34 106.8 65.00 0.19 0.09 -23.08 861.00 0.31 51.60 8.94 0.44 860.93 -8.57 109.5 63.00 0.28 -0.22 25.67 923.00 0.10 118.94 9.02 0.62 922.93 -8.60 112.2 62.00 0.46 -0.34 108.61 988.00 1.05 159.48 8.44 0.88 987.93 -7.97 112.2 65.00 1.50 1.46 62.37 1050.00 2.05 166.76 6.83 1.33 1049.91 -6.29 112.2 62.00 1.64 1.61 11.74 1114.00 3.20 164.33 3.99 2.07 1113.84 -3.36 112.2 64.00 1.80 1.80 -3.80 1177.00 4.32" 161.26 0.05 3.31 1176.70 0.76 117.6 63.00 1.81 1.78 -4.87 1241.00 5.22 162.10 -5.00 4.98 1240.48 6.07 125.7 64.00 1.41 1.41 1.31 1304.00 6.45 161.99 -11.09 6.96 1303.15 12.46 117.6 63.00 1.95 1.95 -0.17 1367.00 7.81 166.36 -18.62 9.06 1365.66 20.27 120.3 63.00 2.32 2.16 6.94 1429.00 9.14 169.33 -27.55 10.97 1426.99 29.40 120.3 62.00 2.26 2.15 4.79 1492.00 10.27 166.69 -37.94 13.18 1489.08 40.01 120.3 63.00 1.93 1.79 -4.19 1553.00 11.13 162.63 d0,43,5 16,19 154942 51.32 98.7 61.00 1.87 1.41 -6.66 1617.00 12.45 162.60 -6133 20.10 1611.67 64.38 104.1 64.00 2.06 2.06 -0.05 1679.00 13.85 163.13 - 16,10178.46 106.8 62.00 2.27 2.26 0.85 1742.00 14.86 164.55 -89.81 28.59 1733.08 94.07 109.5 63.00 1.70 1.60 2.25 1805.00 16.16 166.82 -106.13 32.75 1793.78 110.91 117.6 63.00 2.28 2.06 3.60 1867.00 17.35 166.93 -123.54 36.80 1853.15 128.79 117.6 62.00 1.92 1.92 0.18 1930.00 18.55 166.51 -142.43 41.27 ;13.08 148.20 117.6 63.00 1.92 1.90 -0.67 1993.00 19.78 165.19 -162.49 46.33 1972.59 168.88 120.3 63.00 2.07 1.95 -2.10 2056.00 20.92 166,02 -183.71 51,22, 1.66 190.79 120.3 63.00 1.87 1.81 1.32 2121.00 22.01 168.31 -206.90 57.04 2092.15 214.56 77.0 65.00 2.11 1.68 3.52 2184.00 23.05 167 a -230.51 .,_a`-6 .34 238.68 120.3 63.00 1.67 1.65 -0.73 2248.00 24.41 167.09 -255.65 67.62 2208.93 264.43 120.3 64.00 2.18 2.13 -1.19 2311.00 25.77 167.20 -281.70 73.56 2265.98 291.13 120.3 63.00 2.16 2.16 0.17 2373.00 27.05 168.17 -308.64 79.44 2321.51 318.70 120.3 62.00 2.18 2.06 1.56 2437.00 28.45 167.76 -337.78 85.66 2378.15 348.47 120.3 64.00 2.21 2.19 -0.64 2500.00 29.95 167.85 -367.82 92.15 2433.14 379.19 120.3 63.00 2.38 2.38 0.14 2562.00 30.50 168.94 -398.40 98.42 2486.71 410.37 106.8 62.00 1.25 0.89 1.76 2626.00 31.53 168.86 -430.76 104.77 2541.56 443.30 109.5 64.00 1.61 1.61 -0.13 2690.00 32.54 167.08 -463.95 111.86 2595.82 477.22 112.2 64.00 2.16 1.58 -2.78 2754.00 33.35 167.21 -497.89 119.60 2649.52 512.02 114.9 64.00 1.27 1.27 0.20 2816.00 34.52 166.24 -531.57 127.55 2700.96 546.62 117.6 62.00 2.08 1.89 -1.56 2863.00 35.10 166.70 -557.65 133.83 2739.55 573.45 117.6 47.00 1.35 1.23 0.98 2923.90 34.83 166.04 -591.57 142.05 2789.46 608.35 85.1 60.90 0.76 -0.44 -1.08 2986.54 35.09 166.49 -626.44 150.57 2840.80 644.24 85.1 62.64 0.58 0.42 0.72 3049.22 36.06 166.05 -661.86 159.23 2891.78 680.71 90.5 62.68 1.60 1.55 -0.70 3110.45 36.85 166.08 -697.17 167.99 2941.03 717.09 93.2 61.23 1.29 1.29 0.05 Page 1 2b738, 114170 IEUIVED MI ICER Cook Inlet Energy_ ADVANTAGE Final Survey Listing APR 2 8 ZOL HUGHES Q1cF INTEQ Operator Cook Inlet Energy Fields North Fork API No 231200�600D0 Well North Fork Unit#42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Tie MD In ft I deg l deg Noftrth I East ( TVD I VS ITemdegFture CRS LEN deg/00ftIBuild deg/100ftI Turn deg/100ft 3174.34 37.33 1 166.12 -734.57 177.25 2991.99 755.62 96.0 63.89 0.75 0.75 0.06 3237.20 37.72 165.80 -771.72 186.53 3041.84 793.91 96.0 62.86 0.69 0.62 -0.51 3300.51 37.99 166.64 -809.45 195.79 3091.83 832.75 96.0 63.31 0.92 0.43 1.33 3363.23 38.16 166.86 -847.10 204.65 3141.20 871.43 98.7 62.72 0.35 0.27 0.35 3427.00 38.01 166.08 -885.34 213.85 3191.40 910.76 98.7 63.77 0.79 -0.24 -1.22 3489.29 38.01 165.67 -922.54 223.22 3240.48 949.12 98.7 62.29 0.41 0.00 -0.66 3552.25 37.22 165.16 -959.73 232.89 3290.35 987.55 101.4 62.96 1.35 -1.25 -0.81 3614.92 36.17 165.43 -995.95 242.40 3340.60 1024.99 104.1 62.67 1.70 -1.68 0.43 3679.10 36.34 165.80 -1032.72 251.83 3392.35 1062.95 96.0 64.18 0.43 0.26 0.58 3742.21 35.69 165.06 -1068.63 261.16 3443.40 1100.05 98.7 63.11 1.24 -1.03 -1.17 ilk 3804.91 35.72 164.54 -1103.94 270.75 3494.31 1136.64 101.4 62.70 0.49 0.05 -0.83 3867.35 35.47 164.61 -1138.98 280.42 3545.09 1172.97 101.4 62.44 0.41 -0.40 0.11 3930.72 35.64 164.02 -1174.45 290.38 3596.64 1209.81 104.1 63.37 0.60 0.27 -0.93 3993.67 35.34 163.96 -1209.58 300.46 3647.90 1246.33 106.8 62.95 0.48 -0.48 -0.10 IMPF-4056.65 35.15 164.48 -1244.56 310.35 3699.33 1282.66 - 109.5 62.98 0.56 -0.30 .u.. 0.83 4120.18 34.87 164.39 -1279.67 320.13 3751.37 1319.10 109.5 63.53 0.45 -0.44 -0.14 4184.31 34.76 164.20 -1314.91 330.04 3804.02 1355.70 112.2 64.13 0.24 -0.17 -0.30 4246.32 35.05 164.10 -1349.05 339.73 3854.87 1391.17 112.2 62.01 0.48 0.47 -0.16 4309.96 34.58 163.99 -1383.98 349.72 3907.12 1427.48 109.5 63.64 0.75 -0.74 -0.17 4373.66 34.36 163.82 -1418.62 359.71 3959.64 1463.51 112.2 63.70 0.38 -0.35 -0.27 4437.19 34.66 164.11 -1453.21 369.65 4011.99 1499.49 114.9 63.53 0.54 0.47 0.46 4499.38 34.76 163.99 -1487.26 379.38 4063.11 1534.88 114.9 62.19 0.19 0.16 -0.19 4562.54 34.88 164.40 -1521.96 389.21 4114.96 1570.93 114.9 63.16 0.42 0.19 0.65 4625.30 34.95 165.69 -1556.67 398.47 4166.43 1606.85 117.6 62.76 1.18 0.11 2.06 4688.89 35.31 165.49 -1592.11 407.58 4218.43 1643.44 117.6 63.59 0.59 0.57 -0.31 4755.00 35.57 164.76 -1629.16 417.42 4272.29 1681.77 120.3 66.11 0.75 0.39 -1.10 4816.72 35.84 164.83 -1663.92 426.87 4322.41 1717.78 120.3 61.72 0.44 0.44 0.11 4879.29 36.26 165.10 -1699.48 436.42 4373.00 1754.60120.3 62.57 0.72 0.67 0.43 4942.32 36.08 165.57 -173„5 _ 445,84 4423.88 x1..80 120.3 63/ 0.52 -0.29 0.75 5005.29 35.74 166.46 -1771.30 454.77 4474.88 1828.73 120.3 62.97 0.99 -0.54 1.41 5069.93 35.82 166.42 -1 1 4527.33 7866.52 120.3 6 0.13 0.12 -0.06 5123.77 35.42 166.50 -1838.53 470.97 4571.09 1897.87 109.5 53.84 0.75 -0.74 0.15 5186.24 34.50 167.85 -1873.43 478.92 4622.29 1933.66 112.2 62.47 1.92 -1.47 2.16 5249.90 34.67 166.56 -1908.66 486.92 4674.70 1969.78 112.2 63.66 1.18 0.27 -2.03 ;' 5313.15 34.68 167.02 -1943.69 495.14 4726.72 2005.76 114.9 63.25 0.41 0.02 0.73 5375.68 34.69 167.07 -1978.37 503.12 4778.13 2041.34 114.9 62.53 0.05 0.02 0.08 lir 5438.68, 34.96 166,,34,.-2Q13.38 511.41. 4829.85 2077.31 117.6 63.00 .�. 479 ,„.,.,Q„43 -1.16 5502.06 35.10 166.24 -2048.73 520.02 4881.75 2113.69 117.6 63.38 0.24 0.22 -0.16 55 :99 35.03 1b83.86 528.53 4933.26 2149.84 117.6 62.93 ' F1 0.43 5628.04 35.20 166.41 -2119.12 537.03 4984.83 2186.11 117.6 63.05 0.28 0.27 -0.16 5691.82 34.75 165.56 -2154.59 545.88 5037.09 2222.67 120.3 63.78 1.04 -0.71 -1.33 5755.48 34.59 165.45 -2189.65 554.94 5089.45 2258.88 120.3 63.66 0.27 -0.25 -0.17 5817.90 34.92 164.99 -2224.06 564.02 5140.74 2294.46 120.3 62.42 0.68 0.53 -0.74 5881.97 35.05 165.05 -2259.55 573.52 5193.23 2331.19 123.0 64.07 0.21 0.20 0.09 5945.52 34.38 164.99 -2294.51 582.87 5245.47 2367.38 123.0 63.55 1.06 -1.05 -0.09 6007.91 33.83 165.92 -2328.37 591.66 5297.13 2402.36 123.0 62.39 1.21 -0.88 1.49 6070.90 34.1111 165.65 -2362.49 600.30 5349.37 2437.56 123.0 62.99 0.50 0.44 -0.43 6133.57 34.35 165.97 -2396.66 608.94 5401.18 2472.81 123.0 62.67 0.48 0.38 0.51 6197.07 34.34 165.67 -2431.40 617.72 5453.61 2508.63 125.7 63.50 0.27 -0.02 -0.47 6260.95 34.54 165.89 -2466.42 626.59 5506.29 2544.76 125.7 63.88 0.37 0.31 0.34 lit 6324.87 34.88 165.52 -2501.69 635.58 5558.84 2581.16 125.7 63.92 0.63 0.53 -0.58 6387.24 35.13 165.51 -2536.33 644.53 5609.92 2616.93 128.4 62.37 0.40 0.40 -0.02 �: 645.0 34t,, ...;65.25 -2571.47 653.69 5662.28 2653.25 128.4 63.72 1.23 -1.21 -0.41 6512.78 33.76 165.06 -2604.94 662.56 5713.50 2687.87 128.4 61.82 0.99 -0.97 -0.31 it 65 '`- 64.78 -2639.31 671.83 5766.84 2723.46 125.7 64.13 0.28 -0.14 -0.44 6635.38 33.68 164.43 -2670.56 680.43 5815.50 2755.87 112.2 58.47 0.33 0.02 -0.60 6699.04 31.40 165.38 -2703.62 689.36 5869.16 2790.11 117.6 63.66 3.67 -3.58 1.49 6761.88 30.00 164.70 -2734.61 697.63 5923.19 2822.18 117.6 62.84 2.30 -2.23 -1.08 6825.45 29.02 164.44 -2764.80 705.96 5978.52 2853.49 120.3 63.57 1.55 -1.54 -0.41 6888.42 27.36 165.67 -2793.53 713.64 6034.02 2883.23 120.3 62.97 2.79 -2.64 1.95 Page 2 RECEIVED APR 28Z015e- Cook Inlet Energy ADVANTAGE Final Survey Listing ,, HUGHES ICC INTEQ Operator Cook Inlet Energy Fields North Fork API No 231200460000 Well North Fork Unit#42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Tie In ft0 I Incl deg deg North I East I TVD I VS 'Temperature CRS EN IDLS deg/OOftlBuild deg/100ftlTurn deg/100ft 6951.71 25.95 l 166.56 -2821.09 720.46 6090.58 2911.62 123.0 63.29 2.32 -2.23 1.41 7013.56 24.99 166.11 -2846.94 726.74 6146.42 2938.22 123.0 61.85 1.58 -1.55 -0.73 7077.22 23.69 166.55 -2872.43 732.95 6204.42 2964.45 123.0 63.66 2.06 -2.04 0.69 7140.17 22.93 167.21 -2896.69 738.60 6262.23 2989.36 125.7 62.95 1.28 -1.21 1.05 7203.86 22.57 166.75 -2920.69 744.15 6320.96 3013.98 125.7 63.69 0.63 -0.57 -0.72 7267.82 21.90 167.64 -2944.29 749.52 6380.17 3038.18 125.7 63.96 1.17 -1.05 1.39 7330.64 21.04 168.52 -2966.78 754.27 6438.62 3061.15 120.3 62.82 1.46 -1.37 1.40 7393.50 19.97 167.04 -2988.30 758.92 6497.51 3083.16 123.0 62.86 1.89 -1.70 -2.35 7455.72 18.95 166.46 -3008.48 763.67 6556.17 3103.88 123.0 62.22 1.67 -1.64 -0.93 7520.52 17.95 168.25 -3028.48 768.17 6617.64 3124.38 123.0 64.80 1.77 -1.54 2.76 7582.48 17.13 168.91 -3046.79 771.87 6676.72 3143.04 123.0 61.96 1.36 -1.32 1.07 7645.76 16.73 169.58 -3064.89 775.31 6737.26 3161.43 125.7 63.28 0.70 -0.63 1.06 n 7708.23 15.69 168.64 -3082.02 778.60 6797.24 x,,3,178.84 __au 62.47 1.72 -1.66 -1.50 7771.44_ 14.80 168.21 -3098.30 781.93 6858.23 3195.44 125.7 63.21 1.42 -1.41 -0.68 x$35.51 13.26 168.63 -3113.51 785.05 6920.38 3210.96 T8.$ 64.07 2.41 -2.40 0.66 7899.52 11.67 168.94 -3127.06 787.74 6982.88 3224.76 128.4 64.01 2.49 -2.48 0.48 7963.19 10.39 169.48 -3139.03 790.03 7045.38 3236.92 128.4 63.67 2.02 -2.01 0.85 8026.23 8.90 167.96 -3149.39 792.08 7107.52 3247.47 128.4 63.04 2.40 -2.36 -2.41 8089.34 7.62 164.41 -3158.19 794.22 7169.98 3256.53 131.1 63.11 2.18 -2.03 -5.63 8151.73 6.30 159.97 -3165.39 796.51 7231.91 3264.07 131.1 62.39 2.28 -2.12 -7.12 8215.74 5.18 152.66 -316 799.04 7295.60 3270.38 133.8 64.01 2.09 -1.75 -11.42 8278.36 4.64 147.32 -3175.90 801.70 7357.99 3275.53 133.8 62.62 1.13 -0.86 -8.53 8340.69 3.39 150.98 33 '.64 803.96 7420.16 3279.70 133.8 62.33 2.05 -2.01 5.87 8403.58 2.34 170.30 -3182.53 805.08 7482.97 3282.78 133.8 62.89 2.25 -1.67 30.72 8467.11 1.40 211.47 -3184.47 804.89 7546.47 3284.61 136.5 63.53 2.49 -1.48 64.80 8523.65 1.11 223.74 -3185.45 804.15 7603.00 3285.39' 125.7 56.54 0.70 -0.51 21.70 8586.23 0.40 239.71 -3186.00 803.54 7665.57 3285.77 125.7 62.58 1.17 -1.13 25.52 8648.90 0.55 356.16 -3185.81 803.34 7728.24 3285.54 128.4 62.67 1.29 0.24 185.81 8712.13 0.96 353.61 -3184.98 803.26 7791.47...._,p84.71 128.4 63.23 0.65 0.65 -4.03 8775.33 1.18 346.50 -3183.82 803.04 7854.65 3283.54 131.1 63.20 0.41 0.35 -11.25 8840.12 1.76 355.87 -3182.18 802.82 7919.42 '1281.89 131.1 64.79 0.97 0.90 14.46 8903.90 1.51 7.44 -3180.37 802.86 7983.18 3280.14 133.8 63.78 0.65 -0.39 18.14 8966.26 1.49 20.51 -3178.80 803.25 8045.52 3278.71 133.8 62.36 0.55 -0.03 20.96 9029.49 1.86 12.03 -3177.03 803.75 8I08.72 3277.12 136.5 63.23 0.70 0.59 -13.41 9092.77 1.72 11.76 -3175.09 804.16 8171.97 3275.34 136.5 63.28 0.22 -0.22 -0.43 9155.82 1.47 8.69 -3173.37 804.47 8234.99 3273.74 139.2 63.05 0.42 -0.40 -4.87 .01 1.79 5.87 -3171.58 804.69 8298.14;,x;;;4272.07 141.9 63.19 0.52 0.51 -4.46 9281.33 2.07 4.20 -3169.49 804.88 8360.44 3270.09_ 141.9 62.32 0.46 0.45 -2.68 9145.19 2.83 357.72 -3166.77 804.90 8424.24 3267.45 141.9 63.86 1.26 1.19. -10.15 9408.89 3.54 357.39 -3163.23 804.75 8487.84 3263.98 141.9 63.70 1.11 1.11 -0.52 9471.76 3.37 0.15 -3159.44 804.66 8550.60 3260.29 133.8 62.87 0.38 -0.27 4.39 9533.17 2.31 7.18 -3156.41 804.82 8611.94 3257.39 133.8 61.41 1.81 -1.73 11.45 ' 9598.09 2.21 10.68 -3153.88 805.22 8676.80 3255.03 136.5 64.92 0.26 -0.15 5.39 9661.49 2.60 6.49 -3151.25 805.61 8740.15 3252.58 139.2 63.40 0.67 0.62 -6.61 9725.27 3.04 3.20 -3148.13 805.86 8803.85 3249.61 141.9 63.78 0.69 -5.16 9787.44 3.35 0.97 -3144.67 805.99 8865.92 3246.28 141.9 62.17 0.54 0.50 -3.59 9850.78 3.65 359.98 -3140.80 806.02 8929.15 3242.54 144.6 63.34 MEM 0.47 -1.56 9912.97 4.11 356.44 -3136.59 805.88 8991.19 3238.43 144.6 62.19 0.83 0.74 -5.69 Projection to TD 9968.00 4.11 356.44 -3132.66 805.63 9046.08 3234.55 55.03 0.00 0.00 0.00 Tie Column Legend: I - interpolated tie-point, S- survey station, U -user-defined, T- Surface Page 3 i RECEIVED APR 282015 AOGCC rb Coo Ic INLeir £NseG-• 'I I 7OO Mo I MPRCT (52x svpeedesse II it 8Omin Iz NFU 42-3t A i So -731 -26696 Sugle Y { LOGS L43 , DUS ,T FPpD ic;k3 4 b+•41 I Volume in drive F is NFU 42-35 Volume Serial Number is 9F97-82A6 Directory of F:\ 04/27/2015 04:37 PM <DIR> DirSurvey 04/27/2015 04:38 PM <DIR> Logs 04/27/2015 04:39 PM 0 list.txt 1 File(s) 576 bytes Directory of F:\DirSurvey 04/27/2015 04:37 PM <DIR> . 04/27/2015 04:39 PM <DIR> .. 01/21/2015 01:00 PM 79,360 CIERig37_NFU_42-35_Final Survey.xls 04/27/2015 03:52 PM 11,726 CIERig37_NFU_42-35_Final Survey_loadfile.txt 01/19/2015 05:43 PM 76,194 CIERig37_NFU_42-35_Final_Survey.pdf 3 File(s) 167,736 bytes Directory of F:\Logs 04/27/2015 04:38 PM <DIR> . 04/27/2015 04:39 PM <DIR> .. 04/27/2015 04:37 PM <DIR> BakerTC 04/27/2015 04:37 PM <DIR> CBL 04/27/2015 04:38 PM <DIR> HalliburtonDVTC 04/27/2015 04:38 PM <DIR> HalliburtonTC_SWC_BHV 04/27/2015 04:38 PM <DIR> Perf Record 0 File(s) 2,048 bytes Directory of F:\Logs\BakerTC 04/27/2015 04:37 PM <DIR> . 04/27/2015 04:38 PM <DIR> .. 04/27/2015 04:37 PM <DIR> LAS 04/27/2015 04:37 PM <DIR> PDF 0 File(s) 1,060 bytes Directory of F:\Logs\BakerTC\LAS 04/27/2015 04:37 PM <DIR> . 04/27/2015 04:37 PM <DIR> .. 01/21/2015 07:34 AM 9,855,889 CIE_Rig37_NF42-35_MEM_4MPR_TC.Ias 1 File(s) 9,856,129 bytes Directory of F:\Logs\BakerTC\PDF 04/27/2015 04:37 PM <DIR> . 04/27/2015 04:37 PM <DIR> 01/21/2015 07:34 AM 2,240,936 CIE_Rig37_NFU-42-35_MD1MEM_4MPR_TC.PDF 01/21/2015 07:34 AM 3,729,162 CIE_Rig37_NFU-42-35_MD2MEM_4MPR_TC.PDF 01/21/2015 07:34 AM 7,875,071 CIE_Rig37_NFU-42-35_MD5MEM_4MPR_TC.PDF 01/21/2015 07:37 AM 2,529,479 CIE_Rig37_NFU-42-35_TVD1MEM_4MPR_TC.PDF 01/21/2015 07:37 AM 3,862,965 CIE_Rig37_NFU-42-35_TVD2MEM_4MPR_TC.PDF 01/21/2015 07:37 AM 7,500,502 CIE_Rig37_NFU-42-35 TVDSMEM_4MPR_TC.PDF 6 File(s) 27,738,763 bytes Directory of F:\Logs\CBL 04/27/2015 04:37 PM <DIR> . 04/27/2015 04:38 PM <DIR> 02/04/2015 06:55 PM 1,219,900 NFU_42_35_CBL_03Feb15_With_Image_03Feb15.Ias 02/04/2015 06:50 PM 12,666,257 NFU_42_35_CBL_03Feb15_With_Image_03Feb15.PDF 2 File(s) 13,886,665 bytes Directory of F:\Logs\HalliburtonDVTC 04/27/2015 04:38 PM <DIR> . 04/27/2015 04:38 PM <DIR> 02/04/2015 10:19 AM 4,617,346 COOK_INLET_ENERGY_NFU_42-35_DEVA-02_20JAN15.Ias 02/04/2015 10:19 AM 9,456,913 COOK_INLET_ENERGY_NFU_42-35_DEVA-02_20JAN15.pdf 02/04/2015 10:19 AM 35,174,099 COOK_INLET_ENERGY_NFU_42-35_DEVA-02_20JAN15_img.tiff 3 File(s) 49,249,014 bytes Directory of F:\Logs\HalliburtonTC_SWC_BHV 04/27/2015 04:38 PM <DIR> . 04/27/2015 04:38 PM <DIR> 02/04/2015 10:19 AM 6,408,436 NFU_42-35_BHV_20JAN15_img.pdf 02/04/2015 10:19 AM 2,692,273 NFU_42-35_BHV_20JAN15_img.tiff 02/04/2015 10:19 AM 25,547 NFU_42-35_SWCT_20JAN15.las 02/04/2015 10:19 AM 1,090,189 NFU_42-35_SWCT_20JAN15_img.pdf 02/04/2015 10:19 AM 459,663 NFU_42-35_SWCT_20JAN15_img.tiff 02/04/2015 10:19 AM 2,233,892 NFU_42-35_TC-Conductivity_20JAN15.las 02/04/2015 10:19 AM 2,215,656 NFU_42-35_TC_20JAN15.dlis 02/04/2015 10:19 AM 4,331,870 NFU_42-35 TC_20JAN15.Ias 02/04/2015 10:19 AM 10,044,984 NFU_42-35_TC_20JAN15_img.pdf 02/04/2015 10:19 AM 5,488,545 NFU_42-35_TC_20JAN15_img.tiff 1 ' 10 File(s) 34,992,087 bytes Directory of F:\Logs\Perf Record 04/27/2015 04:38 PM <DIR> . 04/27/2015 04:38 PM <DIR> .. 02/04/2015 06:51 PM 1,032,024 CI E_N F_42_35_4.5in_HSD_POWERJ ET_PURE_Perforation_Record_Rev2.pdf 1 File(s) 1,032,468 bytes Total Files Listed: 27 File(s) 136,926,546 bytes 27 Dir(s) 593,807,360 bytes free Cook Inlet Energy RECEIVED MAR 2 6 2015 March 26, 2015 Ms. Cathy Foerster, Chair AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: NFU 42-35 Well Completion Cook Inlet Energy, LLC: NFU 42-35 Permit to Drill No: 214-170 Dear Ms. Foerster, Please find our enclosed 10-407 Well Completion for the NFU 42-35 well. Included is the 10- 407 form, drilling summary, wellbore schematic, final survey, cementing report, and core depth sheet. If you have any questions, please contact me at(907)-727-7404. Sincerely, .1)"Conrad Perry Drilling Manager—Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax •. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas 0 SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _1 ' Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Datt Comp.,Susp.,or 12. Permit to Drill Number: Cook Inlet Energy, LLC Ab'and.-'"` 2/3/2015• 214-170 ' 3.Address: 6. Date Spudded: 13.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 1/2/2015• 50-231-20046-00-00 • 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 588'FSL&1453'FEL Sec 26 4S 14W 1/17/2015• North Fork Unit 42-35 • Top of Productive Horizon: 1310'FNL&919'FEL Sec 35 4S 14W 8. KB(ft above MSL): 6fi8.8�15. Field/Pool(s) µ kECE /ED GL(ft above MSL): 6 - .9 . North Fork Total Depth: 2502'FNL&582'FEL Sec 35 4S 14W 9. Plug Back Depth(MD+TVD): t4`-te, R 2 6 2015 N/A ;dD 7.,-/../., 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designati n ^ Surface: x- 199,958 • y- 2121128 ' Zone- 4 .9968'+9046' ADL 391210/ Afj' (�? /�• ! / TPI: x- 200435.21 y- 2119032.03 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: ,? �-f•/S Total Depth: x- 200686.45 y- 2117976.74 Zone- 4 357'+357' LOCI 10-004 18. Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: LWD,Realtime log,Resistivity,compensated Neutron,Compensated Density,Gamma Ray,CBL, N/A 23. CASING, LINER AND CEMENTING I4ECOF2D WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84 N/A 0 120 0 120 Driven N/A NONE 9 5/8" 40#SD L-80 0 2920 0 2750 12 1/4" 12ppg Lead 546 SXS+13ppg Tail 162 S NONE 7" 26 L-80 0 9948 0 9026 8 3/4" 13.5ppg Lead 816 SXS+13.5ppg tail 92 SX NONE 24.Open to production or injection? Yes ❑ - No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): Total Perfs 185' 2 7/8"6.5#L-80 9,504'MD 1. 5538/4911 ;_..GOMP ON) Cont.2.5829/5149 3.7158/6278 4.8107/7187 5.8961/8045 4954-4967 TVD 5590-5606 MD ' 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. 5093-5089 TVD 5737-5760 MD ' Zi: J ; Was hydraulic fracturing used during completion? Yes ❑ No 0 5269-5291 TVD 5974-6000 MD :-. 'i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 5676-5693 TVD 6467-6488 MD 6317-6336 TVD 7200-7220 MD 7240-7258 TVD 8160-8178 MD 7977-7993 TVD 8898-8914 MD 8581-8597 TVD 9502-9518 MD 8606-8620 TVD 9527-9541 MD 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 3/24/2015 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 3/24/2015 3 Test Period -O N/A 47 0 11/128 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 274 0 24-Hour Rate - N/A 375 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 . Sidewall Cores Acquired? Yes No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. See attached sheet for Core Depths Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 1-i5 -f5 ,..e.._�� R:DMS APR 1 8 201 >i.,�i 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? n Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top N/A N/A and submit detailed test information per 20 AAC 25.071. Permafrost-Base N/A N/A Beluga 1390 1326 Tyonek 5304 4720 Formation at total depth: 31. List of Attachments: 10-407,Wellbore Schematic, Daily Drilling Summaries, Direction Surveys, Casing and Cement Report,and Core Depths 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Conrad Perry A Email: Conrad.Perry@Cooklnlet.net Printed Name: Conrad Pyfj1I Title: Drilling Manager Signature: Phone: (907)727-7404 Date: 3/26/2014 INSTRUCTIONS General: This form is designed for sub fitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • 1 42-35 Final Completion Schematic Version: FINAL Cook Inlet Energy_ February 23,2015 20"Conductor i — th.. 20" _ 120#L-80 _ 120'MD 19" Welded 120'TVD 1 E� • TRSSSV @+/-35T MD-2.313"ID 1 1 s 1 1 A, 2 7/8"Chemical Injection Mandrel @+/-2521'MD-2.313"ID 12 114"Hole - 9 518" 40#L-80 2,920'MD ID 8.835" BTC 2,750'TVD —....., (1 I f'D All Sleeves Open Down Perforations d1i Sliding Sleeve @ 5489'MD-2.31"ID Tripoint Hydraulic Set Packer @ 5538' Sliding Sleeve @ 5588'MD-2.31"ID MD TVD Zone#1 5590-5606 4954-4967 Zone 1 5737-5760 5093-5089 Zone 1 Tripoint Hydraulic Set Packer @ 5829' 5974-6000 5269-5291 Zone 2 _ Sliding Sleeve @ 5877'MD-2.31"ID 6467-6488 5676-5693 Zone 2 a c Zone#2 7200-7220 6317-6336 Zone 3 a 8160-8178 7240-7258 Zone 4 Tripoint Hydraulic Set Packer @ 7158' 8898-8914 7977-7993 Zone 4 Sliding Sleeve @ 7206'MD-2.31"ID 9502-9518 8581-8597 Zone 5 Zone#3 aBill m= 9527-9541 8606-8620 Zone 5 - -- Tripoint Hydraulic Set Packer @ 8107' I Sliding Sleeve @ 8155'MD-2.31"ID a - 7Q a S= — . Tubing punch 8910'-8920'MD Future Perfs Thru Tbg Zone#4 MD TVD 9296-9300 8375-8379 Tripoint Hydraulic Set Packer @ 8961' 9808-9816 8886-8894 1I• k X Nipple @ 9004'MD-2.313"ID 9894-9896 8972-8974 li . XN Nipple @ 9037'MD-2.205"ID ME L LL — RA marker @ 9394'MD • Zone#5 a a a Tubing 2 718" 6.5#L80 EUE 9,504'MD ID-2.441" BTC 8,583'TVD Est.TOF @ 9,806'MD I - PBTD @ 9,858'MD 8,936'TVD TD at 9,968'MD 19,046'TVD 7" 26# L-80 9,948'MD 8 3/4"Hole ID-6.276" GeoCon 9,026'TVD • Cook Inlet Energy Well NFU 42-35 '/De ft,/?// Comes Sample# Depth (ft) MD Depth (ft)ND Length Est (in) Condition 24 5530 4905 0.3 C 23 5534 4908 0.4 C 22 No Recovery, No Depth Listed 21 5601 4962 0.3 C 20 5876 5188 0.6 B 19 5986 5280 0.2 D 18 5992 5285 0.3 C 17 5996 5288 0.5 B 16 6386 5609 0.3 C 15 6397 5618 0.6 B 14 6474 5681 0.3 C 12 6484 5690 0.3 C 13 6487 5692 0.5 C 11 No Recovery, No Depth Listed 10 No Recovery, No Depth Listed 9 7208 6325 0.4 C 8 7216.5 6333 0.8 B 7 7754 6841 Mudshot? Fail? 6 7762 6849 0.1 D 5 8166 7246 0.8 B 4 8175 7255 0.6 B 3 8872 7951 0.3 C 2 No Recovery, No Depth Listed 1 8906 7985 0.3 D Estimates of length and condition based on unopened sample jars, condition can be slighlty better or worse once jars are opened and samples actually analyzed. NFU 42 35 Drilling Summaries PTD: 214-170 12/29/14-12/31/14 Rig move and prep 1-1-15 Continue Rig prep, function test diverter 1-2-15 SPUD Well. Drill from 138'-650'. 1-3-15 Drill ahead from 650'-1547'. Short trip to 138'. 1-4-15 RIH. Drill ahead from 1547-2362'. 1-5-15 Drill ahead from 2362'-2573'. Short trip. RIH to bottom, drill ahead from 2573'- 2647'. 1-6-15 Drill ahead from 2647'-2920'. TD hole section. Condition and circulate. POH. 1-7-15 RIH with 9 5/8" 40#SD BTC casing to 2920'. RU cementers. Pump 241 bbls lead 12 ppg and 56.2 bbls tail of 13 ppg. Received 105 bbls cement to surface. Blow down cement unit and lines. 1-8-15 RD Cement. RD Diverter. Weld Wellhead 1-9-15 NU BOPE: test 1-10-15 RU BHA. RIH. Test Casing. Drill Out for LOTS LOT: 15.1 EMW 1-11-15 Drill ahead from 2828'to 3442' 1-12-15 Short trip to 2915'. RIH. Drill ahead from 3669'-5122'. Circulate hole clean. 1-13-15 Wiper Trip to 3980'. CBU. RIH. Drill ahead from 5122'-6568'. 1-14-15 Drill ahead from 6568'-7385'. Pump Hi Vis Sweep and condition mud. 1-15-15 Drill ahead from 7385'-8586'. Condition mud and circulate. POH to 7440'. 1-16-15 POH to 6545'. RIH. Drill ahead from 8586-9521. 1-17-15 POH to 7649. RIH. Drill ahead from 9521'-9968'TD Hole section. Condition mud. POH to 7656' 1-18-15 POH. BOPE test. RIH to 5206' 1-19-15 RIH from 5206'to 9968'. TOH and L/D BHA. 1-20-15 Finish laying down LWD/MWD. Rig up E-line P/U triple combo Tools,load sources. Run 24 sidewall cores. P/U clean out BHA. Mix 400 bbls of 4%kcl. 1-21-15 TIH with clean out BHA. Circulate hole clean. MW 9.3 1-22-15 Backream F/9968'.TOH,lay down excess drill pipe and clean out BHA. 1-23-15 Change upper pipe ram to 7" and test T/250 -3000 psi. Rig up for running casing. Pick up shoe track and check float collar. Run casing T/7000'. 1-24-15 Continue to run casing T/8925,unable to pass bridge. POH and laydown casing T/4795. 1-25-15 Finish laying down casing. Test BOPE. 1-26-15 Continue testing BOPE. Pick up cleanout BHA. Single in hole. Slip and cute drilling line. RIH T/7030' r 1-27-15 RIH T/9968 and condition mud. Build mud weight from 9.4 to 9.7. 1-28-2015 Short trip T/8500' circ and cond. Pump slug blow down mud lines. TOH and L/D BHA. Pull Wear Bushing. Change pipe rams. M/U 7" test joint and test. R/D test joint and pull test plug. 1-29-15 R/U casing tools and RIH to 9960'. P/U landing joint and land Hanger with 150K down. Start rigging up cement head. 1-30-15 1'1'; R/U cement head. Pump 30 bbls tuned spacer @ 10.5 ppg with Rig. Mix and pump 254 bbls of lead cement @ 13.5 ppg and 27.5 bbls of 13.5 tail. Drop plug and displace with 381 bbls of kcl brine @ 8.5 ppg. R/D cement lines and head. L/D landing joint. Service rig. Lay down 5" drill pipe out of Derrick. 1-31-15 Test 7" casing to 4000 psi for 30 min on chart. Rig up Schlumberger for CBL. Run CBL F/9860' T/3700'. Pick up perf guns, Run It 1 zone 5590' to 5606'. Short on guns POH with live guns. Pull apart guns and fix short. 2-1-15 TIH and Fire guns F/5590 T/5606, F/5737 T/5760, F/5974 T/6000, F/6467 T/6488, F/7200 T7220, F/8160 T/8178, and F/8898 T/8914. 2-2-15 Fire guns F/8898 T/8914. Service Rig. 2-3-15 RIH with completion. Rig up pollard control line to chemical injection sub. Pick up SSSV and tie in with control line. P/U pups for space out. RIH with CCL/GR correlate and land hanger. 2-4-15 Confirm landed correctly with CCL/GR. RIH with standing valve&set in XN nipple. Pressure up to 3000 psi to set packers&hold for 30 min. Test Annulus to 2500 psi for 30 min. POOH W/ standing valve. R/D slick line, close SSSV and plug chem injection line. Set BPV and start Nipple Down. , 2-5-15 Set Tree • ........... ... Will • KER _ Cook Inlet Energy ADVANTAGE Final Survey Listing HUUGHES INTEQ Operator Cook Inlet Energy Fields North Fork API No 231200460000 Well North Fork Unit#42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Well Origin Latitude 59.7962 deg Longitude -151.6291 deg North Reference True Drill Depth Zero Rig Floor Vertical Datum is Ground Level Vertical Datum to DDZ 20.80 ft Vertical Section North 0.00 ft Vertical Section East 0.00 ft Vertical Section Azimuth 165.8700 deg Vertical Section Depth 0.00 ft Grid Convergence 0.0000 deg Magnetic Declination 16.4400 deg Total Correction 16.4400 deg TVD Calculation Method Minimum Curvature D-Raw Calculation None Local Magnetic Field 55056 nT Local Magnetic Dip Angle 72.8580 deg Local Gravity Field 9.819 m/s^2 Tie In 1ft I Incl deg I Azim deg North I EasftI TftD I Vftt ITemdegFperature CRSft LEN Ideg/100ftDLS ldeg/1100ftd 1Turn deg/100ft T 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20.80 0.00 0.00 0.00 0.00 20.80 0.00 20.80 0.00 0.00 0.00 175.00 0.59 0.89 0.79 0.01 175.00 -0.77 68.9 154.20 0.38 0.38 0.58 233.00 0.81 352.61 1.50 -0.04 232.99 -1.46 74.3 58.00 0.42 0.38 -14.28 295.00 0.99 354.40 2.47 -0.14 294.99 -2.43 85.1 62.00 0.29 0.29 2.89 358.00 0.94 345.84 3.51 -0.32 357.98 -3.48 90.5 63.00 0.24 -0.08 -13.59 419.00 1.00 356.47 4.53 -0.48 418.97 -4.51 93.2 61.00 0.31 0.10 17.43 484.00 0.99 354.45 5.65 -0.57 483.96 -5.62 96.0 65.00 0.06 -0.02 -3.11 545.00 1.06 351.27 6.73 -0.70 544.95 -6.70 98.7 61.00 0.15 0.11 -5.21 608.00 0.56 6.32 7.62 -0.76 607.94 -7.57 104.1 63.00 0.86 -0.79 23.89 671.00 0.43 60.23 8.04 -0.52 670.94 -7.92 104.1 63.00 0.74 -0.21 85.57 733.00 0.39 50.43 8.29 -0.16 732.94 -8.08 106.8 62.00 0.13 -0.06 -15.81 798.00 0.45 35.43 8.64 0.16 797.94 -8.34 106.8 65.00 0.19 0.09 -23.08 861.00 0.31 51.60 8.94 0.44 860.93 -8.57 109.5 63.00 0.28 -0.22 25.67 923.00 0.10 118.94 9.02 0.62 922.93 -8.60 112.2 62.00 0.46 -0.34 108.61 988.00 1.05 159.48 8.44 0.88 987.93 -7.97 112.2 65.00 1.50 1.46 62.37 1050.00 2.05 166.76 6.83 1.33 1049.91 -6.29 112.2 62.00 1.64 1.61 11.74 1114.00 3.20 164.33 3.99 2.07 1113.84 -3.36 112.2 64.00 1.80 1.80 -3.80 1177.00 4.32 161.26 0.05 3.31 1176.70 0.76 117.6 63.00 1.81 1.78 -4.87 1241.00 5.22 162.10 -5.00 4.98 1240.48 6.07 125.7 64.00 1.41 1.41 1.31 1304.00 6.45 161.99 -11.09 6.96 1303.15 12.46 117.6 63.00 1.95 1.95 -0.17 1367.00 7.81 166.36 -18.62 9.06 1365.66 20.27 120.3 63.00 2.32 2.16 6.94 1429.00 9.14 169.33 -27.55 10.97 1426.99 29.40 120.3 62.00 2.26 2.15 4.79 1492.00 10.27 166.69 -37.94 13.18 1489.08 40.01 120.3 63.00 1.93 1.79 -4.19 1553.00 11.13 162.63 -48.85 16.19 1549.02 51.32 98.7 61.00 1.87 1.41 -6.66 1617.00 12.45 162.60 -61.33 20.10 1611.67 64.38 104.1 64.00 2.06 2.06 -0.05 1679.00 13.85 163.13 -74.81 24.25 1672.04 78.46 106.8 62.00 2.27 2.26 0.85 1742.00 14.86 164.55 -89.81 28.59 1733.08 94.07 109.5 63.00 1.70 1.60 2.25 1805.00 16.16 166.82 -106.13 32.75 1793.78 110.91 117.6 63.00 2.28 2.06 3.60 1867.00 17.35 166.93 -123.54 36.80 1853.15 128.79 117.6 62.00 1.92 1.92 0.18 1930.00 18.55 166.51 -142.43 41.27 1913.08 148.20 117.6 63.00 1.92 1.90 -0.67 1993.00 19.78 165.19 -162.49 46.33 1972.59 168.88 120.3 63.00 2.07 1.95 -2.10 2056.00 20.92 166.02 -183.71 51.77 2031.66 190.79 120.3 63.00 1.87 1.81 1.32 2121.00 22.01 168.31 -206.90 57.04 2092.15 214.56 77.0 65.00 2.11 1.68 3.52 2184.00 23.05 167.85 -230.51 62.03 2150.34 238.68 120.3 63.00 1.67 1.65 -0.73 2248.00 24.41 167.09 -255.65 67.62 2208.93 264.43 120.3 64.00 2.18 2.13 -1.19 2311.00 25.77 167.20 -281.70 73.56 2265.98 291.13 120.3 63.00 2.16 2.16 0.17 2373.00 27.05 168.17 -308.64 79.44 2321.51 318.70 120.3 62.00 2.18 2.06 1.56 2437.00 28.45 167.76 -337.78 85.66 2378.15 348.47 120.3 64.00 2.21 2.19 -0.64 2500.00 29.95 167.85 -367.82 92.15 2433.14 379.19 120.3 63.00 2.38 2.38 0.14 2562.00 30.50 168.94 -398.40 98.42 2486.71 410.37 106.8 62.00 1.25 0.89 1.76 2626.00 31.53 168.86 -430.76 104.77 2541.56 443.30 109.5 64.00 1.61 1.61 -0.13 2690.00 32.54 167.08 -463.95 111.86 2595.82 477.22 112.2 64.00 2.16 1.58 -2.78 2754.00 33.35 167.21 -497.89 119.60 2649.52 512.02 114.9 64.00 1.27 1.27 0.20 2816.00 34.52 166.24 -531.57 127.55 2700.96 546.62 117.6 62.00 2.08 1.89 -1.56 2863.00 35.10 166.70 -557.65 133.83 2739.55 573.45 117.6 47.00 1.35 1.23 0.98 2923.90 34.83 166.04 -591.57 142.05 2789.46 608.35 85.1 60.90 0.76 -0.44 -1.08 2986.54 35.09 166.49 -626.44 150.57 2840.80 644.24 85.1 62.64 0.58 0.42 0.72 3049.22 36.06 166.05 -661.86 159.23 2891.78 680.71 90.5 62.68 1.60 1.55 -0.70 3110.45 36.85 166.08 -697.17 167.99 2941.03 717.09 93.2 61.23 1.29 1.29 0.05 Page 1 J 17M- Cook Inlet Energy ADVANTAGE Final Survey Listing HUGHES DEQ Operator Cook Inlet Energy Fields North Fork API No 231200460000 Well North Fork Unit #42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Tie In rftD I deg I Azim deg ft North I Eftt I Tft VD I VS ITemdegFperature CRS LEN Ideg/100ftDLS ldeg/1IOOftd lTurn deg/l00ft 3174.34 37.33 166.12 -734.57 177.25 2991.99 755.62 96.0 63.89 0.75 0.75 0.06 3237.20 37.72 165.80 -771.72 186.53 3041.84 793.91 96.0 62.86 0.69 0.62 -0.51 3300.51 37.99 166.64 -809.45 195.79 3091.83 832.75 96.0 63.31 0.92 0.43 1.33 3363.23 38.16 166.86 -847.10 204.65 3141.20 871.43 98.7 62.72 0.35 0.27 0.35 3427.00 38.01 166.08 -885.34 213.85 3191.40 910.76 98.7 63.77 0.79 -0.24 -1.22 3489.29 38.01 165.67 -922.54 223.22 3240.48 949.12 98.7 62.29 0.41 0.00 -0.66 3552.25 37.22 165.16 -959.73 232.89 3290.35 987.55 101.4 62.96 1.35 -1.25 -0.81 3614.92 36.17 165.43 -995.95 242.40 3340.60 1024.99 104.1 62.67 1.70 -1.68 0.43 3679.10 36.34 165.80 -1032.72 251.83 3392.35 1062.95 96.0 64.18 0.43 0.26 0.58 3742.21 35.69 165.06 -1068.63 261.16 3443.40 1100.05 98.7 63.11 1.24 -1.03 -1.17 3804.91 35.72 164.54 -1103.94 270.75 3494.31 1136.64 101.4 62.70 0.49 0.05 -0.83 3867.35 35.47 164.61 -1138.98 280.42 3545.09 1172.97 101.4 62.44 0.41 -0.40 0.11 3930.72 35.64 164.02 -1174.45 290.38 596.64 1209.81 104.1 63.37 0.60 0.27 -0.93 3993.67 35.34 163.96 -1209.58 300.46 3647.90 1246.33 106.8 62.95 0.48 -0.48 -0.10 .i 4056.65 35.1+64.48 -1244.56 310.35 t699.33 1282.66 109.5 62.98 0.56 -0.30 0.83 4120.18 34.87 164.39 -1279.67 320.13 3751.37 1319.10 109.5 63.53 0.45 -0.44 -0.14 4184.31 34.76 164.20 -1314.91 330.04 3804.02 1355.70 112.2 64.13 0.24 -0.17 -0.30 4246.32 35.05 164.10 -1349.05 339.73 3854.87 1391.17 112.2 62.01 0.48 0.47 -0.16 4309.96 34.58 163.99 -1383.98 349.72 3907.12 1427.48 109.5 63.64 0.75 -0.74 -0.17 4373.66 34.36 163.82 -1418.62 359.71 3959.64 1463.51 112.2 63.70 0.38 -0.35 -0.27 4437.19 34.66 164.11 -1453.21 369.65 4011.99 1499.49 114.9 63.53 0.54 0.47 0.46 4499.38 34.76 163.99 -1487.26 379.38 4063.11 1534.88 114.9 62.19 0.19 0.16 -0.19 4562.54 34.88 164.40 -1521.96 389.21 4114.96 1570.93 114.9 63.16 0.42 0.19 0.65 4625.30 34.95 165.69 -1556.67 398.47 4166.43 1606.85 117.6 62.76 1.18 0.11 2.06 4688.89 35.31 165.49 -1592.11 407.58 4218.43 1643.44 117.6 63.59 0.59 0.57 -0.31 4755.00 35.57 164.76 -1629.16 417.42 4272.29 1681.77 120.3 66.11 0.75 0.39 -1.10 4816.72 35.84 164.83 -1663.92 426.87 4322.41 1717.78 120.3 61.72 0.44 0.44 0.11 4879.29 36.26 165.10 -1699.48 436.42 4373.00 1754.60 120.3 62.57 0.72 0.67 0.43 4942.32 36.08 165.57 -1735.46 445.84 4423.88 1791.80 120.3 63.03 0.52 -0.29 0.75 5005.29 35.74 166.46 -1771.30 454.77 4474.88 1828.73 120.3 62.97 0.99 -0.54 1.41 5069.93 35.82.__166.42 -1808.04 463.63 4527.33.._ 866.52 120.3 64.64 0.13 0.12 -0.06 5123.77 35.42 166.50 -1838.53 470.97 4571.09 1897.87 109.5 53.84 0.75 -0.74 0.15 5186.24 34.50 167.85 -1873.43 478.92 4622.29 1933.66 112.2 62.47 1.92 -1.47 2.16 5249.90 34.67 166.56 -1908.66 486.92 4674.70 1969.78 112.2 63.66 1.18 0.27 -2.03 5313.15 34.68 167.02 -1943.69 495.14 4726.72 2005.76 114.9 63.25 0.41 0.02 0.73 5375.68 34.69 167.07 -1978.37 503.12 4778.13 2041.34 114.9 62.53 0.05 0.02 0.08 5438.68 34.96 166.34 -2013.38 511.40 4829.85 2077.31 117.6 63.00 0.79 0.43 -1.16 5502.06 35.10 166.24 -2048.73 520.02 4881.75 2113.69 117.6 63.38 0.24 0.22 -0.16 5564.99 35.066.51 -2083.86 528.53 4933.26 2149.84 117.6 62.93 0.27 -0.11 0.43 5628.04 35.20 166.41 -2119.12 537.03 4984.83 2186.11 117.6 63.05 0.28 0.27 -0.16 5691.82 34.75 165.56 -2154.59 545.88 5037.09 2222.67 120.3 63.78 1.04 -0.71 -1.33 5755.48 34.59 165.45 -2189.65 554.94 5089.45 2258.88 120.3 63.66 0.27 -0.25 -0.17 5817.90 34.92 164.99 -2224.06 564.02 5140.74 2294.46 120.3 62.42 0.68 0.53 -0.74 5881.97 35.05 165.05 -2259.55 573.52 5193.23 2331.19 123.0 64.07 0.21 0.20 0.09 5945.52 34.38 164.99 -2294.51 582.87 5245.47 2367.38 123.0 63.55 1.06 -1.05 -0.09 6007.91 33.83 165.92 -2328.37 591.66 5297.13 2402.36 123.0 62.39 1.21 -0.88 1.49 r 6070.90 34.11.. 65.65 -2362.49 600.30 5349.37 2437.56 123.0 62.99 0.50 0.44 1.43 6133.57 34.35 165.97 -2396.66 608.94 5401.18 2472.81 123.0 62.67 0.48 0.38 0.51 6197.07 34.34 165.67 -2431.40 617.72 5453.61 2508.63 125.7 63.50 0.27 -0.02 -0.47 6260.95 34.54 165.89 -2466.42 626.59 5506.29 2544.76 125.7 63.88 0.37 0.31 0.34 6324.87 34.88 165.52 -2501.69 635.58 5558.84 2581.16 125.7 63.92 0.63 0.53 -0.58 6387.24 35.13 165.51 -2536.33 644.53 5609.92 2616.93 128.4 62.37 0.40 0.40 -0.02 6450.96 34.36 165.25 -2571.47 653.69 5662.28 2653.25 128.4 63.72 1.23 -1.21 -0.41 6512.78 33.76 165.06 -2604.94 662.56 5713.50 2687.87 128.4 61.82 0.99 -0.97 -0.31 6576.91 33.67 164.78 -2639.31 671.83 5766.84 2723.46 125.7 64.13 0.28 -0.14 1.44 6635.38 33.68 164.43 -2670.56 680.43 5815.50 2755.87 112.2 58.47 0.33 0.02 -0.60 6699.04 31.40 165.38 -2703.62 689.36 5869.16 2790.11 117.6 63.66 3.67 -3.58 111111.49 6761.88 30.00 164.70 -2734.61 697.63 5923.19 2822.18 117.6 62.84 2.30 -2.23 -1.08 6825.45 29.02 164.44 -2764.80 705.96 5978.52 2853.49 120.3 63.57 1.55 -1.54 -0.41 6888.42 27.36 165.67 -2793.53 713.64 6034.02 2883.23 120.3 62.97 2.79 -2.64 1.95 Page 2 • read KER• Cook Inlet Energy- ADVANTAGE Final Survey Listing HUGHES INTEQ Operator Cook Inlet Energy Fields North Fork API No 231200460000 Well North Fork Unit#42-35 Wellbore NFU #42-35 Orig Hole Rig 37 Job 6904702 Tie In rftD I Incl deg I deg AzimN ft h Eftt I t D I VS ITemdegFrture CR ft LEN Ideg/100ftDLS ldeg/100ft Build lTurn deg/100ft 6951.71 25.95 166.56 -2821.09 720.46 6090.58 2911.62 123.0 63.29 2.32 -2.23 1.41 7013.56 24.99 166.11 -2846.94 726.74 6146.42 2938.22 123.0 61.85 1.58 -1.55 -0.73 7077.22 23.69 166.55 -2872.43 732.95 6204.42 2964.45 123.0 63.66 2.06 -2.04 0.69 7140.17 22.93 167.21 -2896.69 738.60 6262.23 2989.36 125.7 62.95 1.28 -1.21 1.05 7203.86 22.57 166.75 -2920.69 744.15 6320.96 3013.98 125.7 63.69 0.63 -0.57 -0.72 7267.82 21.90 167.64 -2944.29 749.52 6380.17 3038.18 125.7 63.96 1.17 -1.05 1.39 7330.64 21.04 168.52 -2966.78 754.27 6438.62 3061.15 120.3 62.82 1.46 -1.37 1.40 7393.50 19.97 167.04 -2988.30 758.92 6497.51 3083.16 123.0 62.86 1.89 -1.70 -2.35 7455.72 18.95 166.46 -3008.48 763.67 6556.17 3103.88 123.0 62.22 1.67 -1.64 -0.93 7520.52 17.95 168.25 -3028.48 768.17 6617.64 3124.38 123.0 64.80 1.77 -1.54 2.76 7582.48 17.13 168.91 -3046.79 771.87 6676.72 3143.04 123.0 61.96 1.36 -1.32 1.07 7645.76 16.73 169.58 -3064.89 775.31 6737.26 3161.43 125.7 63.28 0.70 -0.63 1.06 7708.23 15.69 168.64 -3082.02 778.60 6797.24 3178.84 123.0 62.47 1.72 -1.66 -1.50 7771.44 14.80 168.21 -3098.30 781.93 6858.23 3195.44 125.7 63.21 1.42 -1.41 -0.68 7835.51 13.26 168.63 -3113.51 785.05 6920.38 3210.96 128.4 64.07 2.41 -2.40 0.66 7899.52 11.67 168.94 -3127.06 787.74 6982.88 3224.76 128.4 64.01 2.49 -2.48 0.48 7963.19 10.39 169.48 -3139.03 790.03 7045.38 3236.92 128.4 63.67 2.02 -2.01 0.85 8026.23 8.90 167.96 -3149.39 792.08 7107.52 3247.47 128.4 63.04 2.40 -2.36 -2.41 8089.34 7.62 164.41 -3158.19 794.22 7169.98 3256.53 131.1 63.11 2.18 -2.03 -5.63 8151.73 6.30 159.97 -3165.39 796.51 7231.91 3264.07 131.1 62.39 2.28 -2.12 -7.12 8215.74 5.18 152.66 -3171.26 799.04 7295.60 3270.38 133.8 64.01 2.09 -1.75 -11.42 8278.36 4.64 147.32 -3175.90 801.70 7357.99 3275.53 133.8 62.62 1.13 -0.86 -8.53 8340.69 3.39 150.98 -3179.64 803.96 7420.16 3279.70 133.8 62.33 2.05 -2.01 5.87 8403.58 2.34 170.30 -3182.53 805.08 7482.97 3282.78 133.8 62.89 2.25 -1.67 30.72 8467.11 1.40 211.47 -3184.47 804.89 7546.47 3284.61 136.5 63.53 2.49 -1.48 64.80 8523.65 1.11 223.74 -3185.45 804.15 7603.00 3285.39 125.7 56.54 0.70 -0.51 21.70 8586.23 0.40 239.71 -3186.00 803.54 7665.57 3285.77 125.7 62.58 1.17 -1.13 25.52 8648.90 0.55 356.16 -3185.81 803.34 7728.24 3285.54 128.4 62.67 1.29 0.24 185.81 8712.13 0.96 353.61 -3184.98 803.26 7791.47 3284.71 128.4 63.23 0.65 0.65 -4.03 8775.33 1.18 346.50 -3183.82 803.04 7854.65 3283.54 131.1 63.20 0.41 0.35 -11.25 8840.12 1.76 355.87 -3182.18 802.82 7919.42 3281.89 131.1 64.79 0.97 0.90 14.46 8903.90 1.51 7.44 -3180.37 802.86 7983.18 3280.14 133.8 63.78 0.65 -0.39 18.14 8966.26 1.49 20.51 -3178.80 803.25 8045.52 3278.71 133.8 62.36 0.55 -0.03 20.96 9029.49 1.86 12.03 -3177.03 803.75 8108.72 3277.12 136.5 63.23 0.70 0.59 -13.41 9092.77 1.72 11.76 -3175.09 804.16 8171.97 3275.34 136.5 63.28 0.22 -0.22 -0.43 9155.82 1.47 8.69 -3173.37 804.47 8234.99 3273.74 139.2 63.05 0.42 -0.40 -4.87 9219.01 1.79 5.87 -3171.58 804.69 8298.16 3272.07 141.9 63.19 0.52 0.51 -4.46 9281.33 2.07 4.20 -3169.49 804.88 8360.44 3270.09 141.9 62.32 0.46 0.45 -2.68 9345.19 2.83 357.72 -3166.77 804.90 8424.24 3267.45 141.9 63.86 1.26 1.19 -10.15 9408.89 3.54 357.39 -3163.23 804.75 8487.84 3263.98 141.9 63.70 1.11 1.11 -0.52 9471.76 3.37 0.15 -3159.44 804.66 8550.60 3260.29 133.8 62.87 0.38 -0.27 4.39 9533.17 2.31 7.18 -3156.41 804.82 8611.94 3257.39 133.8 61.41 1.81 -1.73 11.45 9598.09 2.21 10.68 -3153.88 805.22 8676.80 3255.03 136.5 64.92 0.26 -0.15 5.39 9661.49 2.60 6.49 -3151.25 805.61 8740.15 3252.58 139.2 63.40 0.67 0.62 -6.61 9725.27 3.04 3.20 -3148.13 805.86 8803.85 3249.61 141.9 63.78 0.73 0.69 -5.16 9787.44 3.35 0.97 -3144.67 805.99 8865.92 3246.28 141.9 62.17 0.54 0.50 -3.59 9850.78 3.65 359.98 -3140.80 806.02 8929.15 3242.54 144.6 63.34 0.48 0.47 -1.56 9912.97 4.11 356.44 -3136.59 805.88 8991.19 3238.43 144.6 _ 62.19 0.83 0.74 -5.69 Projection to TD 9968.00 4.11 356.44 -3132.66 805.63 9046.08 3234.55 55.03 0.00 0.00 0.00 Tie Column Legend: I - interpolated tie-point, S - survey station, U - user-defined, T- Surface Page 3 ., Conductor Cook Inlet Energy Casing and Cementing Report Te12: Operator:Cook Inlet Energy Consultant Allen Lunda/Daniel Sainz Tell UWI: 50-231-20046-00-00 WELL: NFU 42-35 DATE: 08-Jan-2015 AFE No.: 146005 KB Elevation: 678.58 ft -1KB to Ground: 20.58 ft KB to CBF: 21.70 ft I CBF Elevation: 656.88 ft CASING SUMMARY NO.of JTS. Size O.D Weight CASING GRADE THREAD STRING DESCRIPTION Length Tops ftKB (in) (lb/ft) S/P Y/S ft ftKB ftKB 1 9.6 40.00 N 80 BUTT Float Shoe Single 1.78 2918.22 2920.00 1 9.6 40.00 N 80 BUTT Surface Casing 43.86 2874.36 2918.22 1 9.6 40.00 N 80 BUTT Float Collar Single 2.07 2872.29 2874.36 70 9.6 40.00 N 80 BUTT Surface Casing 2838.77 33.52 2872.29 1 7.0 26.00 N 80 BUTT Production Casing 41.56 -8.04 33.52 Total Number of items in Use: 74 Total length In Use: 2928.04 ft Rig Ld Joint: 34.S2 ft Liner Top: ftKB Number of full length joints on site: 72 Total full length Joints: 2924.19 ft Shoe Joint Length: ft Top Marker Set At t: 0.00 ftKB Number of full length joints left Out: 0 Total full length left Out: 175.42 ft , Stick Up: 8.04 ft Plug Back TD: ftKB Number of full length joints left In: 72 Total Length left In: 2924.19 ft Left In Hole: 2928.04 ft LCsg Landed @ 2920.00 ftKB Csg Bowl Model: Csg Bowl Serial#: Make Up Torque: ft•Ib TVD Depth: ft Csg Bowl MFG: Size: x Pressure: psi OutletType: Hole Depth: ftKB Transferred: 0 Joints Moved from: 50.231-20046-00-00 To: via: Hole Size: 0.00 in Markers Make: Number:0 Positions:0 Centralizers Make: Number: Positions: Scratchers Make: Number: Positions: Pup Joints Make: Number: Positions: Couplings Make: Number: Positions: Turbolizers Make: OGL Number:23 Positions:Every 3rd joint Casing on pe Circulated for Circulating Pressure Prior Circulation Rate Mud Properties Mud Checked Bottom @ to Cementing(psi) (BPM) yp PV Gels 9:00 12 Hrs 350 10 14 14 5/7/8 Yes Landed in: 0 Tension 0 Compression Q Unspecified Weight: 0.00 lbf CEMENTING SUMMARY Pressure Test: psi Safety Meeting: Circulation While Mixing: Rate BPM Cemented By: TIME STAGE INTERVAL AMOUNT UNIT TYPE/ADDITIVE CEMENT SLURRY TOP (ftKB) BOTTOM (ftKS) CODE VOLUME(bbl) Density(Ib/gal) FILL04 241 12 NO.1 TAIL 0 2400 546 If Sacks N0.2 FILL ,( TAIL 2400 2920 162 ✓ Sacks 04 56.2 13 NO.3 FILL TAIL Lines Pumped Out? ❑Yes ❑ No On the Fly? ❑Yes p No Circulation: %Excess: Displaced Volume(bbl) Fluid Used Rate Circulating Pressure(psi) Plug Down Float(s) Calculated Actual (BPM) Initial Maximum Bump Day Month Year Time Held FLOAT COLLAR 214 217 WATER 6 300 696 1328 07/Jan/2015 23:30 Yes STAGE COLLAR Cement Returns to Surface Q Yes ❑ No Volume: 80 bbl Type of Returns Cement RIM Milli Version 1136 Wellman 9-Resource Energy Solutions Inc.(403)245-0220 www.resourceenergysolutions.com March 25 2015 Page 1 of 1 Surface _ _Cook Inlet Energy_ Casing and Cementing Report Telt: Operator.Cook Inlet Energy Consultant T.McKiernen/A.Lunda Tell: (907)433-3549 UWI: 50-231-20046-00-00 WELL: NFU 42-35 DATE: 30-Jan-2015 AFE No.: 146005 KB Elevation: 678.58 ft KB to Ground: 20.58 ft KB to CBF: 21.70 ft CBF Elevation: 656.88 ft CASING SUMMARY NO.of JTS. Size O.D Weight CASING GRADE THREAD STRING DESCRIPTION Length Tops ftKB (in) (lb/ft) S/P Y/S ft ftKB ftKB 1 7.0 26.00 L 80 Geoconn Guide Shoe 3.58 9945.19 9948.77 2 7.0 26.00 L 80 Geoconn Production Casing 85.85 9859.34 9945.19 1 7.0 26.00 L 80 Geoconn Float Collar Single 1.70 9857.64 9859.34 219 7.0 26.00 L 80 Geoconn Production Casing 9451.20 406.44 9857.64 9 7.0 26.00 P 110 Geoconn Production Casing 379.07 27.37 406.44 1 7.0 26.00 L 80 Geoconn Pup Joint 3.37 24.00 27.37 1 7.0 26.00 L 80 Geoconn Landing Joint 28.23 -4.23 24.00 Total Number of items in Use: 248 Total length In Use: 10542.78 ft Rig Ld Joint: 28,23 ft Liner Top: ftKB Number of full length joints on site: 244 Total full length Joints: 10505.90 ft Shoe Joint Length: ft Top Marker Set At: 0,00 ftKB Number of full length joints left Out: 14 Total full length left Out: 589.78 ft _ Stick Up: 4.23 ft Plug Back TD: ftKB Number of full length joints left In: 230 Total Length left In: 9916.12 ft Left In Hole: 9924.77 ft Csg Landed @ 9948.77 ftKB Csg Bowl Model: Csg Bowl Serial#: Make Up Torque: tit) TVD Depth: 2725.00 ft Csg Bowl MFG: Size: x Pressure: psi OutletType: SSO Hole Depth: 9968.00 ftKB Transferred: 14 Joints Moved from: 50-231-20046-00-00 To: via: Hole Size: 8.75 in Markers Make: Number:0 Positions:0 Centralizers Make: Number: Positions: _ Scratchers Make: Number: Positions: Pup Joints Make: Number:1 Positions: under hanger Couplings Make: Number: Positions: Turbolizers Make: Number: Positions: Casing on Circulating Pressure Prior Circulation Rate Mud Properties Bottom Circulated for to Cementing(psi) BPM Mud Checked @ (BPM) YPjimr PV Gels 19:00 6 Hrs 730 7 19 17 4/7/7 Yes Landed in: 0 Tension 0 Compression QQ Unspecified Weight: 0.00 lbf CEMENTING SUMMARY Pressure Test: 4000 psi Safety Meeting: Yes Circulation While Mixing: Full Rate: 7 BPM Cemented By: Halliburton TIME STAGE TOP (ftKB)ERVAL BOTTOM (5KB) AMOUNT UNIT TYPE/ADDITIVE CEMENTCODEVOLUME(bbl)SLURD Density(lb/gal) 2:54 N0. FILL 3993 9432 816 Sacks Microlite, Halad-344,SCR-100,SUPER CBL,EZ-F 04 254 13.5 1 TAIL 9432 9950 92 Sacks II,SA-1015,D-AIR 5000 04 27.5 13.5 FILL NO.2 TAIL NO.3 FILL TAIL Lines Pumped Out? ®Yes ❑ No On the Fly? ❑Yes © No Circulation: Full %Excess: 0 Displaced Volume(bbl) Fluid Used Rate Circulating Pressure(psi) Plug Down Float(s) Calculated Actual (BPM) Initial Maximum Bump Day Month Year Time Held FLOAT COLLAR 377 382 WATER 4.5 265 2200 3105 30/Jan/2015 06:10 Yes STAGE COLLAR Cement Returns to Surface ❑Yes © No Volume: bbl Type of Returns REMARKS 6 VLf' a l j=am _I S4, - .5-eta& m1) 7-0 `-f L(0 L)' /IA.D -Z.4,s---t 5-- Version Version 1136 Wellman 9-Resource Energy Solutions Inc.(403)245-0220 www.resourceenergysolutions.com March 25 2015 Page 1 of 1 c)7/ y- rte Cook Inlet Energy, LLC 74-1 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: January 30, 2015 To: Meredith Guhl From: Barbara Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433 -3802 FAX: (907) 334-6735 TRANSMITTAL DESCRIPTION Well Data for North Fork Unit - 42-35, API#50-231-20046-00-00 Item No. Qty Description 1 Washed &Dried Samples for North Fork Unit-42-35 1 Box 1 of 5- Dry Samples Interval depths(2,920' -4,410') @ 30' 1 Box 2 of 5- Dry Samples Interval depths(4,410'-5,910') @ 30' 1 Box 3 of 5-Dry Samples Interval depths(5,910'-7,410') @ 30' 1 Box 4 of 5- Dry Samples Interval depths (7,410' -8,910') @ 30' 1 Box 5 of 5- Dry Samples Interval depths (8,910' -9,968') @ 30' EC \JED Please sign below to acknow ecelp I AN 3 0 2015 Received By: Angela K. Singh Date: AOGGC Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC.xlsx/AOGCC 1-30-15 NF42-35 '' � OF , THE STATE Alaska Oil and Gas � \�\��7, s �w I- foALAS� Conservation Commission =.--- M 333 West Seventh Avenue *M1,� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manger Cook Inlet Energy, LLC 601 W. 5ht Ave., Suite 310 a.I Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU 42-35 Sundry Number: 315-039 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 27 day of January, 2015 Encl. RECEIVED STATE OF ALASKA JAN 2 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon Plug for Redrill❑ Perforate New Pool E Repair Well❑ Change Approved Program❑ Suspen❑ Plug Perforations❑ Perforate❑✓ - Pull Tubing❑ Time Extension� Ile Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: RCA,1+ h itt Il 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q 214-170 • ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20046-00-00 • 7.If perforating: , 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 2 26:955 Will planned perforations require a spacing exception? Yes ❑., No ❑ North Fork Unit 42 35 9.Property Designation(Lease Number): 10.Field/Pool(s): 394.2.1.0m 4154.53./24./ 74...De_ .3 /zio / �3 is-Development North Fork Undefinded Gas • l 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,968 9,046 9,968 9,046 None None Casing Length Size MD TVD Burst Collapse Structural 120' 20" 120' 120' N/A Conductor Surface 2920 9 5/8" 2920 2750 5750 3090 Intermediate Production 9960 7" 9960 8359 7240 5410 Liner (Production Casing not run yet) Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: an • 12.Attachments: Description Summary of Proposal ❑✓ '13.Well Class after proposed work: • Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑] Service ❑ 14.Estimated Date for 1/26/2015 15.Well Status after proposed work: Commencing Operations: _-------- Oil ❑ Gas Q • WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Courtney Rust 907-433-3809 Email courtnev.rust(a cookinlet.net Printed Name Conrad IIF Drilling Mail 727-�4 Title _ 1/23/2015 Signature ' one Date COMMISSION USE ONLY Conditions of approval: Notify Commission.o th . epresentative ay witness Sundry Number: Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: /S W T C Pth5P : 37os•-• /03.:.> �' `loo0�os,: A F/ 4.s •t3 /l'c�+moor�Z� c,Lr.Jcar ZO /QAj6 r / • !a-e i^l a -.4_,,,,a t,...e__,...e__ ZQ M M.s J rt ExceptionRequired? Ji `'iKt ,./ -t-Cp .3+v�-„kl% 7� Ji5.(_ /y%' t� /4, is 1` Spacing Yes No � , Subsequent Form Required: l 407 qia de- _�r-1 J APPROVED S BY ` /Z7/�� Approved by: /(:=7) Y COMMISSIONER THE COMMISSION Date: // Of4iG4a4 Submit Form and Form 10 403(Bevis 10/2012) i�lor 12 months from the date of approval. Attachments in Duplicate RBDMS JAN 2 7 2015/10 ,5—s/ -z-3 rs� • Cook Inlet Energy_ RECEIVED JAN 232015 AOGCC January 23, 2015 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 42 35 API: 50-231-20046-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completion sundry for North Fork Unit 42-35, PTD: 214-170. AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE requests permission to vent or flare gas from the North Fork Unit 42-35 well test for a period of 14 days according to 20 AAC 25.235 d (6). Maximum anticipated daily flaring is expected to be 10 MMSCF/D with a total expected not to exceed 20 MMSCF over the entire test. If the well is successful, it will be tied into the North Fork production facility. If you have any questions, please contact me at (907) 727-7404. Sincerely, Conrad Perry Drilling Mana, ;r-Coo let Energy 1 Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 42 35 Requirements of 20 MC 25.005(f) Well Summary Current Status: Well has been drilled to TD and 7" production casing is being run. Scope of Work: • Wireline perforate and run a multi-zone single selective completion. General Well Information: Reservoir Pressure/TVD: 4192 psi @ 9,750 TVD • MASP: 3,705 psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Gas Well Estimated Start Date: January 23, 2015 Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Courtney Rust (907) 433-3809 Courtney.rust@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 2 Cook Inlet Energy_ NFU 42-35 Completion Procedure ?� rbiA` o, , Q. :2 The 7" casing top plug will be displaced with 4% filtered KCL brine (+/- 8.6 ppg) ©' ^'`` lA7T ;17 yc 1) Lay down 5" drill pipe. �,ZU ly 2) Make 6" gauge ring run to bottom on slick line. 3) Rig up Schlumberger Electric line 4) Run CBL. Send to engineering ASAP. If bad, a squeeze procedure will be prepared. 5) Perforate the following intervals with 4 'A" PowerJet 4505 Pure Casing Guns at 3 'A" SPF. MD TVD Area From To From To Zone 1 5,590' 5,606' 4,946' 4,967' Casing Guns 5,737' 5,760' 5,074' 5,093' Zone 2 5,974' 6,000' 5,269' 5,291' 6,467' 6,488' 5,676' 5,697' I' Zone 3 7,200' 7,220' 6,317' 6,336' Zone 4 8,160' 8,178' 7,240' 7,258' 8,898' 8,914' 7,977' 7,993' Zone 5 9,296' 9,300' 8,375' 8,379' thru tbg 9,502' 9,518' 8,581' 8,597' TCP 9,527' 9,541' 8,606' 8,620' TCP 9,808' 9,816' 8,886' 8,894' thru tbg 9,894' 9,896' . 8,972' 8,974' thru tbg 6) Run 6.1"Gauge Ring and Junk Basket(clear perfs for packers) 3 Cook Inlet Energy_ 7) Pick up Schlumberger TCP assembly to perforate from 9502' to 9518'. a. Mule shoe b. 4 %2""TCP guns 6 spf for following intervals i. 9502' to 9518' ii. 9527' to 9541' c. TCP Drop Bar firing head without delay at+/- 9495' C d. 2 7/8"XN nipple at 9010' e. 2 7/8"X nipple at 8980' f. Tripoint 7"Hydraulic Packer at 8950' g. 2 7/8"tubing to 2 7/8" Sliding sleeve (closed) at 8150' h. Tripoint 7" Hydraulic Packer at 8120' i. 2 7/8"tubing to Sliding sleeve at 7190' j. Tripoint 7"Hydraulic Packer at 7160' k. 2 7/8"tubing to 2 7/8" Sliding sleeve (closed)at 5864' 1. Tripoint 7"Hydraulic Packer at 5934' m. 2 7/8"tubing to 2 7/8" Sliding sleeve (closed)at 5580' n. Tripoint 7"Hydraulic Packer at 5550' o. 2 7/8"tubing to Sliding sleeve (closed) at 5520' p. 2 7/8"tubing to chemical injection mandrel at 2500' q. 2 7/8"tubing to Tubing Retrievable SSSV at 350'. r. Vetco 11"x 2 7/8"tubing hanger 8) Rig up eLine and run GR CCL correlation log 9) Space out and land hanger. 10)Confirm space out with GR/CCL 11)Test hanger seals. 12)Run plug to XN nipple at 9010'. Pressure up and set all five hydraulic packers according to Tripoint recommendations. 13)Test annulus to 2500 psi for 30 minutes on chart. 14)Set BPV. 15)Nipple Down BOPs. 16)Nipple up Tree and test to 5000 psi. 17)Rig up and test flowlines 18)Recover BPV 19)Recover Plug from XN nipple 20)Rig up slick line. Test lubricator to 4500 psi. 21)Swab well to have 1000 psi underbalance. 22)Drop bar and flow Zone 5 to Test. , 23)At completion of Zone 5 test, set plug in XN nipple at 9230' ,� /6/1 24)Open Sliding sleeve at 8150' and take Zone 4 to test. 25)Close Zone 4 sliding sleeve at 8150' and open Zone 3 Sliding sleeve at 7190'. 26)Take Zone 3 to Test 27)Repeat for Zones 1 and 2. 4 NFU 42-35 Proposed Completion ' 1/26/2015 Ii TRSSSV @+/-349' f l 2 7/8"Chemical Injection II I mandrel @+1-2517 20" L80 120'TVD 120# BTC 120'MD ,,,, Y V r� 2 7/8"6.5#L80 EUE Tubing All Sleeves Open DOWN 12 1/4"Hole I 9 5/8" L80 2,750'TVD T_ 40#SD BTC 2,920'MD Sliding Sleeve @ 5520' 11•11 Zone#1 I Proposed Perforations Tripoint Hydraulic Set Packer @ 5550' I - Sliding Sleeve @ 5580' _1 MD TVD 1 t! t� Area From To From To I� Zone 1 5,590' 5,606' 4,946' 4,967' Casing Guns '1��1,111 5,737' 5,760' 5,074' 5,093' Zone#2 Zone 2 5,974' 6,000' 5,269' 5,291' Tripoint Hydraulic Set Packer @ 5934' 6,467' 6,488' 5,676' 5,697' " Sliding Sleeve @ 5964' C Zone 3 7,200' 7,220' 6,317' 6,336' " Zone 4 8,160' 8,178' 7,240' 7,258' " +I i 8,898' 8,914' 7,977' 7,993' " Zone#3 Zone 5 9,296' 9,300' 8,375' 8,379' thru tbg Tripoint Hydraulic Set Packer @ 7160' a 9,502' 9,518' 8,581' 8,597' TCP Sliding Sleeve @ 7190' DI El 9,527' 9,541' 8,606' 8,620' TCP 9,808' 9,816' 8,886' 8,894' thru tbg 9,894' 9,896' 8,972' 8,974' thru tbg Zone#4 Tripoint Hydraulic Set Packer @ 8120' - Sliding Sleeve @ 8150' _ Zone#5 Tripoint Hydraulic Set Packer @ 8950' X Nipple @ 8980' : : 0 8 3/4"hole XN Nipple @ 9010' j '!1U 7"L80 26#GeoCon TD 9,046'TVD 9,968'MD 9,960'MD 8,359'TVD , Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 42 35 Requirements of 20 AAC 25.005(D Well Summary Current Status: Well has been drilled to TD and 7" production casing is being run. Scope of Work: • Wireline perforate and run a multi-zone single selctive completion. General Well Information: / Reservoir Pressure/TVD: 4192 psi @ 9, 0 TVD MASP: 3,705 p Wellhead Type/Pressure Rating: 11" ultibowl 5K Wellhead Well Type: s Well Estimated Start Date: January 23, 2015 Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Courtney Rust (907) 433-3809 Courtney.rust@CookInlet.net Production M. ager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 2 Cook Inlet Energy_ NFU 42-35 Completion Procedure //// The 7" casing top plug will be displaced with 4% filtered KCL brine (+ - 8.6 ppg) 1) Lay down 5" drill pipe. 2) Make 6" gauge ring run to bottom on slick line. 3) Rig up Schlumberger Electric line 4) Run CBL. Send to engineering ASAP. If bad, a squeeze procedure will be prepared. 5) Perforate the following intervals with 4 '/2" PowerJet 4505 Pure Casing Guns at 3 '/2" SPF. MD TVD Area From To From To Zone 5 9,894' 9,896' 8,972' 8,974' thru tbg 9,808' 9,816' 8,886' 8,894' thru t bg 9,500' 9,506' 87579' 8,585' TCP 9,480' 9,490' J,559' 8,569' TCP 9,296' 9,300' 8,375' 8,379' thru tbg Zone 4 8,896' 8,910' 7,975' 7,989' Casing Guns 8,258' 8,264' 7,338' 7,344' 8,170' 8,1,76' 7,250' 7,256' Zone 3 7,204' 7414' 6,321' 6,330' 6,950' ,956' 6,089' 6,094' 6,470' 6,490' 5,678' 5,695' Zone 2 6,406' 6,410' 5,625' 5,629' 6,276' 6,282' 5,519' 5,524' " 5,980' 6,000' 5,274' 5,291' 5,860' 5,880' 5,175' 5,192' Zone 1 5,737' 5,760' 5,074' 5,093' 5,598' 5,606' 4,960' 4,967' 5,160' - 5,170' - 4,601' 4,609' " 6) Run 6.1"Gauge Ring and Junk Basket (clear perfs for packers) 3 Cook Inlet Energy_ 7) Pick up Schlumberger TCP assembly to perforate from 9502' to 9518'. a. Mule shoe b. 4 '/2"" TCP guns 6 spf for following intervals i. 9502' to 9518' c. TCP Drop Bar firing head without delay at 9260' d. 2 7/8" XN nipple at 9230' e. 2 7/8" X nipple at 9200' f. Tripoint 7" Hydraulic Packer at 9,170' g. 2 7/8"tubing to 2 7/8" Sliding sleeve (closed) at 8160' h. Tripoint 7" Hydraulic Packer at 8130' i. 2 7/8"tubing to Sliding sleeve at 6460' j. Tripoint 7"Hydraulic Packer at 6430' k. 2 7/8"tubing to 2 7/8" Sliding sleeve(closed) at 5850' 1. Tripoint 7" Hydraulic Packer at 5820' m. 2 7/8"tubing to 2 7/8" Sliding sleeve (clos d) at 5150' n. Tripoint 7" Hydraulic Packer at 5120' o. 2 7/8"tubing to Sliding sleeve (closed)at 5090' p. 2 7/8"tubing to chemical injection mandrel at 2500' q. 2 7/8"tubing to Tubing Retrievable SSSV at 350'. r. Vetco 11"x 2 7/8"tubing hanger 8) Rig up eLine and run GR CCL correl ion log 9) Space out and land hanger. 10)Confirm space out with GR/CCL 11)Test hanger seals. 12)Run plug to XN nipple at 9239'. Pressure up and set all five hydraulic packers according to Tripoint recommendations. 13)Test annulus to 2500 psi for 30 minutes on chart. 14)Set BPV. 15)Nipple Down BOPs. 16)Nipple up Tree and test to 5000 psi. 17)Rig up and test flowlines 18)Recover BPV 19)Recover Plug from XN nipple 20)Rig up slick line. Test lubricator to 4500 psi. 21)Swab well to have 1000 psi underbalance. 22)Drop bar and/flow Zone 5 to Test. 23)At completj''O"n of Zone 5 test, set plug in XN nipple at 9230' 24)Open Sliding sleeve at 8160' and take Zone 4 to test. 25)Close Zone 4 sliding sleeve at 8160' and open Zone 3 Sliding sleeve at 6460'. 26)Take Zone 3 to Test 27)Repeat for Zones 1 and 2. 4 ± NFU 42-35 rroposed Completion 1/23/2015 ' [ . TRSSSV @+/-349' (I 2 7/8"Chemical Injection LL mandrel @+/-2517' 20" L80 120'TVD 120# BTC 120'MD • • 2 7/8"6.5#L80 EUE Tubing �..,r.. • 12 1/4"Hole .. ' 9 5/8" L80 2,750'TVD i Ea- Sliding - 40#SD BTC 2,920'MD Sliding Sleeve @ 5090' UR Zone#1 Proposed Perforations , il Tripoint Hydraulic Set Packer @ 5120' I MD TVD Sliding Sleeve @ 5150' _ Area From To From To 1� _ Zone 1 5,737' • 5,760' 5,074' 5,093' Casing Guns 5,598' 5,606' 4,960' 4,967' i l 5,160' ' 5,170' • 4,601' 4,609' " Zone#2Zone 2 6,406' 6,410' 5,625' 5,629' Tripoint Hydraulic Set Packer @ 5820' 6,276' 6,282' 5,519' 5,524' " Sliding Sleeve @ 5850' 5,980' 6,000' 5,274' 5,291' " • 5,860' 5,880' 5,175' 5,192' " Zone#3 I Zone 3 7,204' 7,214' 6,321' 6,330' t 6,950' 6,956' 6,089' 6,094' " Tripoint Hydraulic Set Packer @ 6430' - 6,470' 6,490' 5,678' 5,695' " Sliding Sleeve @ 6460' - I L- Zone 4 8,896' 8,910' 7,975' 7,989' " L. I i 8,258' 8,264' 7,338' 7,344' Zone#4 8,170' 8,176' 7,250' 7,256' " Zone 5 9,894'' 9,896' ' 8,972' 8,974' thru tbg Tripoint Hydraulic Set Pa er @ 8130' 'I 9,808' 9,816' 8,886' 8,894' thru tbg Sliding Sleeve @ 816 9,500' 9,506' 8.579' 8,585' TCP 9,480' 9,490' 8,559' 8,569' TCP Zone#5 ,1 9,296' 9,300' 8,375' 8,379' thru tbg Tripoint Hydraulic Set Packer @ 9170' X Nipple @ 9200' 1 `-� 8 3/4"hole XN Nipple @ 9230 7"L80 26#GeoCon TD 9,046'TVD 9,968'MD j { 9,960'MD 8,359'TVD Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Monday,January 26, 2015 9:00 AM To: 'Conrad Perry' Cc: Tyler Wagner;Courtney Rust; Stephen Ratcliff Subject: RE: NFU 42-35 PTD 214-170 Conrad, I will just update the current sundry with the new pages.. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226 or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry@cookinlet.net] Sent: Monday,January 26, 2015 6:30 AM To: Schwartz, Guy L(DOA) Cc: Tyler Wagner; Courtney Rust; Stephen Ratcliff Subject: RE: NFU 42-35 PTD 214-170 Guy, We have revised the perforations and space out of the completion jewelry on NFU 42-35. Procedure has stayed the same. Do you want a new sundry app or just replace the relevant sheets? No problem either way. We are just picking up BHA for the cleanout this morning. So completion not expected until Wednesday now. conrad 1 Roby, David S (DOA) From: Roby, David S (DOA) Sent: Monday,January 26, 2015 8:24 AM To: 'Courtney Rust' Subject: RE: Sundry application for North Fork Unit 42-35 well (PTD 214-170) Thank you. Dave Roby (907) 793-1232 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 Dave Roby at (907)793-1232 or dave.robyaalaska.aov. From: Courtney Rust [mailto:Courtney.RustOcookinlet.net] Sent: Saturday,January 24, 2015 2:42 AM To: Roby, David S (DOA) Subject: Re: Sundry application for North Fork Unit 42-35 well (PTD 214-170) David, Our intent is to take it to production,we would only flare in the event we can't take it through the production facility. But yes,your assumptions are correct. We would allow time to clean up the perfs,so it would allow for several days for each zone. The answer to your last question is yes,but only with more information from the flow test,specifically pressure data. We will work with you to provide the information and let you know if we see signs that could lead to cross flow. Sorry for the delay in response, I was flying all day.. Courtney Rust On Jan 23,2015, at 4:53 PM, Roby, David S(DOA)<dave.roby@alaska.gov>wrote: Courtney, A few quick questions about the flaring authorization you requested for this well. You requested authorization for flaring for up to 14 days. Is the request for 14 calendar days,or 14 days of actual flaring? Looking at the sundry procedures it shows you testing each zone individual. I assume your plan is to flow each zone until it cleans up and you can get an accurate flow test of the formation and you anticipate that on average it will take about 3 days to do this per zone and that's where the 14 day request came from. Is my assumption correct? 1 • Finally,the proposed procedure only shows testing of individual zones. Is mere any possibility that you'd open multiple zones up for testing at the same time after testing all of the zones individually? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dove robyaalaska.gov. 2 Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Wednesday, December 31,2014 11:58 AM To: 'Evan.Harness@cookinlet.net' Cc: 'Regg,James B (DOA) (jim.regg@alaska.gov)' Subject: FW: NFU #42-35 PTD#214170/Forgot Attachement Attachments: 12-31-14 Diverter Line Layout.pdf;ATT00001.htm Evan, Jim and I have reviewed the new diverter line layout you propose below. Previous operators have also used an shallow upturn to direct line away from roadbed in the past. It appears to satisfy requirements of the 20 AAC 25.035(c) .. we will have an inspector out to look over the layout and witness the function testing when you are ready to spud. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.ciov). From: Regg, James B (DOA) Sent: Wednesday, December 31, 2014 11:08 AM To: Schwartz, Guy L(DOA) Subject: FW: NFU # 42-35 PTD# 214170/ Forgot Attachement Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Evan Harness [mailto:Evan.Harness@cookinlet.net] Sent: Wednesday, December 31, 2014 8:59 AM 1 To: Regg, James B(DOA) Cc: Courtney Rust; North ForkDSM; Stephen Ratcliff Subject: NFU # 42-35 PTD# 214170/ Forgot Attachement Mr. Regg We did additional Location work to allow Rotation of Rig Footprint-Removed some of the Subbase Wind Wall - Contacted the Burrow and secured the Road for the time Window we need We now can Lay out the Diverter Line with in Regulations with a Slight upturn on the Road end 2 NFU 42-35 PTD# 214170 -- EDGE OF R.O.W. ``NNICV1 t 1 i 1 NORTH FORK RO-___AD _ „• OF A( It/ ,`1- .40„- R� N 2121143.9950 _ (mac `)i �,0 CP-1 E 666.07 r700 *. 49Th,. I� �',i •` N21211372190 OF R.O.W _____ELEV 1 r ..,y .. .. ..... . / ----- - ELEV 656 6,0[.— EDGES - \//�f I'i i! [�l/11.Q.' r• / „+ � =.ri._---____ Tei '- �'I I' /s,TTAN A. MCLANE r r 11111M1111 •- x % pa—\ 'iPp,ESStDHa-` "1• a 1=11 m 1 ‘ 77/'‘'l Tract 18 64, des' so e. x 1 it I 1 - -_O-_ - � f i E-A/01 ®c /c 8 , Idie P' I'i 34 .26 WELL 32.35 WELL 14-26 Wel !�I o rYl ,i O m 23.26WWg.E-,. l'Illti n . */- 75 if-Rom S b eis x ----.0--- Ilia --.1 NFU 42-35 WELL ” 1453' —� N:2121128.246 I > FEL E:199958.041 1 C / •' / 10 IQ LATITUDE:5947'46.358N , JI)>I. N 0 �O LONGITUDE: 151°37'44.913"W ��. k' ��E hI�L, u ❑ NAD 27 ASP ZONE 4 •� ,y HE w ELEV.657.8'NAVD88 \ ai N V��1' , x 1) g 1 Tract 19 `, LL ,' i ). =North Fork Acres Subd. No.t o Wi—z =-- -- — z _ Qo•/ op _ p ce \ C___ _n V •-i-----..., .` \ e TOP OF BERM 0h/ W _ Wcr. AK. RN 2120505.986 S25 Section 26,TO4S, 14W,S.M., E 201396.26 — — — — _. I _I S2 S350S36 /` NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 63 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORE N OR T H BASE STATIONS'KENS','TSEA'AND'WOE OBSERVED DEC 13.2007 ON NF1 3 1?ALUM CAP SET 14 2121137.137 5:1339704.533 ELEV 656.6• 2)BASIS OF ELEVATION IS NGS BENCHMARK N66110195 ELEV 160.4 FT. WIND%DATUM 0 SCALE 200 3)SOUTHEASTCORNER SEC 26 COORDINATES DETERMINED FROM DIRECT ' I FEET , I SURVEY TIE TO THE TO EXISTING BIM SECTION CORNER TIE PER 1144111.57 AND NOT THE PROTRACTED SECTION CORNER VALUES PROJECT REVRTIO41 • NORTH FORK 42-35 WELL DM 16.21II ' AS-STAKED SURFACE LOCATION DIAGRAM 6RAMNSY sae Cook Inlet Energy_ NAD27 FOR INFORMATIONAL PURPOSES sem. 1•'110 — ONLY PROJECT NO 141135 "Ifir IS EIIGPIEERNG I MAPPING l SURVFYPIO I TEI MPIG BOOK NO - Cwuull�g Ins P O BO%IM 304110134,NC MN LOCATION =140 VOCE (107)1334211 FAX(PM sorsa SW 1/4 SE 1/4 B FST VIALB.MC`""F°Nr1A"E`G`oN S26 T4S R14W SEWARD MERIDIAN,ALASKA 1 a 1 i4,or ,Ii'I"1 ll; STATE Alaska Oil and Gas Conservation Commission"ALAS 333 West Seventh Avenue Anchorage,Alaska 99501-3572 'x (30V1..RN+)R BILI. `'sTALKI~R Main:907.279.1433 tytl� Fax:907.276.7542 L AS www.aogcc.alaska.gov Stephen F. Hennigan Consulting Project Engineer Cook Inlet Energy 3000 A Street, Suite 410 Anchorage, AK 99503 Re: North Fork Field,North Fork Undefined Gas Pool,North Fork Unit#42-35 Cook Inlet Energy Permit No: 214-170 Surface Location: 588' FSL, 1453' FEL, SEC. 26, T4S, R14W Bottomhole Location: 2573' FNL, 593' FEL, SEC. 35, T4S, R14W Dear Mr. Hennigan: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Cook Inlet Energy assumes the liability of any protest to the spacing exception that may occur. 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, P avid . ayberry Commissioner DATED this I flay of December, 2014. STATE OF ALASKA F SKAOILAND GAS CONSERVATION COMM! I ^n r Jp �`� PERMIT TO DRILL ,C 1 ���� f,"4)- �--� 20 AAC 25.005 1a.Type of Work //, 1 b Proposed Well Class. Development-Oil I J/ Service- Winj Single Zone Is! 1c.Specify �. Drill Lateral '..' Stratigraphic Test Development-Gas, `� Service-Supply Multiple Zone . Coalbed Gas Gas Hydrates Redrill Reentry I Exploratorypi Service- AG I Service-Disp Geothermal Shale Gas EI 2 Operator Name ! 5. Bond: Blanket Single Well 11.Well Name and Number: frr Cook Inlet Energy fiJ• Bond No. tr/D ‘47,.../7....i3-70 ilk/v Z46./f North Fork Unit #42-35 • 3.Address: 6.Proposed Depth. ///"` 12 Field/Pool(s): 3000 A Street,Suite 410-Anchorage AK 99503. MD 10621' ' TVD 9679'' 4a. Location of Well(Governmental Section) 7.Property Designation(Lease Number): !� North Fork . Surface • 588'FSL&1453'FEL- Sec 26 4S 14W . 4 ADL 391210/391211 (c" .'. Top of Productive Honzon Primary 8.Land Use Permit: / 13 Approximate Spud Date. 2573 FNL&593'FEL Sec 35 4S 14W 4 LOCI 10-004 20-Oct-14 ' Total Depth: 9.Acres in Property: 14 Distance to Nearest Property,Lease/Se( 2573 FNL&593 FEL Sec 35 4S 14W 4 1920.00 588 646 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elev above MSL . 679 feet 15 Distance to Nearest Well Open Surface' x- 199,958 Y- 2,121,128 Zone- 4 GL Elev above MSL 4,75-J/ry r�r feet o Same Pool: 1821'NFU 32-35 /v-z:Ai 16 Deviated wells. Kickoff depth: 11000 feet 17 Maximum Anticipated Pressures in see 20 AAC 5 035) Maximum Hole Angle t36 degrees Downhole. 4530 ' Surface. 3562 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) Driven 16 1/2 N80HC Welded R3 0 0 120 120 'Dnven • R3 0 0 na 12 1/4 9 5/8 - 40 N/L 80 SP DRFT BTC R3 0 0 2881 • 2750 . Osx Lead @ Oppg+790sx Tail @ 12ppg 8 3/4 7 26 N/L 80 BTC-M R3 0 0 10621 , 9679 • 540sx Lead @ 13 5ppg+370sx Tail @ 15 8ppg R3 0 0 na R3 0 0 na 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft). Plugs(measured). Effect.Depth MD(ft) Effect Depth ND(ft) Junk(measured). Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner 1 Perforation Depth MD(ft): Perforation Depth ND(ft). BOP Sketch pi Drilling Program Time v.Depth Plot Shallow Hazard Analysi! 20 Attachments Property Plat El Diverter Sketch Seabed Report N Drilling Fluid Program M20 AAC 25.050 requirement, , 21 Verbal Approval Commission Representative: Date 10/13/14 22. I hereby certify that the foregoing is true and correct Stephen Hennigan 337 849-5345 Contact Email shennigan@peilnc.com Pnnted Name / //s Stephen F.Hennigan Title Consulting Project Engineer for Cook Inlet Energy „r' T 4 Signature eor-.► /m—Phone (337)849-5345 Date 10/13/14 Commission Use Only Permit to Drill , / .' API Number r, 'Permit Approval See cover letter for other Number: �/`'7` / 7v 50- Z31- Z-C- J4&--«✓-'-ice Date. ONW VI' 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 shale✓' Other: 44 L(°°6 r 5` i o 1 /e ./� Samples req'd: Y Mud log req'd.Yr— V-7,'" / I ] HZS measures: Y Directional svy req'd Yd.7../.1. -)17 J., Sc r / S LL Spacing exception req'd Y Inclination-only svy req'd.VIf t✓ ��iJe_t^ 3"- Lam'et�L'-e! ���iu.t..�( re '"moi/ APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date. P.,)11 h 9 7/ ORIGINAL ,/,--- (6(2'0/ty Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Cook Inlet Energy_ ED RECEIV OCT 13 2014 October 13, 2014 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for Permit to Drill—Cook Inlet Energy, LLC —NFU#42-35 Dear Ms. Foerster, Cook Inlet Energy, LLC (CIE) hereby applies for a Permit to Drill an onshore gas DELINEATION well near Anchor Point on the Kenai Peninsula. CIE plans to spud the well in October, 2014. This is the same well that Armstrong Cook Inlet, LLC had obtained a spacing exception for (co662) and the PTD. CIE plans on using the CIE Rig 37 (Glacier) for the drilling of this well. If the well test results are sufficiently encouraging, the well will be placed on long- term production. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: • Form 10-401 Application for Permit to Drill • Spacing Exception • Plats showing the surface location of the well • Aerial map • Proposed Wellbore Diagram • Plan Plot • Drilling Time vs. Depth Plot • Program Details with calculations • Cementing Program Summary • Directional Plans • Drilling Operations Plan • Wellhead diagram • Diagrams and Descriptions of the BOP Equipment to be used • Proposed Solids handling • List of Variances 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Page 2 Other information is included as well. CIE is however requesting a variance for diverter utilization and is addressed in the permit package Following are CIE's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) - Stephen Hennigan, (337)-849-5345 2) Geologic Data and Logs (20 AAC 25.071)—Greg Kirkland, If you have any questions or require additional information, please contact me or Stephen Hennigan at(337)- 849-5345. Thank you. Sincerely, Conrad Perry Drilling Manager Cook Inlet Energy, LLC Enclosures Cc: file Stephen Hennigan—Petroleum Engineers for AAO and CIE 2IPage Cook Inlet Energy List of Variances for Drilling A variance to the following is requested. 20AAC 25.035. Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements (c) Except as provided in (d) and (h) of this section, a high capacity flow diverter system must be installed to provide safety for personnel and equipment before rotary rig drilling is performed below a well's structural or conductor casing, unless the casing is equipped with BOPE conforming with (e) of this section. The following provisions apply to a diverter system: (1) the diverter system must consist of a remotely operated annular pack-off device, a full-opening vent line valve,and a diverter vent line with a diameter (A)of at least 16 inches, unless a smaller diameter is approved by the commission to account for smaller hole size,geological conditions,rig layout,or surface facility constraints; and (B)at least as large as the diameter of the hole to be drilled, unless a pilot hole with a diameter no larger than that of the vent line is drilled first; the commission will waive the requirement of this paragraph if the operator demonstrates, based on drilling experience in the near vicinity, that drilling a pilot hole would not be necessary for safety; (2)the diverter system must be assembled as follows: (A) the diverter vent line outlet must be located below the annular pack-off, either as an integral part of the annular pack-off device or as a vent-line outlet spool immediately below it; (B) the actuating mechanism for the vent line valve must be integrated with the actuating mechanism for the annular pack-off device in a fail-safe manner so that the vent line valve automatically opens before full closure of the annular pack-off; (C)the vent line must extend to a point at least 75 feet (i)away from a potential source of ignition; and (ii) beyond the drill rig substructure, or to a point within the reserve pit and at least 50 feet beyond the drill rig substructure; (D) the vent line must be as straight as possible,secured to prevent movement, and designed to avoid freeze- up; (E) the vent line may be secured to the rig and with portable cradle supports, but may not be attached to flowlines,cable trays,or other processing equipment; (F)all turns with a bend radius less than 20 times the inside diameter of the vent line must be targeted; (C)all valves must be full-opening; (3)a clearly marked "warning zone" must be established on each side and ahead of the vent line tip, and the following restrictions must be in effect within the warning zone, beginning with the function test of the diverter system immediately before drilling operations begin and ending with diverter system rig-down: (A)a prohibition on vehicle parking; (B)a prohibition on ignition sources or running equipment; (C)a prohibition on staged equipment or materials; (D)the restriction of traffic to essential foot or vehicle traffic only; (4) the commission will, in its discretion, inspect the diverter system for compliance with the requirements of this subsection and require the operator to test the system to ensure proper operation. (d) If the formation competence at the structural casing setting depth is not adequate to permit use of a diverter system while drilling the conductor hole,a program that provides for safety in that drilling operation must be described and submitted to the commission for approval. This program must be supported by pertinent information including seismic and geologic data, water depth, drilling fluid hydrostatic pressure, and a contingency plan for moving off location. 0 A variance to the requirement of utilizing a diverter is requested. Numerous wells have been drilled on the pad to surface casing depth of±2750'TVD. No incidences have occurred. This well is on the easterly end of the southerly row. There is no production equipment,wells or structures including homes east or south of the proposed surface location of the well. The variance is requested because "drilling experience in the near vicinity indicates that a diverter system is not necessary". Authority (h)Upon request of the operator,the commission will, in its discretion,approve a variance (1) from the BOPE requirements in (e)of this section if the variance provides at least an equally effective means of well control;and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. 20 AAC 25.037. Well control requirements for other drilling and completion operations For drilling and completion operations for which the provisions of 20 AAC 25.033, 20 AAC 25.035, or 20 AAC 25.036 would not be practical or appropriate, the commission will approve alternate well control procedures and equipment if the procedures and equipment are adequate to maintain well control. It is requested that the suggested variances and exceptions noted above be reviewed and determined to be more than adequate as per this section. 20 AAC 25.050. Wellbore surveys (2) surveyed to determine the inclination from vertical with surveys starting at 500 feet and no more than 500 feet apart to total depth; and .... `` // G4.i,ty/ile.:.t 7. -VVI ;4 A variance is requested that all surveys prior to total depth be exempted and replace with survey from total depth to surface performed on eline. „,m.:,,2,-frp*--Ae kt, e •e- ✓llic c' cct z, i -er- utty, Authority i Jo•u*i, tc/ - (h) Upon application, the commission will, in its discretion, waive all or part of the directional survey requirements of this section or approve alternate means for determining the location of a wellbore if the variance at least equally ensures accurate surveying of the wellbore to prevent ,A ,t* well intersection, to comply with spacing requirements, and to ensure protection of correlative 12 \ rights. to 7/1,....., 20 AAC 25.061. Well site surveys (a) For an exploratory or stratigraphic test well, near surface strata to a depth of 2,000 feet in the vicinity of the well must be evaluated seismically by common depth point refraction or reflection profile analysis, or by another method approved by the commission, to identify anomalous velocity variations indicative of potential shallow gas sources. Analysis results must be included with the application for the Permit to Drill (Form 10-401). A variance to this requirement is requested based upon the following re soning: ,/ . iArets2 ,(.`1c�+�c ,K C..—�"iS r 5 �= (see separate documentation) �,� �4-- ex,.e,/1'cit-:/1e�,�pr,,,,, .�X-/��� I /s .�:/- c�4 • . J (c) Upon request by the operator, the commission will, in its discretion, waive-The reepairements l' of this section if the operator can identify, by other equally effective means, the likelihood of encountering potential shallow gas or seabed hazards or if the commission already has information that substantiates the presence or absence of shallow gas or seabed hazards. Authority: AS 31.05.030 40 EDGE OF R.O.W. ROAD •``�%XXIX‘i ' \ NORTH FORK _ of a Il N 2121143.9950 CP-2XP II oo RAN E 1340068.0700 — �' .- . CP-1 ELFV 866.07' ,� * 49 T H �� '. N 21211379 . . . — � / • E 1339704.6100 EDGE OF R.O.W• — \', � ELEV 656.1).81.._ . - -- ' i / - '`ai, o .,_ 41-11-"'4:1__ tit) �, �, STAN A. McLANE .�� _ 63' �x_�' I s '. 4637—S0 Ito (r.-----_-,---- �� I ``'PF ' .10/3/14 . e� �X mI, O pR•o.• �P�p `X ' i ) O �� 1'' FESS I ONO' ``� Tu m V- ��� Tract 18 6LS o GCr ATE' W ❑ I MEII - 00 El u o 34-26 WELL 32-35 WELL 14-25 WELL C� m 23-25 WELL ulmII x x NFU 42-35 WELL f _ 0 N:2121128.246 ) .( > FEL E:199958.041 LATITUDE: 59°47'46.358"NEl LONGITUDE: 151°37'44.913"W ❑ NAD27ASPZONE4 ,HE W I ELEV. 657.8'NAVD88 Q X Tract 19 LL 1 o `—= =North Fork Acres Subd. No. 1 co i X — 0 s 6 _ _ I Q -,--,------- �T...., IIIIIIIIIhhhh._.__. K,� 1 0 o �� "" bb WIOFBERMj) lekb i 1 0 CO is w I 1 I N 2120505.98 _ Section 26,TO4S,RI4W,S.M.,AK. — — I — E 201396.26 S26 S25 — S35 S36 t. NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N OR T H BASE STATIONS"KENS", TSEA"AND"KOD5"OBSERVED DEC.13,2007 ON _ NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' i oIII(U(IIIIII w:..11 111 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. D 100 200 SCALE 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT I I I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 IAND NOT THE PROTRACTED SECTION CORNER VALUES. FEET \ / PROJECT REVISION: - NORTH FORK 42-35 WELL DAT: 114 AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY. BOB Cook Inlet Energy_ ,/NAD27 FOR INFORMATIONAL PURPOSES SCALE: 1•=100• ONLY PROJECT NO. 143135 AENGINEERINGIMAPPING/SURVEYING/TESTING BOOK NO. - G'onsu�}ing Inc P.O.BOX 468 SOLDOTNA AK.99669 LOCATION VOICE:(907)283218 FAX:(907)283-3265 SW 1/4 SE 1/4 SHEET EMAIL:SAMCLANEGMCLANECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA 1 OF 1 to EDGE OF O.W• ROAD ���,kyvk i,%11 NORTH FORK — OF A4 �s yo ` — — �— 100' R� N 2121143.9950 �CP-2 Mar�P �) •�y,/I • CP-1 E 1340068.0700 * 49 TH /\ N 2121137.2190 ELEV 666;OT /_ • E 1339704.6100 EDGE OF R.O.W•— \ C _ECFV 656.6°' i / /`i i����' i / • - C .- ,w_ OHF— O2OHE— OHF- 7 01 A / g � � 6 ____ 4/ � �, .STAN A. McLANE : ,� � 5 �/ >,•._ 4637—S if/(1 ESSIONA� �`re P .11 p � NI- � N W�� Tract 18ssSATE✓ "II-\ 34-26 WELL 32-35 WELL 14-25 WELL 23-25 WELL II' 0 co x x j / J 1453' NFU 42-35 WELL FEL ea— N:2120883.406 t'1 I° ,i ' E:1339983.463 TA LATITUDE: 59°47'44.156"N ii LONGITUDE: 151°37'52.681"W NAD 83 ASP ZONE 4 J k,,, 'HE— Q x ELEV. 657.8' NAVD88 v =, Tract 19 �" CO L----Ei North Fork Acres Sub . No. 2 0 0 x x xv � \ X — i z _ --° _—SSS _ % '_�., 1_� < v ,rn I o O bos - - c\ b b J blO V )---..' \ b TOP OF BERM , UIL 4a. I 1 ‹- i w N 2120261.15 _ Section 26,TO4S,R14W,S.M.,AK. _ --I■ — I —I — E 1341421.67 S26 S25 S35 S36 NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS NORTH BASE STATIONS"KENS','TSEA'AND'KOD5' OBSERVED DEC.13,2007 ON 1. NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' 1 Il ISI,"u1 II. 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. 0N SCAL00 E ALE 3)SOUTHEAST4CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT I i I I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 IFEET AND NOT THE PROTRACTED SECTION CORNER VALUES. PROJECT REVISION: - NORTH FORK 42-35 WELL DATE: 10/3/14 Cook Inlet Energy_ AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BGB NAD83 SCALE: 1•=100' PROJECT NO. 143135 AENGINEERING/MAPPING/SURVEYING/TESTING — BOOK NO. - ConwLting Inc P.O.Box 468 soLDOTNA,AK99669 VOICE:(907)283-4218 FAX:(90712833266 SW 1/4 SE 1/4 SHEET EMAIL:BAMDLANE4$MCLANECG.CDM LOCATION S26 T4S R14W SEWARD MERIDIAN,ALASKA OF 1 Al xn: 198800 . , . . 1 , Feet 19400 i It i 1 - 2128700 2128700-22 28 24 J - 2123700 2123700- )7 11 23-25 25 34-26 -- /NFU-24-26 ,, 14-25,, Co, 1-35 - • y32-3 C - 211e700 2118700- 22-35 =4 -4t. 3 NFU 2-35 ,NFU 31-3 _ 44 - 2113700 2113700- 3 2 1 - 2108700 2108700- Scale=1:32029 memo mom wimmem 2000 3000 10 1 194 199800 204800 Al o� 04S01416J 045013W 1F 15 38 1' 14 21 22 2 20 15 2r v 0 N o N North 27 29 26 38 Fork" Unit 35 Sa 3, 31 r + i2 f 1 6 .i.• /MUM*. O o S 1. 11 12 7 055014.6 055013W North Fork Unit '▪ ,•I kvlin•Rommel "`r` 113 North Fork Unit BoundaryLeased State Tracts =° Cook Inlet Regionmewl Gas Pool#1 PA Section Grid s:.• w«"'"woos i 0.1 0.5 1 mo =*w'"" woos Township Gnd I i t 1 1 1 1 Miles '"d• 0,0 ." S.;\14140 ao Local= Nt ,no EDGE of R.a.w—H FORK READ — �••%c O F A`� II '. .• qs _ — — - CP-2 P `/L 10 1 0 oo Rr� N 2121143.9950 (��•' �' ••'9 I, CP-1 E,340066.0700 au. * 49 Ill 1 .•* • \ ELEV BBB.OT N 2121137.2190 1'.. • E 1339704• .6100 EDGE OF R•Q•W•, \41/4 - �`` - ELEV 856f$— �� _:- _ '�zdial �` .STAN A. McLANE i 65' –POST hob, ,� s 4637-S f �`� .__- '--"' ,�, '•.10/7/14.. ' X CO RED A O m It 1P'AESS I o1+n;.- :/ / a 656 CONEX / CO� � ❑ ELE.•ANEW BL �,. %�%�� (ANTENNA � w COVERED 6�� Tract 18 6s'9� o o��� � ELE.PANEL x� ii‘ �H9 — / R VAULT VAULT VAULT BLDG U/ .23-25 WELL �r ISI I 34-26 WELL 32-35 WELL 14-25 WELL , J BLDG 0 4.�0 IIS BLDG / PW � çH4? 7LrTNK NFU24-26WELLID 11 / Ki GARBAGE 0GVe � „ I0 SKID , •� HE II x �� METER NFU '2-35 WELL I I COVERED BLDG. Tract 19 i' ELE�PANEL 0 North Fork Acres Subd. No 2 co X X X . x co css� r,;; NO ) P \ -' b LL ). TOP OF BERM U „, w I I (.---IN (f- NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS N O R TH BASE STATIONS"KENS","TSEA"AND"KOD5"OBSERVED DEC.13,2007 ON NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' _( 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. SCALE 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0 100 200 SURVEY TIE TO THE TO EXISTING ELM SECTION CORNER TIE PER HM91-57 FEET (, PROJECT \ REVISION: _ L, NORTH FORK 42-35 WELL DATE: 10/7/14 Cook Inlet Energy_ RIG 37 LAYOUT DRAWN BY: BGB ^,,. SCALE: 1'=100' PROJECT NO. 143135 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. - it, ConwLting Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(9071 283.4218 FAX:(907)283-3265 SW 1/4 SE 1/4 SHEET EMAIL:SAMCLANE©MCLANECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA OF 1 co 0 0 LL i 9 O _� Z. t)e'��d '� (� 1111110 Tho Er 0 0 v � 0) f6 4101 � E �d Y .n y4'4� I Cook Inlet Energy 0 North 1-ork Unit #42-35 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.:214??? PAIN. PP MW FG Comments/ CSG TOPS/ DIR. (ppg or ppga) EVALUATION MD/TVD TOC Csg Dem. CASING&HOLE SIZE USDW:' Est Rkb 20' Air Gap • 0' • Wtr.Depth 8.3 8.6 9.8 100'pen 120' 0.S#N8OHC Welded Dflve St a.> 16 " ROP/Gas log Cond/Drive to TD. 9.0 16.0 GR,Res 2881' 40#N/L 80SPDRFT BTC 12 1/4" mien► irr 2750' 9 5/8" 2750' Casing 1 5409' 5300SD 5941' Begin Srop 5979' 6000SD Tgt Est TUC—4000'MD • 6119' 6100SD 6659' 670080 7379' End of Drop/Tgt 1 7379' Vertical 7909' 7800SD Mud Logging: Manned: 2 sx/50'0-2000',2 sx/10'2000'-TD.iii 3i: 7969' 79505D • 8004' 800050 8104' 8150SD 8469' 850050 9.0 9.6 16.5 GR,Res 10621' :N 26#N/L 80 BTC-M 8 3/4" iii► rr 9279' 9200SD 9679' BC/UR/HO 7 7 " 9679' Casing 2 9679' TD CD CO 0 - o N NO- 4:0N NOQ 1 N- in C as co 'If LLCd c� LL1 172 0 ,n LL / o Z o a� CI / a 0 2 / CL o L Z , CCI � • a) CO i- a) CI o CN - 0 0 # CO 2 Is o •°) ca 0 0 Wo0 CO 0 -`111181.1"...e."..2011"1"60- 0 �r o a v o Co Nas" N N N N M C � O N N N Cn vD Co s' T 0 '- c„, CD © 0 CD G Q C r, OM O o.o O Of o i, oaOmRoW coo o . h 0 2O 0 -_I 1 1 ' ► - M 'c W To i I Y L Ll t O 0 O C z o Q of w ^ C "N ,6 - O S 0 O O c W _p i c o :0000•••••••••000 C 8 111-1 CH.N - T--+— -lie • CD CD CD CD CD 0 CD CD CD CD CD CD CD CD CD CD CD 0 CD CD CD CD CD CD o 0 CD CD CD CD CD CD CD CD N- N CO - 4a/u.) (o r- co O) CD N- 4J g4daa Cook Inlet Energy 0 North Fork Unit #42-35 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.:214??? 588'FSL&1453'FEL Sec 26 4S 14W 2617'FNL&646'FEL Sec 35 4S 14W Sand Tops/Significant Markers Objectives Type TVD EMW COMMENTS Casing 1 _ __2750_ 8.4 53005D __5409__ 8.6 _ Begin&op_ _ _59418.8 600050 Tgt — _5979__ 8.8 61005D _6119__ 8.8 67005D _ __6659__ 8.8 End of Drop/Tgt 1 __7379_ 8.8 Vertical __7379__ 8.8 78005D __7909_ 8.9 7950SD __7969__ 8.9 80005D __8004__ 8.9 81505D __8104__ 9 850050 __8469__ 9 92005D __9279__ 9 Casing 2 __9679_ 9 TD 9679 9 Directional Program: Directional Per program TVD VS Opn(s) 0 0 0 Lithology 1000 0 KO @ 3°/100, Samples: 165.87AZ 2 sx/50'0-2000',2 sx/10'2000'-TD 2653 525 EOB,Hold 2750 594 Surf Casing Directional Survey: 5409 2473 5300SD 5941 2849 EOT,Begin Per regulatory and directional requirements. Drop 5979 2875 6000SD 6119 2963 . 610USD 6659 3199 670USD 7379 3305 End of Drop/Tgt 1 7379 3305 Vertical Logging Program: Lwd OH OH Possible Cased Hole Mudio9ging Surface GR,Res ' none CBL Full Svc resistivity,GR, t- Prod GR,Res ` SP,Density, High res CBL Full Svc Neutron and LSS 0 0 Cook Inlet Energy 0 North Fork Unit#42-35 Block/Sec 26 4S 14W North Fork 0 Mud Logging: Unmanned: ROP/Gas log Cond/Drive to TD. Manned: 2 sx/50'0-2000',2 sx/10'2000'-TO �r �� Mud Program: AV Interval(TVD) Mud Weight(ppg) - �G}-From To From To j Mud Type 0 8.8 2750 9 spud 2,750 9679 9 9.6 wbm Casing Program: Measured Depth Connection CMTD Est No. Hole Size Casing Size From To Wt lb/ft Grade Type with TOC Centralizers Drive/Structural Driven 16 0 120 1/2"wall N8OHC Welded none NA none NO Conductor Surface 12.25 9.625 0 2881 40.00 N/L 80 SP DRF1 BTC 790 0 16 Prod 8.75 7 0 10621 26.00 N/L 80 BTC-M 910 4,000 69 General Drilling Prognosis: 1 Prep location. MIRU. Conform to ALL regulations. Drive conductor,etc. Perform spud mtg. 2 PU LWD BHA. Clean out drive/conductor.Drill slowly until stabilizers exited. 3 Incr RPM and flow rate. Be prepared for losses. Drill. 4 Nudge and KO. Drill to surface casing point. Condition hole. 5 Run surf csg and cmt. NU BOPe. Test. 6 PU BHA and TIH. Drill shoe track. 7 Drill out 20'&perf LOT. Anticipate 14.2 ppge. 8 Run CBL. Displace mud. 9 PU BHA w/LWD. 10 Directionally drill to drop point.Drop. 11 Cont drill ahead. Cond mud and reduce fluid loss and treat w/LCM. 12 Correlate logs and monitor drill breaks 13 Monitor surge&swabs. Set down slowly on slips. Kick pumps on slowly. 14 Minimize ECD. (Pump wtd&LCM sweeps prior to each trip. Stage in hole carefully after each trip.) 15 Condition hole. Evaluate. 16 17 18 19 20 21 22 23 24 25 26 Run Production.Cement. Bump plug with water. Cleanout. 27 Displace with clean water. 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Time vs Depth Casing Size&Depth 0 t I I U Days vs MD---TVD vs Days Prod Csg/Inr 1,000 - 2,000 - 3,000 - 4,000 - 5,000 - 6,000 - 7,000 - 8,000 9,000 - I , 10,000 - - 11,000 - i 12,000 0 5 10 15 20 25 30 35 1 Emergency response Information L1 Directions to Location Method Directions Air Latitude: 2617 Longitude: 646 virecaons Trom Renal •Start out going north on Main St toward Highland Ave.travel 0.1 mi •Take the 2nd right onto Kenai Spur Hwy.Kenai Spur Hwy is just past Frontage Rd travel 0.7 mi •Turn right onto Bridge Access Rd.Bridge Access Rd is 0.1 miles past Spur View Dr travel 3.3 Ground •Turn right onto Kalifornsky Beach Rd.travel 16.2 mi •Turn right onto Sterling Hwy/AK-1/I-A1.Sterling Hwy is 0.2 miles past Heine Berger Ln travel 45.7 mi •Turn left onto N Fork Rd.N Fork Rd is just past Williams Way travel 8.4 mi •Turn Right on Epic rd.travel 120' •Pad on right hand side of road 35315 North Fork Road 1.2 Rig Contact Numbers(Tentative depending on rig and communications available at time of MIRU)) Rig Phone List Cell#'s Co.Manr See below Tool Pusher. Mud Engr Directional: Expediter:See below Rig Fax: CM Backup:See below TP Backup: 1.3 Emergency Response Contact Numbers Company Contact Numbers Name Position Office Cen Co Man TBD Clerk Superintendent/Opns Mgr Conrad Perry VP Operations Stephen Hennigan Proj Mgr/Engr (337)849-5345 Logistics Response Service Location Contact Phone ALL dial 911 for Homer,AK Kachemak Emergency Services (907)235-9811 Homer,AK Front desk (907)235-8121 Aerial Ambulance/Life Med Kenai/Soldotna,AK Trooper Dispatch (907)262-4453 Nikiski,AK Nikiski Fire Station 2 (907)776-6402 Fire Anchor Point,AK Station (907)235-6700 Homer,AK (907)235-3155 Hospital Homer,AK I South Peninsula I (907)235-8101 Police(Local) Homer,AK Front desk (907)283-7879 (907)235-3150 Anchor Point,AK Alaska State (907)235-8239 Alaska State Troopers Soldotna,AK Alaska State (907)283-4388 (800)478-9300 Alaska State Spill Reporting Alaska (907)269-3063 National Response Center (800)424-8802 Spill&Contamination Coast Guard (800)479-5555 AK AOGCC (907)793-1236 (907)279-1433 Spill&Contamination Mgmnt Slidell,LA Witt/O'Brien's Resource Management 24-hour emergency (985)781-0804 Operations Houston,TX Wild Well (281)784-4700 Main Single Point (866)942-6564 Prepared by Stephen F.Henniganq 10/10/14 Page 7 1.4 Company Emergency Response Name Poeelon Office Mobile Conrad Perry VP Supenntendent/Opns Mgr HSE Manager Logistics Steve Hennigan Project Mgr/Engr (337)849-5345 2 Regulatory Agency Contacts by phone or email Agency Office M-F(SAM-SPM) Contact 48 hr AOGCC (907)793-1236 Inspection Supervisor(Jim Regg) See industry Guidance 10-01 http//doa alaska gov/ogc/formgTestWitnessNotif html) AOGCC Inspectors@alaska gov See drilling prog for additional Information 3 Regulatory Compliance Regulation _ 20 AAC 25 _ BOP testing every 7 days 48 hr notice required Prepared by Stephen F.Henniganq 10/10/14 Page 8 4 Drilling Program Summary 4.1 General Well data Nano North Fork Unit N 42-35 taam/Uc 391210/11 Surface Lcn 566'FSL&1453'FEL Sec 26 4S 14W Slt/Pad Existing Pad Field North Fork Spud Deb1.0) 1020/14 KB(above MSL) 679 / County/Prov Kenai AN Ne. OL(above MSL) 659 State AK Pernik N.. Perm Datum KB Total MD 10,621 WeNOea ALL Zones WD na Total TVD 9,679 Dry Contractor CIE USDW <+-2700' Ale Name CIE Rig 37 4.2 Working Interest Owners Company Working Interest Address Primary Phone Fax Operator Cook Inlet Energy 100 00% 501 W.5th Avenue STE 310 (907)433-3816 Anchorage,AK 99601 4.3 Geologic Program Summary NAD 27 NAD 93 SHL SHL Prepared by Stephen F.Henniganq 10/10/14 Page 9 NAD 27;Alaska Zone 4 X Co-ord. Y Co-ord. Surface Location Co-ordinates 199,9511 2,121,128 Bottom Hole Location co-ordinates 200,856 2,117,904 Pore n0.-tt/t, ` Pressure Mg.d L ri ft'1 1 Targets M.D.(ft) T.V.D.(ft) X Co-ord. Y Co-ord. (PPM est I 0 0 199958 2121128 8 3 g,S Surface Casing 2881 2750 200089 2120549 8 6 _ _ Q.$_. 5300S0 6137 5409 200503 2118716 8 8 C/ p End of Tangent(S) 6789 5941 200585 2118349 8 8 Begin Drop 6789 5941 200585 2118349 8 8 6000SD 6834 5979 200591 2118324 8 8 6100SD 7000 6119 200611 2118238 8 8 6700SD 7591 6659 200663 2118008 8 8 End of Drop/Tgt 1 8321 7379 200686 2117904 8 9 Vertical 8321 7379 200686 2117904 8 9 7800SD 8851 7909 200686 2117904 8 9 7950SD 8911 7969 200686 2117904 9 0 8000SD 8946 8004 200686 2117904 9 0 8150SD 9046 8104 200686 2117904 9 0 8500SD 9411 8469 200686 2117904 9 0 9200SD 10221 9279 200686 2117904 0 0 End of Tangent,TD 10621 _ 9679 200686 2117904 0 09'6, /owiY4.4 Formation Evaluation Summary Final Hole OH-WL Other OH-WL Pilot Hole Size MD TVD (Possible) (TBD) LWD Mud Logging Cased Hole Size 120' 120' NO Conductor 0 0 0 0 0 Surface 121/4" 2661' 2760' none 0 GR,Res Full Svc CBL resisooiry,GR,SP, Prod a 3/4" 10621' 1671' Density,Neutron and 0 GR,Res LSS Full Svc High res CBL o 0 0 0 0 o 0 0 0 0 •large rotary sidewall core ▪ up to 10 in gas,20 in oil Prepared by Stephen F.Henniganq 10/10/14 Page 10 4.5 Summary of Potential Drilling Hazards Hazard Event Depth Discussion Precautions /interval Deliniation/Expoitation Well ALL Monitor all parameters for exploratory well. Balling Conductor/S Maintain high gpm/rpm to keep bit/BHA clean Perform urface additional circulating times Perform multiple conditioning trips circulating Stuck casing ALL at max rate and rpm with stiff BHA(ultra packed) Boulders/rocks/sand Surface Control penetration,add Icm,high vis sweeps Monitor for loss of rtns Possible depleted zones Intm Offset wells indicated no issues Monitor for loss of rtns and differential sticking. Discontinuity of formations minimizes potential. Monitor for connections in hole. Circulate hole High drill gas Prod Offset wells indicated no issues / clean to clear wellbore of gas before proceeding. Be sure degassing eqpmt is operating properly prior to spud. Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house._The man on the brake,duller or relief driller is responsible for shutting the well in BOPE or diverter as applicable as soon as waming signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands MAY be encountered from 330007VD to total depth of the well. These sands will run from slightly depleted to normal pressure. The drilling mud system will be properly weighted to control control the pressure of all sands and lost circulation materials will be available on location if required. Prepared by Stephen F.Henniganq 10/10/14 Page 11 4.6 Drilling Program Summary 4.6 General Summary Well Name North Fork Unit#42-35 Permit to Drill No. 214??? Location Surface: 588'FSL&1453'FEL Sec 26 4S 14W - Top of Productive Horizon:2617'FNL&646'FEL Sec 35 4S 14W Bottom Hole: 2617'FNL&646'FEL Sec 35 4S 14W Planned TD MD: 10621' . TVD: 9679' Directional Plan As per program Well Summary 't-t14 A 16"conductor will be driven/drilled to 1120'and a cellar will be constructed and installed. Using water-based mud,approxtmatety700'MD of 13- W hole will be drttled as a"nudged"straight hole prior to kicking off and drifting directionegyto the first casing point at t2750'TVD where 9 5/8" surface casing will be set and cemented to surface. Then a 8 3/4"hole will be directionally drilled to a planned TD of 11000079628'MD/TVD. If electric logs indicate zones that are encouraging, 7"production casing will be set and cemented. Then the well will be tested,completed,and then suspended for production hook-up. The entire production hole will be drilled in the Beluga and Tyonek Formations,which contain coal beds of varying thickness.The well will be drilled using PDC bits.These bits exhibit a reverse drilling break upon encountering coals,allowing time for these bits to work the coals as they distress and swell. Based upon the near offsets, gas cut mud may occur. Therefore there will be close monitoring and more circulation of mud to insure proper conditions for progressing. Based on offsetting well information,there are no special risks anticipated for this well except as previously discussed. KEY CASING DEPTHS Start Depth Seat Depth Interval Hole Size MD TVD MD TVD Drivel Structural Driven 00 120 120 NO Conductor Size Surface 12 1/4" 00 2881 2750 Prod 8 3/4" 00 10621 9679 Pore Pressure/Mud Program The well will be drilled to TD using water-base mud with a weight of 19.3-9.8 ppg in the production hole section and adjusted as necessary while drilling to TD. Mud Logging Logging Gas monitoring will be provided in the conductor/surface holes. Basic mud logging services will be provided from SPUD to TD. Services will consist of cuttings description and construction of a lithology log. The mud loggers will tie their well monitoring system into a PVT system to help monitor fluid levels and system gains/losses. Logging Program Electric logging(either LWD or/and open hole)will be performed at each casing depth. If hydrocarbons are indicated to be potentially economic, then the testing phase will begin after casing is run at TD. BOP Testing BOP testing will be conducted at least every seven days and every casing run. AOGCC Field Inspectors will be notified 48 hours in advance of spud and all diverter/BOP Tests. It will be noted on drilling report and on IADC sheet whether the test was witnessed by the AOGCC inspector or waived. Waste Disposal All solid waste,including drill cuttings,will be disposed of per regulatory. Excess mud and fluids will be disposed of as permitted. • Completion/Well Testing After the production casing/liner is run,it will be cleaned out and tested. A completion/test string and packer will be run. Each potential zone will be perfed,tested,and then isolated. Following the tests,zones will be identified for potential development. Prepared by Stephen F.Henniganq 10/10/14 Page 12 4.7 Casing program Summary Start Depth Seat Depth Seat Depth Casing Interval Hole Size MD TVD MD TVD Size Wt(Ibfft) Grade Conn Burst Collapse Tension Drive/ Driven 0 0 120 120 16 " 0.5 N60HC Welded NIA NIA Structural NO Conductor Surface 12 1/4" 0 0 2991 2750 I 518" 40 NIL SO SP DRFT BTC 5750 3090 916 Prod 9 314" 0 0 10621 9679 7 26 NIL 80 BTC-M 7240 5410 604 Buck on float equipment Q yard MU casing to optimum torque 4.8 Calculation of Maximum Anticipate Pressures(MASP and MADP) Note In this program,MASP for each hole section is defined as the pore pressure(in psi)at the next casing point(or TD)less a gas column to surface The MADP is defined as the maximum pp WITHOUT a gas gradient Gas gradient is assumed to be 0 1 psi/ft 12 1/4" Hole Section—estimated pore pressure of 8 4 ppg emw This hole section will be dolled to depth with a diverter only(no BOP's)and±8 7-9 1 ppg mw While MASP will equal the formation pore pressure at the next shoe,less a gas gradient to surface,it cannot be shut in,only diverted Calculations MASP(pp)=((PP ppge)x 052 x TVD)-(gg x ND) MASP= 2750'ND x((8 4 ppge'052)-0 1 psi/ft) 926 psi MADP=((PP ppg)x 052 x ND) MADP= 2750'ND x(8 4 ppg'0 052) 1201 psi 8 3/4" Hole Section—estimated MAXIMUM pore pressure of 9 ppg emw This hole section will be dnlled to TD with BOP's and related equipment installed and tested and with a±9 4 ppg mud weight Based on available offset information the most likely maximum pore pressure is anticipated to be<8 6 ppg EMW Calculations MASP(pp)=((PP ppge)x 052 x ND)-(gg x ND) / MASP= 9679'ND x((9 ppge*052)-0 1 psi/ft) 3562 psi MADP=((PP ppge)x 052 x ND) / MADP= 9679'ND x(9 ppg'0 052) 4530 psi Prepared by Stephen F.Henniganq 10/10/14 Page 13 4.9 Casing Design and Calculations Note: In this program,MASP for each hole section is defined as the pore pressure(in psi)at the next casing point(or TD)less a gas column to surface. Gas gradient is assumed to be 0.1 psi/ft. MADP is defined as the maximum pore pressure in the hole section.AT TIMES MASP CALCULATIONS WILL BE ADJUSTED FOR AIR GAP AND WATER DEPTH when applicable. Final Start Depth Seat Depth Casing Interval Hole Size MD ND MD TVD Size Wt(Ib/ft) Grade Conn Burst Collapse Tension Drivel Driven 0 0 120 120 16 " 0.5 N8OHC Welded N/A N/A Structural NO Conductor Surface 12 1/4" 0 0 2881 2750 9 5/8" 40 I/L 80 SP DRF BTC 5750 3090 916 Prod 8 3/4" 0 0 10621 9679 7 " 26 N/L 80 BTC-M 7240 5410 604 =minimum of body and connection strengths RECOMMENDED Casing Design Factors BURST(from internal pressure) 1.1 COLLAPSE(from external pressure) 1 TENSILE(joint body and connection)strength 1.6 BURST REQUIREMENTS 9 5/8" Surface Size 12 1/4" Hole Section—estimated pore pressure of 8.4 ppg emw This hole section will be drilled to t 2750'ND with BOP's installed/tested with a max anticipated mud wt of t 9 ppg from above MASP(pp)=((PP ppge)x.052 x ND)-(gg x ND) MASP= 2750'ND x((8.4 ppge*.052)-0.1 psi/ft) 926 psi MADP=((PP ppge)x.052 x ND) MADP= 2750'TVD x(8.4 ppg`0.052) 1201 psi MASP(fg)=((FG+SF ppg)x.052 x ND)-(gg x ND) MASP Csg Design= 2750'ND x((16ppge+.5 ppge)-0.1 psi/ft) 2086 psi Burst Stress= MASP Csg Design Is used since in case of a kick in excess of 2085 psi,shoe would break down. Design Factor Burst Strength/Burst Stress= 575012084.5 2.76 SF 7 Prod 8 3/4" Hole Section—estimated pore pressure of 9 ppg emw This hole section will be drilled to t 9679'ND with BOP's installed/tested with a max anticipated mud wt of t 9.6 ppg from above MASP(pp)=((PP ppge)x.052 x ND)-(gg x ND) MASP= 9679'ND x((9 ppge".052)-0.1 psi/ft) 3562 psi MADP=((PP ppge)x.052 x ND) MADP= 9679'ND x(9 ppg'0.052) 4530 psi Burst Stress= MASP Csg Design= TD MASP is used since this will be a production string mum from below Design Factor Burst Strength/Burst Stress= 7240/3561.872 2.03 SF Prepared by Stephen F.Henniganq 10/10/14 Page 15 COLLAPSE REQUIREMENTS Use an external pressure that the casing could possibly be put under One design methodology uses pore pressure at the casing shoe with a gas gradient internally 16 " NO Conductor 9 5/8" Surface External Pore Pressure less gas gradient MASP(pp)=((PP ppge)x 052 x TVD)-(gg x TVD) MASP= 2750'TVD x((8 4 ppge*052)-01 psi/ft) 926 psi Design Factor Collapse Rating/Collapse stress= 3090/926.2 3.34 SF 7 Prod External Pore Pressure less gas gradient MASP(pp)=((PP ppge)x 052 x ND)-(gg x ND) MASP= 9679'ND x((9 ppge*052)-0 1 psi/ft) 3562 psi Design Factor Collapse Rating/Collapse stress= 6410/3561.672 1.52 SF Prepared by Stephen F.Henmganq 10/10/14 Page 16 TENSILE REQUIREMENTS Tension is usually defined as the body or connection tensile strength(whichever is least)compared to the buoyed weight of casing in mud when run Buoyed weight is defined as weight in air minus the weight of displaced fluid that it is run in Buoyed weight formula=MD•Csg Wt(lb/ft)•(1-mw/65 45)where 65 5 is the avg wt per cu ft of iron in air 16 " NO Conductor 9 5/8" Surface Buoyed weight= pounds 2881'MD x 40 ppf•(1-9ppg/65 45) 99394 Design Factor= tensile strength/buoyed wt = 916000/99394 9.22 SF 7 Prod Buoyed weight= 10621'MD x 26 ppf•(1-9 6ppg/65 45) 236642 pounds Design Factor= tensile strength/buoyed wt= 604000/236642 2.56 SF Prepared by Stephen F.Henmganq 10/10/14 Page 17 4.10 Casing Test Pressure Calculations In this well,formation pressure is assumed to be the backup See Casing design and MAWP calculations. See discussion below BOP PROGRAM,Test Pressures and Casing Test Pressures MASP=Maximum Anticiapted Surface Pressure(psi) MHDP=Maximum Anticipated Downhole Pressure(psi)@ TD Casing Size Casing Equipment Test Pressure Low/ High 16" Structural Casing @ 120' 21-1/4" 1000 Diserter Function Test 70%of Burst WA Test Pressure' Function Test NO Conductor (1) 250/ 70%of Burst (2) 250/ Test Pressure (1) 250/ 0 MASP NA MADP NA MASP Casing Design N/A 50%of minimum internal yield NA 9.625" Surface Casing @ 2881 ' (1) 11" 5000 Annular 250/ 2500 70%of Burst 4025 (2) 11" 5000 Pipe Rams 250/ 3000— L(QCO Test Pressure' 3000 I (1) 11" 5000 Blind Rams 250/ 3000- rt DO a MASP 3562 MADP 4530 MASP Casing Design 2085 50%of minimum internal yield 2875 • 7" Production @ 10621 ' (1) 11" 5000 Annular 250/ 2500 70%of Burst 5068 Mn.(2) 11" 5000 Pipe Rams 250/ 4000 Recommended Test Pressure 4800 (1) 11" 5000 Blind Rams 250/ 4000 Test Pressure' 4000 MASP 3562 MADP 4530 MASP Casing Design 3562 50%al.minimum internal yield 3620 (1) 70%of Burst Mn.(2) Recommended Test Pressure (1) 0 Test Pressure' I • MASP N/A MADP N/A MASP Casing Design 0 50%at minimum internal yield � I BOP Test Pressures for Welltest/Completion Production (1) Annular 250/ 2500 70%of Burst of weakest csg 5068 Mn.(2) Pipe Rams 250/ 4000 Test Pressure' 4000 I (1) Blind Rams 250/ 4000 Prepared by Stephen F.Henniganq 10/10/14 Page 18 4.11 Blowout prevention Equipment Details,Testing and General Procedures SEE ATTACHED DRAWINGS Testing: Onsite supervisor will verify all pressure tests.All tests are to be recorded on the IADC and DDR reports.ALL are to be charted.AOGCC to verify BOP tests(48 hr notice) 50%of Casing Size Casing Casing Test BOPs Test Pressure Casing (In) Burst MADP(psi) MASP(psi) Test Pressure Fluid Density MINIMUM 250 psi (psi)•• (lb/gal) Size&Rating Low/high (Psi) Rams are to be variable bore to accept 5"8 4"DP,2 7/8"tbg NO Conductor 16 " NA NA NA 0 0 0 Surface 9 5/8" 2875 4,530 3,562 3000 9 (1)13 5/8'5M annular 2500 (1)13-5/8'5M pipe ram -BOOT 4 0 O (1)13-5/8'5M blind ram (1)13-5/8'5M drilling spool w/3—1/8'5M outlets (1)13-5/8'5M pipe ram Prod 7 3620 4,530 3,562 4000 9.6 (1)13 5/8'5M annular (1)13-5/8'5M pipe ram 2500 (1)13-5/8'5M blind ram 4000 (1)13-5/8'5M drilling spool w/3—1/8'5M outlets (1)13-5/8'SM pipe ram For Compltn 7 N/A N/A 4000 (1)13 5/8°5M annular same as above (1)13-5/8'5M pipe ram (1)13-5/8'5M blind ram 0 (1)13-5/8'5M drilling spool 0 w/3—1/8'5M outlets (1)13-5/8'5M pipe ram CASING TEST PRESSURE DEFINITION "Casing test pressures are based on 70%of the rated burst pressure of the casing adjusted for the mud weight used during the casing test less a 9.0 ppg backup unless otherwise noted and on the lesser value between 70%of the burst and MASP for EACH hole section. CTP=(0.7 x Internal Yield)-(0.052 x (Mud Weight-Backup Mud Weight)x ND). Liner Casing test pressure is the greater of the Expected Leak-off Test or 500 psi over the previous casing shoe test,adjusted for subsequent liner tests with heavier mud. Liner Tod Test=((Previous Frac Gradient-Current Mud Weight)x(0.052)x NDb„„ )). Liner Test=((Frac Grad-Current Mud Weight)x (.052)x TVD,;",). 4.11a The choke manifold will be rated 3 1/8"x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also on the location is a gas buster and a degasser. Flow sensors will be installed in the flowline and the mud pits will have a PVT system. All data will be available to the driller,company men and key individuals. 4.11b Function Testing: Function on each tour. Report test on daily drilling report(DDR)and IADC. Prepared by Stephen F.Henniganq 10/10/14 Page 19 4.12 Wellhead Equipment Summary Component/Description Wellhead See drawing BASEPLATE KIT24 OD X 14 ID X 1.50 THK W/6 NUMBER 1 GUSSETS,W/TWO 2-1/2 GROUT SLOTS.F/13-5/8 CSGHD HSG.WG.5H2-LWR,11 SM X 10-3/4 SOW W/ORING,W/2 2-1/16 5M FPO,6A-PU-M-1-2 CSGHGR,WGSH2,11 X 7 23.0 -26.0 LC BOX BTM X 7.375-4 ACME LH PIN TORMIN BORE 6.276,6A-PU-AA-1-2 TBGHGR.WG.T-M40-CCL11 X 2-7/8 EU BTM AND TORW/2-1/2 HBPVTHD AND TWO DHCV PORTS.4130 80K6A-LU-DO-NL-1-2 Tree 5k tree-TBD USE SPACER SPOOL(s)AS NECESSARY SEE ATTACHED DRAWING Prepared by Stephen F.Henniganq 10/10/14 Page 20 4.13 Directional Surveying Summary Downhole realtime surveying tool. Interval MD(1q MWDILWD Myr.*Multi Gyro Multi Elog Other Remarks Drive/Structural 0 120 none NO Conductor Surface 120 2881 - x Prod 2881 - 10621 • x 4.14 Directional Program Summary Surveys will be taken per AOGCC regulations. Comments MD inclination Azimuth ND Grid East Grid North DLS Build Rate Vert Sect Ea 11 [a L1 [US n] (US ft] r/100fL 2100rttJ L[ 0.00 0.00 165.87 0.00 199958.04 2121128 0 0.00 0.00 Tie On 20.80 0.00 165.87 20.80 199958.04 2121128 0 0.00 0.00 End of Tangent;KOP 1000.00 0.00 165.87 1000.00 199958.04 2121128 0 0.00 0.00 I End of Build(S) 2762.33 35.25 165.87 2653.26 200073.70 2120616 2 2.00 525.18 End of Build 2762.33 35.25 165.87 2653.26 200073.70 2120616 0 0.00 525.19 Surface Casing 2881.00 35.25 165.87 2750.00 200088.76 2120549 0 0.00 593.55 5300SD 6136.66 35.25 165.87 5409.00 200502.57 2118716 0 0.00 2472.50 End of Tangent(S) 6788.56 35.25 165.87 5941.39 200585.42 2118349 0 0.00 2848.70 Begin Drop 6788.56 3525 165.87 5941.39 200585.42 2118349 2 -2.30 2848.70 6000SD 6834.32 34.19 165.87 5979.00 200591.16 2118324 2 -2.30 2874.77 610030 6999.96 30.38 165.87 6119.00 200610.65 2118238 2 -2.30 2963.23 670030 7590.59 16.80 165.87 6659.00 200662.59 2118008 2 -2.30 3199.06 End of Drop/Tgt 1 8321.01 0.00 165.87 7379.00 200686.00 2117904 2 -2.30 3305.38 Vertical 8321.01 0.00 165.87 7379.00 200686.00 2117904 2 -2.30 3305.38 7800SD 8851.01 0.00 16587 7909.00 200686.00 2117904 0 0.00 3305.38 7950SD 8911.01 0.00 16587 7969.00 200686.00 2117904 0 0.00 3305.38 8000SD 8946.01 0.00 165.87 8004.00 200686.00 2117904 0 0.00 3305.38 81505D 9046.01 0.00 16587 8104.00 200686.00 2117904 0 0.00 3305.38 8500SD 9411.01 0.00 165.87 8469.00 200686.00 2117904 0 0.00 330538 Prepared by Stephen F.Henniganq 10/10/14 Page 21 4.15-4.16 Drilling Fluids Program Summary and Specifications TYPICAL Mud Program Overview Fluid Properties Listed Below: Depth Mud Wt Funnel PV 'Geld Point Gets pH API FL HTHP FL Chloride SLDS (MD) PpmseclO e0- E8100112 tOmime a 0.2,881' 8.8-9.2 100-200 15-28 30. 18-35 8.5-9.5 <18 ILA <_5000 <8 1 Add Gelex to sw for added viscosity. 2 Run all avail solids control equipment for maximum solids control. 3 pH ould be controlled with Caustic and/or Soda Ash 4 Add 2-5 ppb MIX II to mud system if seepage losses become a problem. 5 Maintain low gravity solid at<8%with dilution and solids control. 6 Begin adding Poly-Pac UL at 1500 for fluid loss control. • • Mud Program:Drill 8.75"hole and run 7.0"casing ,AliFluid Type:KlaShield WBM System with 6%KCL "" Fluid Properties Listed Below: Depth Mud WL Funnel PV Yield Point Gels pH API FL KIP FL Chloride SLDS 9851 Ms w dnror? 1osevlom�n on zso°F SMOL sec41 Mime cc re9A 2,881'-10,681'MD 9.0-9.6 40-50 18-26 1528 18-22 92-10.2 <5 WA 26k-32k <6 1 Drill out 9.625',casing shoe with previous mud on isolated pit.Perform FIT. 2 The should be maintained with KCI,Flowzan and PolyPac UL with sweeps as needed fa additional hole cleaning.Maintain concentrations of KlaStop for shale inhibition. 3 Prior to drilling cement,pretreat the mud system with.25 ppb Sodium Bicarbonate to minimize effects of cement contamination. 4 Maintain Asphasol and Sack Black concentrations as needed when drilling if any well bore instability is seen increase concentrations per M-I SWACO Project Manager 5 Add MIX II and sized SafeCarb(20,40,250)to the mud for seepage(<15 bph). 6 7 Run solids control equipment continuously to maintain low gravity solids below 6%. 8 Lower yield point/gel strengths prior to logging and cementing per cementers.Ensure casing has reached TD before adjusting any properties. 9 Monitor volumes for influxes and potential losses in this section. 10 4.17 Solids Control Equipment Interval Shaker Desander Desiter Mud Cleaner Centrifuge Cuttings Dryer Cuttings Zero Discharge Comments Injection '- Closed Loop System,Full 0-Total Depth 2 1 1 Containment.run shakers with finest screens possible Equipment Specifications (typical but may not be exact depending on rig) Item (quality,design type,brand,model,flow capacity,etc.) Shaker 2-SWACO Mongoose PT Desander N/A Desilter 1—Derrick Model 0522 Mud Cleaner N/A Centrifuge 1—Hutchison Hayes 5500 Cuttings Dryer N/A Cuttings Injection N/A Zero Discharge N/A Prepared by Stephen F.Henniganq 10/10/14 Page 24 4.18 Cement Program Summary(Brief vendor prog is attached) Cementing Summary MEIt #VALUEI Surface I Size: 9625 Setting Depth 2881 ft. Annular Volume(No Washout). 947 49 cu ft. Lead Slurry Density 0 ppg Yield 0 cuft./sx No.Sxs: 0 Specifications: None Desired Top of Cement N/A ft. Tail Slurry Density: 12 ppg Yield 2.3 cu.ft./sx No.Sxs-.I 790 I Specifications. 8 Hour Compressive Strength of Tail Slurry. 1000+ psi Total Volume:I 1817 'cu.ft. Desired Top of Cerrent. 0 1t. 790 Into.Prod.Casing I Size: 7 Setting Depth: 10621 ft. Annular Volume(No Washout): 994.94 cu ft Lead Slurry Density 13.5 ppg Yield: 1.83 cu.ft./sX No Sxs'. m Specifications. G Desired Top of Cement. 4000 ft. Tail Slurry Density 15.8 ppg Yield- 1.16 cu.ft./sX No.SxsMEM Specifications. G Desired Top of Cement 8621 ft. Total Volume 1417.4 Icu.ft. 8 Four Compressive Strength of Tail Slurry. 1000+ psi 910 I I I I OVAL LIP I I I MIM I I #VALUE' I I I _ I I I I #VALUE' Comments: See cement prognosis for details and spacer specifications.Actual cement volume pumped will be determined by clog caliper and other parameters. Prepared by Stephen F.Henniganq 10/10/14 Page 25 4.19 Bit Summary-ESTIMATED-SAME BIT PROGRAM AS BELOW pry, Cook Cools Iuiot Energy Inlet North Fork Well NF 24-26 1- 1112.11Liom:a _ Drilling GEOGRAPHIC LOCATION CcERATOR CCC,TPA_:OF,F=G Sank PapNtmase Eort pu A=rt6 Fork Cook Wet E..rrr filler Rig or Gerald R.Atel KeralaKeralaD.` FED AREA LOCATION WELL NUMBER North Fork NT-]4-.6 ,Y � BIT DEPTH DIST DRUG ACC MtD I No. SIZE TYPE OUT DRLD TEM" ROP TIULE WOB RPM WE DAYS RENL1R. 34, f, s tri, Lam tlpi SlDil_�� Mill 8314'QDSOSX 1 12-14 VSID-3 228'0 2S-0 2S 100 27 15-20 225 8.4 (mimeo %Nes Set 9-5/8"Cnin 2 8-3 4" QD505X 10.000 7130 -1 100 r 99 10-15 200 8.8 i Set"'IC"sin I l r 11/1 1 1 1 1 I 1 1 iiC N.ah.%(Mitt... — Prepared by Stephen F.Henniganq 10/10/14 Page 26 4.20 Casing Test,FIT,Lot procedure Perform Casing Test(CIT) -the pressure to which the casing should be tested should be 300-400 psi above the expected surface pressure needed for the leak off test.It is NOT necessary to retest to the APD casing test pressure. 1.GIH and clean out to the top of the float collar for casing test. 2.Circulate and condition mud until shaker is free of cuttings and mud weight in is within +/-0.1 ppg of weight out for several consecutive measurements. 3.Rig up,pressure test and check for leaks.Make sure air is purged from the system. 4.Pumping down the drillpipe,break circulation with cementing unit(or low vol/high press pump). 5.Close annular BOP or pipe rams. 6.Pump down drillpipe at 1/2 bpm.Do not exceed this rate and maintain constant rate as well as possible.Record pressure at each 1/2 bbl increment pumped. NOTE:Larger than 11 3/4"use.75-1 bpm,11 3/4-9 5/8 use.75-.5 bpm-plot should be tgreater than 45° 7.Continue until the test pressure(as described above)is reached.Do not exceed test pressure. Stop pump and shut in valve. 8.Monitor and record shut in pressure;hold for at least 5 minutes,or as specified.Troubleshoot problems if desired test pressure cannot be obtained. 9.Release pressure and record volume of fluid recovered during flow back. 10.Input recorded pressures and corresponding volumes on the Casing Test section of the"CSG-FIT"worksheet(in the yellow shaded area).This is the minimum volume line for the subsequent leak off test. Enter flow back when pressure is released. Prepared by Stephen F.Henniganq 10/10/14 Page 27 Perform Formation Test(LOT,FIT,etc) -enter all the header information for the well,ng,casing size,shoe depth,mud weight,date and your name at the top of the form on the"CSG-FIT"worksheet. 1.Drill shoe track and+20'of new formation. POOH into the casing shoe.Circulate and condition mud until shaker is free of cuttings and mud weight in is within+/-0.1 ppg of weight out for several consecutive measurements. 2.Rig up lines,pressure test and check for leaks.Make sure air is purged from the system. 3.Pumping down the drillpipe,break circulation with cementing unit(or low vol/high press pump). 4.Close annular BOP or pipe rams. 5.SLOWLY pump down drillpipe and maintain constant rate as well as possible.Required rate may vary,but first attempt should be at 1/2 bpm(OR same rate as casing test). Record pressure at each 1/2 bbl increment pumped and plot on the FORM INTEG.TEST(FIT)section of the"CSG-FIT"worksheet(in the blue shaded area). This will require teamwork among at least two,but better with three individuals.If the FORM INTEG.TEST(FIT) plot curves BELOW the Maximum Volume Line,stop and bleed off pressure then re-run the test at a higher pump rate(suggest 1/4 bpm higher). Note-also have someone record casing pressure from the choke manifold at the same--bbl increments. If these pressures differ from the drlllpipe recorded pressures by more than 10%,notify the office. 6.Continue until leak off(fracture initiation)is detected as indicated by a change in the rate of pressure increase. This is determined by the leak off test chart and observation of the pressure behavior.Once leak off indications are noted continue to pump at constant rate to confirm.If the pressure resumes a constant rate of increase, continue pumping and watch for subsequent leak off indications.If the rate of pressure increase continues to decline,continue pumping for 3 more_bbl increments to insure fracture has occurred(a noticable pressure drop should be evident).If a sudden pressure drop occurs,stop pumping immediately. 7.Record instantaneous shut in pressure(ISIP). Monitor and record shut in pressure every minute for at least 10 minutes. See#11 below 8.Release pressure and record volume of fluid recovered during flow back. 9.If the measured leak off pressure is less than the predicted leak off,then a cement channel may exist.Whenever a cement channel is suspected,the LOT should be repeated for confirmation.If a channel exists there should be little or no improvement seen. LOT or FIT or PIT(in EMWI=pressure(psi)I.052 I casing shoe depth('TVD)+current mud weight(mil 10.If the Leak Off plot falls between the Minimum and Maximum Volume Lines,this is a good leak off plot.Pick the point on the curve where the line begins to break over(the rate of pressure increase has changed from a straight line).This is the leak off value.On a"jug"test,there is no bend.PPG equivalents are calculated on the right. 11.Input recorded pressures and corresponding volumes on the FORM INTEG.TEST(FIT)section of the"CSG-FIT" worksheet. Values should initially fall between the Maximum volume line and the Csg Test line. 12.Input recorded shut in pressures and corresponding times on the Shut In Pressure(ISIP)section of the "CSG-FIT"worksheet(in the yellow shaded area). This is indicated by ISIP and incremental time©the bottom of FORM INTEG.TEST(FIT)section. Prepared by Stephen F.Henniganq 10/10/14 Page 28 Cook Inlet Energy North Fork Unit 42-35 (Note: Single Slurries MAY be used) Cementing 9-5/8"Surface Casing: 1. Prior to cementing casing: • Check cement lab test for sufficient pumping time,free water and fluid loss. • Discuss job with cementer and customer,double checking calculations for water,displacement,etc. • Verify all hoses and lines are in good shape and on site. Have extra hoses and high pressure pump iron available. • Confirm Stab-In collar placement is correct and hardware matches. • Ensure that 9-5/8""circulating swage is on location prior to running casing. • Ensure Drill Pipe Cross overs are available to fit 1502 discharge Iron Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 60 BBL Tuned Spacer IIIP'10.0 ppg Lead Slurry Cement 670 sks Class G Cement+Additives 12.0 ppg, 292 BBL Open Hole Excess 100% Tail Slurry Cement 190 sks Class G Cement+Additives 13.0 ppg, 62 BBL Open Hole Excess 100% Displacement Spacer: 10 BBL Use fresh water to drop Top Rubber Plug Displacement: 32.4 BBL Volume Based on Inner String Cementing Estimated Top Cement Slurry Surface PROPERTIES Lead Slurry Tail Slurry _Weight 12.0 13.00 Yield 2.48 1.93 Water 14.59 10.56 Pump time ^'05:00 ^'04:00 Water Loss "'500cc/30min ^'350cc/30min Free Water 0 0 Compressive Strength 8 hours 175 450 12 hours 280 702 24 hours 640 1486 48 hours 980 2110 Cement the casing as follows: Immediately prior to shutting the pumps down record and report the pump pressure ON A RATE/TIME/PRESSURE basis+5-10 minutes. Note: The final slurry design will be provided after testing cement,additive and mix water samples prior to performing the job. 2. After Cementing,record the following: • Time cement in place • Pressure used to displace. • RATE/TIME/PRESSURE after slowing down in anticipation of bumping plug. • Amount of barrels pumped behind cement. • Amount of barrels bled back to check floats. • When and if returns were lost while cementing. • Amount of cement(in barrels)circulated to surface. , Cementing 7"Production Casing: 1. Prior to cementing casing: • Check cement lab test for sufficient pumping time,free water and fluid loss. • Discuss job with cementer and customer,double checking calculations for water,displacement,etc. • Verify all hoses and lines are in good shape and on site. Have extra hoses and high pressure pump iron available. • Verify that wiper plugs are loaded in cementing plug assembly. • Drift casing prior to running. • Ensure that 7"circulating swage is on location prior to running casing. Cement the casing as follows: Bump the plug with 500 psi over circulating pressure.Immediately prior to shutting the pumps down record and report the pump pressure ON A RATE/TIME/PRESSURE basis+5-10 minutes. Hold pressure for 5 minutes. Release the pressure and confirm the floats are holding. Do not over displace by more than half of the shoe volume. Lead/Tail System(Option 2) Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 40 BBL Tuned Spacer 111""-11.5 ppg Lead Slurry: 530 sks Class G Cement+Additives ppg - (13.0 ppg) 171 BBL Excess 40% Over calculated volume or 20%over caliper volume Tail Slurry: 390 sks Class G Cement+Additives ppg - (15.8 ppg) 78 BBL Excess 40% Over calculated volume or 20%over caliper volume Displacement Spacer: 10 BBL Use fresh water to drop Top Rubber Plug Displacement Fluid: 369 BBL Estimated Top Cement Slurry Surface PROPERTIES Lead Slurry Tail Slurry Weight 13.00 15.8 Yield 2.44 1.16 Water 13.589 4.95 Pump time 4:23 ^'06:00 Water Loss 150cc/30min ^'100cc/30min Free Water 0 0 Compressive Strength 8 hours 0 900 12 hours 50 1725 24 hours 450 2450 48 hours 900 2950 72 hours 1230 3200 Note: The final slurry design will be provided after testing cement,additive and mix water samples prior to performing the job. 2. After Cementing,record the following: • Time cement in place • Pressure used to displace. • RATE/TIME/PRESSURE after slowing down in anticipation of bumping plug. • Amount of barrels pumped behind cement. • Amount of barrels bled back to check floats. • When and if returns were lost while cementing. CookInlet EneryLocation: Cook Inlet,Alaska(Kenai Peninsula) Slot: North Fo Fa.■ Cook Inlet Energy Field: North Fork Well: NFU#42-35 BAKER Facility: North Fork Unit(NAD27) Wellbore: NFU#42-35 UGIIIES Plot reference wellpem is NFU 42-35 Vera49 Well Profile Data True vertical depths are referenced to CIE 37(RT) Grid System:NAD27/TM Alaska SP,Zone 4(5001).US het Design Comment MD(ft) Inc(°) AZ(°) TVD(ft) Loral N(fl) Local E(ft) DLS(°/1006) VS(ft) Measured depths are referenced to CIE 37(RT) North Reference:True north Tie On 20.80 0.000 165.869 20.80 0.00 0.00 _ 0.00 0.00 CIE 37(R7)to Mean See Level:678.6 feet Scale:True distance End of Tangent _1000.00 0.000 165.869 1000.00 0.00 0.00 0.00 0.00 Mean Sea Level to Mod line(At Slot North Fork#42-35):0 feet Depths ere In feet End of BM(6) 2762.33 35.247 165.869 2653.26 -509.29 128.22 2.00 525.18 Coordinates are In feet referenced to Slot Greeted by:mlrhwAt on 10182014 End of Tangent(S) 6788.56 35.247 165.869 5941.39 -2762.50 895.47 - 0.00 2948.70 Drop(S) 8321.01 0.000 165.869 7379.00 -3205.36 806.97 2.30 3305.38 End of Tangent 10621.01 0.000 165.869 9679.00 -3205.36 806.97 0.00 3305.38 Scale inch=600ft Easting (ft) -300 0 300 600 900300 1 1 1 1 North Fork#42-35 KOP - 0 300 End of Buil z1 coo- 9.625in Casing Surface7' - 600 S 2 o_ - 900 fi d 16in Conductor re --1200 1000- End of Tangent 2.00°/100ft --1500 )),V End of Build(S) CO 3000- 9.625in Casing Surface --1800 9 $ --2100 L 4000- a) 1730 5000- 5300SD --2400 a)f 6000- NFU_4235_TGT 2(8-Oct-14) End of Tangent(S) NFU_4235_TGT 2(8-Oct-14) C, --2700 Begin Drop 2.30°/100ft 6100SD 7000- --3000 6700SD NFU_4235_TGT 1(8-Oct-14) Drop(S) 7in Casing Production 8000- NFU_4235_TGT 1(8-Oct-14) n--3300 NFU_4235_TD(8-Oct-14) TD N (4 (3 9000- -3600 7in Casing Production NFU_4235_TD(8-Oct-14) z 10000- -n c (3 CT 11000 1 1 �p1Q 1 1 1 -1000 0 1Vertical J@ction o 4000 5000 Scale 1 Inch=2000 ft Azimuth 165.87°with reference 0.00 N,0.00 E Spider Cook Inlet Enerjy Ira ail Location: Cook Inlet.Alaska(Kenai Peninsula) Slot North F 5 InIet Energy Fie13: North Fork Well NFU#42-35 RAKER Facility North Fork 001(((NAD271 VVe4lbore- NFU#42-35 mucrage ��k ..e.oa... Cow�v....,.w..•w.-«..x. H.ea�,.....wa���..o.• Easting(ft) % • '' ,200 - a - 1600 Arcb 400 2000 2000 -700 240.2 2400 A2 K 000 •.4.S`' 2000 . -000 North Fork 4.4 1-35 3200 -000 oZ 3200 3600 -was 3000 • 0000 4000 9000 -OMp 4400 -0000 4800 41!00 5200 5600X000 NFU_4235_92000d(9-Sep-14) X00 4)000 Yn *000 122'." ONS Prepared by Stephen F.Henniganq 10/10/14 Page 23 C ■M N r y 1 t y C O• 4-, 40 ,0• ,0 Cl.) • M• Q =• o MV N c O N O O •IIww▪ o c F- V/ Q > O __ N N MMCfl J j O O f� r o p o p p I-- a) = O '--' O O N CO M C CO CO CO p p CO a O O M M M O Q 7 4(i); W W arO aro aro p o C2O V a J _ Z H •r- V) O O (O (O (O W Z .c N ,_ _ _ ■ No 3 X0000 >.....7c. 0 0 V m MMIMIFo 1 co CSD CO o Z p U0 `n CO M O. N C C tovt o 0 0• o <<j 0 0 coi J O O p O O O O O =y p � 9 M M � U a a O O O i W W N O 0 0000 t+^ opo ^ NN lL w () 00000 Ow. V V Ow QO aO v3 11 V O N r r CO CO 'C 00 f� f� '6 "F° _ N_ ■� Or E lL � NNOO .ice O NNN O u N N i11 cuZ i.i � O J 1 00 N 000 N,_, 00 N MO 0 0 W w M CO W lL w OD a0 CO .'�' N 00 toco Co � � t''� 600 � � '6� toM (Oco 'O� 00 N N NNN , coo ? O O IIIIIIIIIIIIIIV O p Q O c cts O 3 aro aro F- u) -Ne E•r in Lo o N N V •N O H H d O O -6 '57 OO00 '6 d GS Cn0 E co /��13 Y - y J - a) Z F- H o ca_ oO C H - y a c u co (0 m o m ~ cm I'_.— o cp 0 - '> o V N a W N p N j U 2' u .0 � w cu Q.' �' = C N d O U) co M N C //�� d y o E c L r• O O C • O I- N N \V ..4-4- ..... V d Y. m = 2 LL (� m t m o o U t6i � "' � c0Q QC LLLLZ 00 L a o `—° m 0 T w coo p E) = = 0 (7) Z Z G p CO o �a - ID Q4 .. i 3 . 0 J _ a �uNOpO Cr) Oinin CU r2�-+ p0 C. O. i N O N N N N o voi i s d = o ° d N - G N (NO r C ce 0 Q it LL (/) 3 3 3. 3 co D o c W U) LL LL N O p IR 0 0 0 (f)tW CD F- m "0 -0 0) Q. D) - m a (0 > O 2 o co H m m p 0 � 0 0 0 0 0 - 0 0 0 0 0 0 �- 0 0 0 w o c 0 0 0 o - 0 0 0 0 0 In o a -0D toD •0)000Dro0oLUooD C C C D cO C (U 0 - N- C N 00 m O - U) N C W UJ W CO U) W OD CO CO CO W > N- N- O) 0) CO CO W 00 0) U) O O O I- CO (0 00 00 00 00 00 00 00 00 00 O (- h f- N 0 CO CO CO CO CO CO M MM O 00 N (0 06 .4 M d1 U) U) U) U) U) 666 U) O N N4 4 ^ CO _O 0 0 0 0 0 0 0 0 0 O O U) 00 CO CO O) CO CO CO CO CO CO CO CO CO N N N N N CO CO CO CO CO 00 CO CO CO CO 000 000000000000000 000 00 M M M M M M 0 0 0 0 0 0 0 O N O 0 0 N N N N N N 0 0 0 0 0 0 0 N O O O 000 O O O O O O O O O O O O 0 000 00 0 C CM M O M 0 0 0 0 0 0 0 N O N O O O N N N N N N 0 0 0 0 0 0 0 a) 0) (0 0 U) (OO N- (00) 0) (0 I- M N N N N N N N N N NO) O) N V V V 0N- N 000000000 CO O O 0 (D 0) 0) 0 N (0 (0VV1- NCO000000000 0 (O (OUNMMMNOOOO) 0) 0) 0) 0) 0) 0) N0000) 0000000000 - r r- r- N N N N N N N N N N N N N N N N N N N N N N N V 00 (0 N- NN (0 LO O) 000000000 O1.- 1� 1- U) V V (OLUO00000000 CO M CO CO N U) U) O N CO CO CO CO (D CO (.0 () (D U) N- N- 00 000 00 0) - (0 00 00 0O C0 00 00 00 00 00 0) O O O O U) U) U) CO (D (D (DCO (0 (O (O (O CO (O 0) 000000000000000000 0) 000000000000000000 N N N N N N N N N N N N N N N N N N O (D (D O O 0) 0) 0 0 0 0 0 0 0 0 0 0 0 0 O N N O O CM M 0 0 0 0 0 0 0 0 0 0 0 0 O M M O 0) - O) 0) O) 0) 0) 0) 0) V V O) O) 0) 0 CO U) U) O V 1- - U) N- N- O (D 0 0 CO N- r- 0 CO OD 0 (O (D 1- V CD 01010) O0 V N (D N N N U) U) U) U) CO CO N- N- N- r 00 00 CO O) 0) N- r r N- r N- N- N- N- N- N- N- N- N- r N- N- r- OD 00 00 00 00 00 CO 00 OD O0 CO (X) 00 00 00 CO 00 (X) 666 666666666666666 0 (D O O (D (D (D (D (O O O O (O O O O (D (D O U) ((7 U) (C) U) 0) 00 O 000000000 0 " " N N N M 00 0 0 0 0 0 0 0 0 0 66664-56 '4' 66666666666 mm M M M M M O CO 00 O CO (D (0 N (D 0) O OO M O (D LO U) M O) (0 0 0 0 O O O O 0• O• ONN T- (JD 0000 V 0) O T- T- T- T- NN 0 (O (O CO CO CC) CO CO 0) O) N N LO V N (D 0 N- N- (D 1- r O 0) U) CO CO (K) 0) O) O O N N N (D (D (D CO CO N- CO 00 CO CO 00 0) 0) Clearance Report Page 1 of 30 Clearance Report Fait NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 1 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) REPORT SETUP INFORMATION Projection System NAD27/TM Alaska SP,Zone 4(5004),US feet • Software System WellArchitect®4.0.1 North Reference True . User Michwilg Scale 1 Report Generated 10/8/2014 at 9:41:59 AM Convergence at slot n/a Database/Source file WA_Anchorage/NFU_#42-35_CR.xml WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates Northift] Eastlft] EastinglUS ft] NorthingIUS ftp Latitude Longitude Slot Location 586.91 -1453.01 199958.04 2121128.25 59°47'46.358"N 151°37'44.913"W Facility Reference Pt 201396.26 2120505.98 59°47'40.579"N 151°37'16.516"W Field Reference Pt 201396.26 2120505.98 59°47'40.579"N 151°37'16.516"W WELLPATH DATUM Calculation method Minimum Curvature CIE 37(RT)to Facility Vertical Datum 678.60ft Horizontal Reference Pt Slot CIE 37(RT)to Mean Sea Level 678.60ft Vertical Reference Pt CIE 37(RT) CIE 37(RT)to Mud Line at Slot(North Fork 678.60ft #42-35) MD Reference Pt CIE 37(RT) Field Vertical Reference Mean Sea Level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start MD 20.80ft Surface Position Uncertainty included Declination 16.51°East of TN Dip Angle 72.86° Mag Field Strength 55060 nT Slot Surface Uncertainty @I SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes ANTI-COLLISION RULE Rule Name E-type Closest Approach w/Hole&Csg Limit:0,StdDev:3.00 Rule Based On Ellipsoid Separation w/Surface Uncert Plane of Rule Closest Approach Threshold Value 0.00ft Subtract Casing&Hole Size yes Apply Cone of Safety no file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 2 of 30 Clearance Report FA. NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 2 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) HOLE&CASING SECTIONS-Ref Wellbore:NFU#42-35 Ref Wellpath:NFU 42-35 Vers#9 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] _ [ft] [ft] [ft] [ft] 16in Conductor 0.25 120.00 119.75 0.25 120.00 0.00 0.00 0.00 0.00 12.25in Open Hole 20.80 2880.79 2859.99 20.80 2750.00 0.00 0.00 -575.58 144.91 9.625in Casing Surface 20.80 2880.79 2859.99 20.80, 2750.00 0.00 0.00 -575.58 144.91 8.75in Open Hole 2880.79 10621.01 7740.23 2750.00 9679.00 -575.58 144.91 -3205.36 806.97 lin Casing Production 2880.79 10621.01 7740.23 2750.00 9679.00 -575.58 144.91 -3205.36 806.97 SURVEY PROGRAM- Ref Wellbore:NFU#42-35 Ref Wellpath:NFU 42-35 Vers#9 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ft] 20.80 2880.79 OnTrak(MagCorr) NFU#42-35 2880.79 10621.01 OnTrak(Standard) NFU#42-35 CALCULATION RANGE & CUTOFF From:20.80ft MD ITo: 10621.O1ft MD IC-C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY(7 Offset Wellpaths selected)Ellipse separations calculated in Closest Approach plane C-C Clearance Distance ACR Ellipse Separation Distance Ref Min C-C Diverging Ref MD of Min Min Ell Sep ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ell Sep Ell Sep Dvrg from Status Facility Slot Well Wellbore Wellpath [ft( MI Ill [ft) IN [ft' North Fork North Fork#23- NFU NFU#23-25 NaviTrak MWD<177- 610.04 61.68 10520.80 623.26 47.87 10520.80 PASS Unit(NAD27) 25 #23-25 3045'>OnTrak<3183-10785'> North Fork North Fork#14- NFU NFU#14-25 OnTRAK MWD<204-117005 1526.76 105.31 10520.80 1541.88 86.95 10520.80 PASS Unit(NAD27) 25(Hemlock) #14-25 , North Fork North Fork#24- NFU NFU#24-26 NFU#24-26 Ver#3 20.80 108.07 10520.80 120.25 94.87 10520.80 PASS Unit(NAD27) 26 #24-26 Wellplan North Fork North Fork#22- NF#22- NF#22-35 NaviTrakMWD<181- 20.80 120.07 9920.80 20.80 106.96 10020.80 PASS Unit(NAD27) 35 35 2945'>OnTrakMWD<3044-10700'> North Fork North Fork#32- NFU NFU#32-35 OnTrak MWD<196-12070'> 20.80 217.60 10420.80 20.80 204.23 10420.80 PASS Unit(NAD27) 35(Tyonek) #32-35 North Fork North Fork#34- NFU NFU#34-26 PGMS GyroData<l00-2500'>MWD 20.80 275.46 9920.80 20.80 262.13 9920.80 PASS Unit(NAD27) 26 #34-26 (HAL)<2550-9021'> NF#41-35 North Fork#41- NF#41- NF#41-35 GyroData PGMS<100-9932'>Inclination 4327.69 465.49 10621.01 4343.63 326.42 10621.01 PASS (NAD27) 35 35 ONLY<10070-123345 file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 3 of 30 Clearance Report Fait A , NFU 42-35 Vers#9 BAKER _ Cook Inlet Energy_ Closest Approach Page 3 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Facility:North Fork Unit NAD27) Slot:North Fork#23-25 Well:NFU#23-25 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [HI [HI [ft! [ftI [ft] [ftI [ftI [HI Bearing Clear Dist MASD Sep Status 11 Iftl IRI [ft' 20.80 20.80 0.00 0.00 25.06 20.83 60.62 -29.78 333.84 67.54 13.33 54.21 PASS 120.80t 120.80 0.00 0.00 125.74 121.50 60.32 -29.13 334.22 66.99 13.22 53.77 PASS 220.80t 220.80 0.00 0.00 226.12 221.87 59.54 -27.40 335.29 65.55 13.10 52.45 PASS 320.80t 320.80 0.00 0.00 325.72 321.45 58.79 -25.44 336.60 64.06 13.23 50.83 PASS 420.80t 420.80 0.00 0.00 425.80 421.51 58.52 -23.82 337.85 63.18 13.38 49.80 PASS 520.801. 520.80 0.00 0.00 525.62 521.29 58.40 -21.14 340.10 62.12 13.57 48.54 PASS 610.04t 610.04 0.00 0.00 614.50 610.02 59.56 -16.04 344.92 61.68 13.79 47.90 PASS 620.801. 620.80 0.00 0.00 625.20 620.67 59.80 -15.15 345.79 61.69 13.82 47.87 PASS 623.261 623.26 0.00 0.00 627.62 623.08 59.86 -14.93 345.99 61.70 13.83 47.87 PASS 720.801. 720.80 0.00 0.00 723.23 718.03 63.61 -4.45 356.00 63.83 14.19 49.64 PASS 820.801- 820.80 0.00 0.00 820.71 814.15 69.44 10.59 8.67 70.55 14.80 55.75 PASS 920.801, 920.80 0.00 0.00 916.54_ 907.80 76.41 29.66 21.22 82.99 15.44 67.55 PASS 1000.00 1000.00 0.00 0.00 990.31 979.14 82.88 47.27 29.70 97.67 15.96 81.71 PASS 1020.80t 1020.80 -0.07 0.02 1009.51 997.58 84.76 52.27 31.63 102.31 16.10 86.21 PASS 1120.801. 1120.76 -2.47 0.62 1100.62 1084.39 94.37 78.20 38.70 129.30 16.80 112.50 PASS 1220.801. 1220.58 -8.25 2.08 1188.32 1166.69 104.79 106.61 42.76 163.12 17.44 145.69 PASS 1320.80t 1320.13 -17.40 4.38 1272.98 1244.82 115.96 137.25 44.89 202.76 18.08 184.68 PASS 1420.80t 1419.29 -29.92 7.53 1354.08 1318.32 127.65 169.44 45.78 247.45 18.75 228.70 PASS 1520.801- 1517.94 -45.78 11.53 1431.86 1387.49 139.70 202.89 45.90 296.71 19.39 277.32 PASS 1620.80t, 1615.95 -64.97 16.36 1505.60 1451.85 151.90 236.76 45.46 350.06 20.08 329.99 PASS 1720.80t 1713.22 -87.47 22.02 1574.28 1510.56 164.31 270.16 44.58 407.48 20.80 386.68 PASS 1820.80t 1809.62 -113.25 28.51 1641.87 1567.17 177.27 304.73 43.55 468.48 21.68 446.80 PASS 1920.80t 1905.03 -142.27 35.82 1705.05 1619.06 189.72 338.55 42.36 532.58 22.59 509.99 PASS 2020.801.- 1999.34 -174.51 43.93 1763.80 1666.28 201.72 371.37 41.03 599.74 23.52 576.22 PASS 2120.80t 2092.43 -209.91 52.85 1828.41 1717.38 215.23 408.52 39.92 669.26 24.75 644.51 PASS 2220.80t 2184.19 -248.45 62.55 1893.32 1768.32 228.94 446.35 38.80 740.37 26.09 714.27 PASS 2320.80t 2274.50 -290.07 73.03 1958.85 1819.56 242.85 484.76 37.69 812.71 27.56 785.15 PASS 2420.80t- 2363.27 -334.72 84.27 2016.77 1864.64 255.37 518.91 36.37 886.42 29.00 857.42 PASS 2520.80t 2450.37 -382.34 96.26 2074.34 1909.16 268.21 553.06 35.08 961.66 30.57 931.10 PASS 2620.80t 2535.71 -432.89 108.98 2134.68 1955.71 281.79 588.98 33.89 1038.06 32.33 1005.73 PASS 2720.801._ 2619.17 -486.29 122.43 2194.01 2001.40 295.12 624.41 32.72 1115.45 34.19 1081.27 PASS 2762.33 2653.26 -509.29 128.22 2218.30 2020.08 300.54 638.97 32.24 1147.87 34.98 1112.89 PASS 2820.80t 2701.01 -542.02 136.46 2252.22 2046.12 308.06 659.34 31.60 1193.70 36.11 1157.59 PASS 2920.80l 2782.68 -597.98 150.54 2309.37 2089.94 320.68 693.79 30.60 1272.38 37.77 1234.61 PASS 3020.80t 2864.35 -653.94 164.63 2365.46 2132.85 333.02 727.75 29.71 1351.40 39.46 1311.94 PASS 3120.80t 2946.01 -709.90- 178.72 2419.98 2174.44 345.04 760.89 28.89 1430.79 41.15 1389.64 PASS 3220.80t 3027.68 -765.87 192.81 2485.58 2224.51 359.59 800.69 28.37 1510.38 43.16 1467.22 PASS 3320.80t 3109.35 -821.83 206.90 2552.31 2275.99 374.53 840.43 27.90 1589.70 45.23 1544.47 PASS 3420.80t 3191.02 -877.79 220.99 2608.09 2319.10 387.11 873.52 27.29 1669.14 47.02 1622.12 PASS 3520.80t 3272.69 -933.76 235.08 2663.71 2362.01 399.71 906.59 26.73 1748.82 48.82, 1700.00 PASS 3620.80t 3354.35 -989.72 249.17 2719.19 2404.72 412.26 939.70 26.22 1828.71 50.63 1778.08 PASS 3720.801 3436.02 -1045.68 263.26 2776.98 2449.11 425.29 974.33 25.80 1908.77 52.53 1856.23 PASS 3820.801. 3517.69 -1101.65 277.35 2833.99 2492.84 438.08 1008.60 25.40 1988.92 54.42 1934.50 PASS 3920.801.- 3599.36 -1157.61 291.43 2887.37 2533.72 450.11 1040.75 24.99 2069.25 56.22 2013.03 PASS 4020.80t 3681.02 -1213.57 305.52 2950.70 2582.19 464.45 1078.91 24.75 2149.73 58.32 2091.41 PASS file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 4 of 30 Clearance Report r NFU 42-35 Vers#9 BAKER; Clearance Report Page 5 of 30 Clearance Report Flit , , NFU 42-35 Vers#9 BAKER _ ; Cook Inlet Energy_ Closest Approach Page 5 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork _Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Facility:North Fork Unit(NAD27) Slot:North Fork#23-25 Well:NFU#23-25 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Iftl Iftl Ft] Iftl Iftl Iftl Iftl Bearing Clear Dist MASD Sep Status - 11 WI Iftl IN 8420.801 7478.79 -3205.36 806.97 8704.09 7536.42 1291.84 3346.11 29.45 5164.82 168.34 4996.48 PASS 8520.801 7578.79 -3205.36 806.97 8824.05 7656.37 1290.75 3344.85 29.44 5163.51 168.44 4995.08 PASS 8620.801 7678.79 -3205.36 806.97 8943.48 7775.79 1289.32 3343.28 29.44 5161.83 168.53 4993.30 PASS 8720.801 7778.79 -3205.36 806.97 9036.22 7868.51 1288.01 3341.96 29.43 5159.91 168.64 4991.27 PASS 8820.80f 7878.79 -3205.36 806.97 9110.01 7942.29 1287.30 3341.00 29.43 5158.43 168.75 4989.68 PASS 8920.80f 7978.79 -3205.36 806.97 9188.11 8020.38 1286.86 3340.19 29.42 5157.42 168.86 4988.56 PASS 9020.80f 8078.79 -3205.36 806.97 9315.09 8147.35 1285.83 3338.98 29.41 5156.22 168.98 4987.24 PASS 9120.80f 8178.79 -3205.36 806.97 9409.43 8241.68 1284.70 3338.61 29.42 5154.98 169.11 4985.87 PASS 9220.80f 8278.79 -3205.36 806.97 9519.98 8352.22 1283.09 3338.52 29.42 5153.67 169.26 4984.41 PASS 9320.80f 8378.79 -3205.36 806.97 9606.71 8438.95 1281.78 3338.32 29.43 5152.26 169.40 4982.86 PASS 9420.80f 8478.79 -3205.36 806.97 9677.09 8509.32 1281.32 3337.96 29.43 5151.42 169.54 4981.88 PASS 9520.80f 8578.79 -3205.36 806.97 9784.69 8616.91 1280.91 3337.28 29.42 5150.79 169.67 4981.11 PASS 9620.80f 8678.79 -3205.36 806.97 9910.38 8742.60 1280.13 3336.16 29.42 5149.81 169.81 4980.00 PASS 9720.80f 8778.79 -3205.36 806.97 10017.15 8849.36 1279.10 3335.00 29.41 5148.43 169.94 4978.49 PASS 9820.80f 8878.79 -3205.36 806.97 10133.17 8965.36 1277.88 3333.70 29.41 5146.97 170.08 4976.89 PASS 9920.80f 8978.79 -3205.36 806.97 10250.55 9082.73 1275.97 3332.62 29.41 5145.10 170.23 4974.87 PASS 10020.80f 9078.79 -3205.36 806.97 10356.28 9188.43 1273.82 3331.96 29.41 5143.02 170.39 4972.63 PASS 10120.80f 9178.79 -3205.36 806.97 10454.39 9286.51 1271.66 3331.50 29.42 5140.88 170.57 4970.31 PASS 10220.80f 9278.79 -3205.36 806.97 10550.31 9382.41 1269.61 3331.26 29.43 5138.89 170.74 4968.14 PASS 10320.80f 9378.79 -3205.36 806.97 10666.55 9498.61 1266.70 3331.11 29.44 5136.63 170.94 4965.70 PASS 10420.80f 9478.79 -3205.36 806.97 10765.78 9597.81 1263.93 3331.34 29.46 5134.31 171.14 4963.17 PASS 10520.801 9578.79 -3205.36 806.97 10785.00 9617.02 1263.38 3331.40 29.46 5132.63 171.30 4961.33 PASS 10620.801 9678.79 -3205.36 806.97 10785.00 9617.02 1263.38 3331.40 29.46 5132.86 171.40 4961.46 PASS 10621.01 9679.00 -3205.36 806.97 10785.00 9617.02 1263.38 3331.40 29.46 5132.86 171.40 4961.46 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Slot Surface Uncertainty @1 SD Horizontal 2.000ft Vertical 1.000ft , Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] _ [ft] [ft] 16in Conductor 20.55 137.00 116.45 16.07 132.52 36.96 -18.16 36.84 -17.91 , 10.75in Casing Surface 20.55 3102.00 3081.45 16.07 2698.13 36.96 -18.16 170.16 347.52 ELLPATH COMPOSITION-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Start MD End MD Uncertainty Model Log Name/Comment Wellbore [ft] [ft] 20.55 3045.00 NaviTrak(MagCorrPositional) NaviTrak MWD<177-3045'> NFU#23-25 3045.00 10785.00 OnTrak(Standard) OnTrak MWD<3183-10785'> NFU#23-25 file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 6 of 30 Clearance Report NFU 42-35 Vers#9 BAKER _ Cook Inlet Energy_ Closest Approach Page 6 of 28 HUGEIES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-l0785'> MD Reference:Nabors 99(RTE) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 20.55ft file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 7 of 30 Clearance Report Fail' A NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 7 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> Facility:North Fork Unit(NAD27) Slot:North Fork#14-25(Hemlock) Well:NFU#14-25 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl IftI Iftl IN IN Iftl Iftl [ft' Bearing Clear Dist MASD Sep Status 1°1 Iftl IftI [ft] 20.80 20.80 0.00 0.00 21.27 21.07 61.56 -148.49 292.52 160.75 13.35 147.39 PASS 120.80t 120.80 0.00 0.00 122.53 122.32 62.13 -147.64 292.82 160.19 13.27 146.92 PASS 220.80t 220.80 0.00 0.00 223.53 223.29 63.47 -145.62 293.55 158.87 13.12 145.75 PASS 320.80t 320.80 0.00 0.00 323.90 323.62 65.04 -143.12 294.44 157.23 13.25 143.98 PASS 420.80t 420.80 0.00 0.00 423.85 423.52 66.61 -140.43 295.38 155.45 13.40 142.05 PASS 520.80t 520.80 0.00 0.00 524.58 524.20 67.82 -137.64 296.23 153.48 13.59 139.89 PASS 620.80t 620.80 0.00 0.00 624.56 624.16 67.60 -135.36 296.54 151.34 13.81 137.53 PASS 720.80t 720.80 0.00 0.00 725.47 725.03 67.00 -132.78 296.78 148.78 14.07 134.72 PASS 820.80t 820.80 0.00 0.00 825.77 825.29 65.40 -130.24 296.66 145.80 14.35 131.45 PASS 920.80t 920.80 0.00 0.00 925.79 925.25 63.66 -127.58 296.52 142.66 14.66 127.99 PASS 1000.00 1000.00 0.00 0.00 1006.46 1005.88 62.25 -125.10 296.45 139.85 14.94 124.92 PASS 1020.80t 1020.80 -0.07 0.02 1028.30 1027.70 61.86 -124.18 296.50 138.95 15.02 123.94 PASS 1120.801, 1120.76 -2.47 0.62 1134.03 1133.14 59.90 -116.87 297.96 133.59 15.45 118.14 PASS 1220.80t1 1220.58 -8.25 2.08 1240.12 1238.43 56.67 -104.36 301.38 125.94 16.01 109.93 PASS 1320.80t 1320.13 -17.40 4.38 1344.01 1340.81 51.88 -87.43 307.04 116.86 16.62 100.24 PASS 1420.80t 1419.29 -29.92 7.53 1445.40 1439.96 46.89 -66.84 315.92 108.90 17.32 91.58 PASS 1520.80t 1517.94 -45.78 11.53 1544.98 1536.57 42.29 -43.15 328.17 105.33 18.22 87.11 PASS 1526.76t 1523.79 -46.83 11.79 1551.03 1542.40 42.02 -41.60 329.00 105.31 18.28 87.04 PASS 1541.881 1538.65 -49.55 12.47 1565.86 1556.70 41.35 -37.71 331.10 105.39 18.44 86.95 PASS 1620.80t, 1615.95 -64.97 16.36 1644.07 1631.66 37.57 -15.70 342.64 108.58 19.38 89.20 PASS 1720.80t 1713.22 -87.47 22.02 1741.30 1723.44 31.90 15.82 357.03 119.97 20.77 99.20 PASS 1820.80t 1809.62 -113.25 28.51 1834.66 1810.01 26.02 50.24 8.87 140.95 22.21 118.74 PASS 1920.80t 1905.03 -142.27 35.82 1924.88 1892.06 20.24 87.32 17.58 170.97 23.65 147.32 PASS 2020.80t 1999.34 -174.51 43.93 2011.80 1969.46 14.56 126.43 23.58 208.43 25.12 183.32 PASS 2120.80t 2092.43 -209.91 52.85 2098.21 2045.02 8.76 167.94 27.76 251.62 26.73 224.89 PASS 2220.80t 2184.19 -248.45 62.55 2183.45 2118.85 2.76 210.14 30.43 298.60 28.49 270.10 PASS 2320.80t- 2274.50 -290.07 73.03 2265.23 2188.49 -3.51 252.52 32.06 348.90 30.35 318.55 PASS 2420.80t 2363.27 -334.72 84.27 2347.57 2257.55 -10.25 296.86 33.23 402.06 32.44 369.62 PASS 2520.80t 2450.37 -382.34 96.26 2431.53 2327.71 -17.31 342.44 34.00 457.06 34.76 422.30 PASS 2620.80t 2535.71 -432.89 108.98 2512.93 2395.65 -24.31 386.70 34.21 513.50 37.16 476.34 PASS 2720.80t 2619.17 -486.29 122.43 2596.75 2465.54 -31.60 432.42_ 34.29_ 571.35 39.80 531.55 PASS 2762.33 2653.26 -509.29 128.22 2630.69 2493.83 -34.66 450.91 34.21 595.67 40.90 554.76 PASS 2820.80t 2701.01 -542.02 136.46 2678.03 2533.29 -38.96 476.72 34.07 630.05 42.47 587.59 PASS 2920.801.- 2782.68 -597.98 150.54 2756.76 2598.81 -46.14 519.76 33.79 688.95 44.78 644.17 PASS 3020.80t- 2864.35 -653.94 164.63 2839.75 2667.66 -53.82 565.45 33.74 747.99 47.29 700.70 PASS 3120.801 2946.01 -709.90 178.72 2919.04 2733.37 -61.47 609.17 33.58 806.83 49.74 757.09 PASS 3220.80t 3027.68 -765.87 192.81 2995.66 2796.81 -68.55 651.55: 33.34 866.03 51.84 814.19 PASS 3320.80t 3109.35 -821.83 206.90 3077.92 2865.11 -75.75 696.84 33.29 925.38 54.12 871.26 PASS 3420.80t 3191.02 -877.79 220.99 3160.49 2933.84 -83.02 742.00 33.25 984.50 56.43 928.07 PASS 3520.80t 3272.69 -933.76 235.08 3241.12 3001.14 -90.01 785.85 33.14 1043.55 58.74 984.82 PASS 3620.80t 3354.35 -989.72 249.17 3320.41 3067.41 -96.71 828.87 32.99 1102.66 61.05 1041.61 PASS 3720.80t 3436.02 -1045.68 263.26 3405.56 3138.75 -103.84 874.82 33.00 1161.66 63.58 1098.08 PASS 3820.80t- 3517.69 -1101.65 277.35 3481.94 3202.85 -110.08 915.88 32.78 1220.68 65.89 1154.79 PASS 3920.80t 3599.36 -1157.61 291.43 3563.13 3271.05 -116.44 959.47 32.69 1279.88 68.37 1211.50 PASS 4020.80t 3681.02 -1213.57 305.52 3649.10 3343.43 -123.26 1005.35 32.70 1338.84 71.03 1267.81 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 8 of 30 Clearance Report Fait NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 8 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 • Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> Facility:North Fork Unit(NAD27) Slot:North Fork#14-25(Hemlock) Well:NFU#14-25 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR lftl Iftl Iftl Iftl !ft] Iftl Iftl Iftl Bearing Clear Dist MASD Sep Status 1°I Iftl Iftl IftI 4120.80f 3762.69 -1269.54 319.61 3726.03 3408.35 -129.23 1046.20 32.50 1397.78 73.43 1324.35 PASS 4220.80f 3844.36 -1325.50 333.70 3808.62 3478.17 -135.38 1089.87 32.43 1456.81 76.03 1380.78 PASS 4320.80f 3926.03 -1381.46 347.79 3894.12 3550.64 -141.78 1134.77 32.41 1515.61 78.72 1436.88 PASS 4420.80f 4007.69 -1437.43 361.88 3979.55 3623.24 -148.21 1179.35 32.38 1574.21 81.44 1492.78 PASS 4520.80f 4089.36 -1493.39 375.97 4066.94 3697.49 -155.28 1224.90 32.39 1632.42 84.24 1548.18 PASS 4620.80f 4171.03 -1549.35 390.06 4143.21 3762.04 -161.71 1265.01 32.23 1690.67 86.72 1603.95 PASS 4720.80f 4252.70 -1605.32 404.15 4226.76 3832.68 -168.74 1309.08 32.21 1749.02 89.46 1659.56 PASS 4820.80f 4334.37 -1661.28 418.24 4303.94 3897.68 -175.44 1350.13 32.10 1807.44 92.03 1715.41 PASS 4920.80f 4416.03 -1717.24 432.33 4384.01 3964.62 -182.95 1393.43 32.06 1865.89 94.73 1771.16 PASS 5020.80f 4497.70 -1773.21 446.41 4464.75 4032.23 -190.27 1436.95 32.04 1924.45 97.46 1826.99 PASS 5120.80f 4579.37 -1829.17 460.50 4540.92 4095.90 -197.26 1478.18 31.95 1983.06 100.06 1883.00 PASS 5220.80f 4661.04 -1885.13 474.59 4612.55 4155.37 -203.88 1517.53 31.81 2042.06 102.54 1939.52 PASS 5320.80f 4742.70 -1941.10 488.68 4701.83 4229.59 -212.24 1566.45 31.94 2100.91 105.62 1995.29 PASS 5420.801 4824.37 -1997.06 502.77 4784.39 4298.49 -219.77 1611.30 31.95 2159.66 108.47 2051.19 PASS 5520.801 4906.04 -2053.02 516.86 4864.08 4365.28 -226.78 1654.22 31.91 2218.37 111.21 2107.16 PASS 5620.80f 4987.71 -2108.99 530.95 4933.61 4423.70 -232.53 1691.48 31.74 2277.29 113.62 2163.67 PASS 5720.80f 5069.37 -2164.95 545.04 5006.14 4484.16 -238.53 1731.09 31.62 2336.73 116.15 2220.58 PASS 5820.801 5151.04 -2220.91 559.13 5097.69 4560.44 -246.45 1781.07 31.75 2395.92 119.33 2276.59 PASS 5920.801 5232.71 -2276.88 573.22 5172.90 4623.38 -252.72 1821.78 31.67 2455.08 121.95 2333.12 PASS 6020.801 5314.38 -2332.84 587.31 5261.15 4697.43 -259.87 1869.25 31.73 2514.20 124.99 2389.22 PASS 6120.801 5396.04 -2388.80 601.39 5341.72 4765.18 -266.19 1912.38 31.70 2573.36 127.57 2445.79 PASS 6220.80f 5477.71 -2444.77 615.48 5438.71 4847.48 -273.62 1963.18 31.83 2631.98 130.56 2501.42 PASS 6320.801 5559.38 -2500.73 629.57 5549.65 4942.65 -281.98 2019.56 32.07 2689.85 133.93 2555.92 PASS 6420.80f 5641.05 -2556.69 643.66 5649.22 5028.96 -289.16 2068.70 32.15 2747.19 136.93 2610.26 PASS 6520.801 5722.72 -2612.66 657.75 5737.87 5106.22 -295.46 2111.70 32.11 2804.18 139.61 2664.57 PASS 6620.801 5804.38 -2668.62 671.84 5868.40 5221.44 -304.22 2172.39 32.40 2860.39 143.38 2717.02 PASS 6720.801 5886.05 -2724.58 685.93 6039.81 5376.29 -315.30 2245.01 32.91 2914.66 147.95 2766.71 PASS 6788.56 5941.39 -2762.50 695.47 6142.84 5471.28 -321.59 2284.40 33.06 2950.21 150.55 2799.65 PASS 6820.80f 5967.84 -2780.38 699.98 6214.93 5538.59 -325.89 2309.83 33.26 2966.55 152.20 2814.35 PASS 6920.801 6051.36 -2833.70 713.40 6360.30 5675.94 -334.45 2356.64 33.33 3014.53 155.46 2859.07 PASS 7020.801 6137.02 -2883.72 725.99 6521.86 5831.12 -342.53 2400.75 33.39 3058.76 158.60 2900.16 PASS 7120.80f 6224.69 -2930.36 737.74 6689.60 5994.88 -348.62 2436.39 33.34 3098.97 161.29 2937.68 PASS 7220.801 6314.21 -2973.56 748.61 6906.22 6209.23 -354.64 2466.65 33.27 3133.92 163.78 2970.14 PASS 7320.80f 6405.45 -3013.24 758.60 7051.91 6354.54 -357.08 2476.78 32.90 3163.85 165.11 2998.73 PASS 7420.801 6498.25 -3049.34 767.69 7158.65 6461.25 -356.89 2479.12 32.44 3190.55 165.97 3024.59 PASS 7520.801 6592.48 -3081.80 775.86 7265.80 6568.38 -356.43 2480.21 32.02 3214.50 166.68 3047.82 PASS 7620.801 6687.97 -3110.56 783.10 7384.10 6686.68 -356.04 2480.55 31.64 3235.53 167.30 3068.23 PASS 7720.80f 6784.58 -3135.58 789.40 7505.05 6807.63 -356.15 2479.93 31.31 3253.26 167.81 3085.45 PASS 7820.80f 6882.14 -3156.82 794.75 7617.32 6919.90 -356.73 2479.03 31.03 3267.84 168.23 3099.61 PASS 7920.80f 6980.51 -3174.25 799.14 7737.26 7039.82 -358.07 2477.66 30.80 3279.00 168.59 3110.41 PASS 8020.80f 7079.51 -3187.84 802.56 7854.70 7157.24 -360.01 2476.22 30.62 3286.91 168.89 3118.02 PASS 8120.80f 7179.00 -3197.56 805.00 7971.01 7273.51 -362.60 2474.53 30.49 3291.39 169.14 3122.26 PASS 8220.80f 7278.81 -3203.41 806.48 8084.59 7387.03 -365.66 2472.66 30.42 3292.52 169.32 3123.20 PASS 8320.80f 7378.79 -3205.36 806.97 8136.22 7438.64 -366.74 2471.91 30.39 3291.41 169.46 3121.94 PASS 8321.01 7379.00 -3205.36 806.97 8136.33 7438.75 -366.75 2471.91 30.39 3291.40 169.46 3121.94 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 9 of 30 Clearance Report 1171 it , .. NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 9 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> Facility:North Fork Unit(NAD27) Slot:North Fork#14-25(Hemlock) Well:NFU#14-25 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] [ft] [ft] [ft] [ft] Iftl [ft] Bearing Clear Dist MASD Sep Status 101 [ft] Ifti [ft] 8420.80f 7478.79 -3205.36 806.97 8242.41 7544.81 -368.25 2470.74 30.39 3289.63 169.56 3120.07 PASS 8520.80f 7578.79 -3205.36 806.97 8317.60 7619.99 -369.47 2470.08 30.39 3287.85 169.65 3118.20 PASS 8620.80f 7678.79 -3205.36 806.97 8379.21 7681.60 -369.93 2470.06 30.39 3287.18 169.74 3117.44 PASS 8720.80f 7778.79 -3205.36 806.97 8480.75 7783.13 -370.26 2470.65 30.41 3287.19 169.89 3117.31 PASS 8820.80f 7878.79 -3205.36 806.97 8554.94 7857.32 -370.59 2471.35 30.42 3287.33 170.01 3117.33 PASS 8920.80f 7978.79 -3205.36 806.97 8635.69 7938.06 -370.36 2472.83 30.44 3288.46 170.15 3118.32 PASS 9020.80f 8078.79 -3205.36 806.97 8728.16 8030.51 -370.11 2474.51 30.46 3289.63 170.32 3119.31 PASS 9120.80f 8178.79 -3205.36 806.97 8773.59 8075.92 -369.51 2475.53 30.47 3291.93 170.34 3121.58 PASS 9220.80f 8278.79 -3205.36 806.97 8871.45 8173.73 -367.38 2478.22 30.49 3295.18 170.53 3124.66 PASS 9320.80f 8378.79 -3205.36 806.97 8967.09 8269.31 -365.45 2480.92 30.52 3298.37 170.71 3127.66 PASS 9420.80f 8478.79 -3205.36 806.97 9041.69 8343.86 -363.20 2482.65 30.52 3302.12 170.78 3131.34 PASS 9520.80f 8578.79 -3205.36 806.97 9262.40 8564.50 -359.58 2483.83 30.51 3303.11 171.17 3131.94 PASS 9620.80f 8678.79 -3205.36 806.97 9385.78 8687.87 -358.87 2483.23 30.49 3303.40 171.30 3132.10 PASS 9720.801 8778.79 -3205.36 806.97 9525.18 8827.27 -359.50 2481.63 30.48 3302.39 171.42 3130.98 PASS 9820.80f 8878.79 -3205.36 806.97 9573.76 8875.84 -359.54 2480.90 30.46 3301.63 171.48 3130.16 PASS 9920.801 8978.79 -3205.36 806.97 9650.06 8952.11 -358.04 2479.54 30.43 3302.34 171.51 3130.83 PASS 10020.801 9078.79 -3205.36 806.97 9768.24 9070.25 -356.16 2477.31 30.38 3302.74 171.57 3131.17 PASS 10120.80f 9178.79 -3205.36 806.97 9875.82 9177.80 -354.74 2475.19 30.34 3302.88 171.62 3131.26 PASS 10220.80f 9278.79 -3205.36 806.97 9988.55 9290.51 -353.63 2473.05 30.30 3302.78 171.69 3131.09 PASS 10320.80f 9378.79 -3205.36 806.97 10090.50 9392.44 -353.31 2471.54 30.27 3302.30 171.78 3130.53 PASS 10420.801 9478.79 -3205.36 806.97 10182.08 9484.03 -353.55 2471.48 30.27 3302.04 171.92 3130.11 PASS 10520.80f 9578.79 -3205.36 806.97 10267.98 9569.92 -353.79 2471.81 30.28 3302.01 172.08 3129.92 PASS 10620.801 9678.79 -3205.36 806.97 10351.18 9653.11 -353.85 2472.83 30.29 3302.56 172.26 3130.30 PASS 10621.01 9679.00 -3205.36 806.97 10351.40 9653.34 -353.85 2472.84 30.29 3302.56 172.26 3130.30 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> Slot Surface Uncertainty @I SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @I SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] _ Ift] [ft] [ft] [ft] [ft] [ft] [ft] [ft] - I6in Conductor 0.00 178.00 178.00 -21.00 156.98 37.52 -90.54 37.89 -89.97 10.75in Casing Surface 0.00 2977.00 2977.00 -21.00 2760.54 37.52 -90.54 -1.63 150.18 7.625in Casing Intermediate 0.00 5297.00 5297.00 -21.00 4706.76 37.52 -90.54 -61.33 530.33 ELLPATH COMPOSITION-Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore ]ft] [ft] 0.00 2927.00 OnTrak(Standard) OnTRAK MWD<204-2992'> NFU#14-25 2927.00 5249.00 OnTrak(Standard) OnTRAK MWD<3016-5306'> NFU#14-25 5249.00 11700.00 OnTrak(Standard) OnTRAK MWD<5314- 11700'> NFU#14-25 file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 10 of 30 Clearance Report Fri� NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 10 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204-11700'> MD Reference:Glacier#1 (RKB) Offset TVD&local coordinates use Reference Wellpath settings _ (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 0.00ft file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 11 of 30 Clearance Report Fait . & NFU 42-35 Vers#9 BAKER • Cook Inlet Energy_ Closest Approach Page 11 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field _North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 Facility:North Fork Unit(NAD27) Slot:North Fork#24-26 Well:NFU#24-26 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Iftl Iftl Iftl Iftl Iftl Iftl Iftl Bearing Clear Dist MASD Sep Status 11 Iftl Iftl Iftl 20.80 20.80 0.00 0.00 20.80 20.80 61.08 -89.15 304.42 108.07 12.96 95.11 PASS 120.251 120.25 0.00 0.00 120.25 120.25 61.08 -89.15 304.42 108.07 13.20 94.87 PASS 120.801 120.80 0.00 0.00 120.80 120.80 61.08 -89.15 304.42 108.07 12.93 95.13 PASS 220.801 220.80 0.00 0.00 220.80 220.80 61.08 -89.15 304.42 108.07 13.00 95.07 PASS 320.801 320.80 0.00 0.00 320.35 320.35 61.15 -89.15 304.45 108.11 13.10 95.01 PASS 420.801 420.80 0.00 0.00 418.09 418.06 63.50 -89.23 305.44 109.56 13.27 96.29 PASS 520.801 520.80 0.00 0.00 515.56 515.36 69.16 -89.43 307.72 113.19 13.54 99.64 PASS 620.801 620.80 0.00 0.00 612.54 611.92 78.08 -89.74 311.02 119.28 13.88 105.40 PASS 720.80t 720.80 0.00 0.00 709.08 707.69 90.17 -90.16 315.00 128.19 14.25 113.94 PASS 820.801 820.80 0.00 0.00 808.10 805.76 103.95 -90.65 318.91 138.74 14.60 124.14 PASS 920.801, 920.80 0.00 0.00 907.12 903.81 117.71 -91.14 322.25 149.83 14.97 134.87 PASS 1000.00 1000.00 0.00 0.00 985.71 981.76 127.51 -93.04 323.88 158.89 15.17 143.73 PASS 1020.801 1020.80 -0.07 0.02 1006.39 1002.30 129.77 -93.97 324.10 161.35 15.33 146.02 PASS 1120.801 1120.76 -2.47 0.62 1105.66 1100.90 138.72 -100.92 324.28 175.04 15.80 159.24 PASS 1220.801 1220.58 -8.25 2.08 1204.34 1198.78 144.52 -111.89 323.28 191.84 16.35 175.49 PASS 1320.801 1320.13 -17.40 4.38 1302.00 1295.27 147.20 -126.72 321.47 211.89 16.87 195.03 PASS 1420.80t, 1419.29 -29.92 7.53 1398.26 1389.74 146.87 -145.15 319.19 235.45 17.36 218.09 PASS 1520.801- 1517.94 -45.78 11.53 1492.75 1481.63 143.66 -166.88 316.72 262.74 17.88 244.87 PASS 1620.801 1615.95 -64.97 16.36 1585.15 1570.47 137.77 -191.57 314.28 293.95 18.50 275.45 PASS 1720.801 1713.22 -87.47 22.02 1675.20 1655.87 129.43 -218.85 312.00 329.17 19.11 310.06 PASS 1820.801, 1809.62 -113.25 28.51 1762.69 1737.55 118.88 -248.33 309.98 368.40 19.89 348.51 PASS 1920.801 1905.03 -142.27 35.82 1848.88 1816.69 106.26 -280.06 308.20 411.53 20.81 390.72 PASS 2020.801 1999.34 -174.51 43.93 1936.96 1897.18 92.80 -313.16 306.82 457.61 21.91 435.70 PASS 2120.801 2092.43 -209.91 52.85 2024.10 1976.83 79.49 -345.92 305.97 506.09 23.16 482.93 PASS 2220.801 2184.19 -248.45 62.55 2110.21 2055.54 66.32 -378.28 305.53 556.75 24.54 532.20 PASS 2320.80t 2274.50 -290.07 73.03 2195.18 2133.20 53.34 -410.22 305.40 609.44 26.06 583.39 PASS 2420.801 2363.27 -334.72 84.27 2278.91 2209.73 40.54 -441.69 305.51\ 664.10 27.68 636.42 PASS 2520.801, 2450.37 -382.34 96.26 2361.29 2285.02 27.95 -472.66 305.80 720.65 29.41 691.25 PASS 2620.801 2535.71 -432.89 108.98 2442.23 2359.00 15.58 -503.08 306.23 779.08 31.23 747.85 PASS 2720.80t 2619.17 -486.29 122.43 2521.63 2431.57 3.45 -532.92 306.77 839.35 33.12 806.24 PASS 2762.33 2653.26 -509.29 128.22 2554.12 2461.26 -1.52 -545.13 307.02` 864.92 33.92 831.00 PASS 2820.801 2701.01 -542.02 136.46 2599.67 2502.90 -8.48 -562.25 307.37 901.17 35.05 866.12 PASS 2920.801 2782.68 -597.98 150.54 2677.57 2574.10 -20.39 -591.53 307.90 963.22 37.55 925.67 PASS 3020.801. 2864.35 -653.94 164.63 2755.47 2645.30 -32.29 -620.81 308.36 1025.35 38.33 987.02 PASS 3120.801. 2946.01 -709.90 178.72 2833.37 2716.50 -44.20 -650.09 308.77 1087.55 40.01 1047.54 PASS 3220.801. 3027.68 -765.87 192.81 2911.27 2787.70 -56.10 -679.37 309.14 1149.81 41.50 1108.31 PASS 3320.801, 3109.35 -821.83 206.90 2989.17 2858.90 -68.01 -708.65 309.47 1212.11 43.02 1169.08 PASS 3420.801 3191.02, -877.79 220.99 3067.07 2930.10 -79.92 -737.93 309.76 1274.45 44.58 1229.86 PASS 3520.801. 3272.69 -933.76 235.08 3144.98 3001.30 -91.82 -767.21 310.03 1336.82 46.19 1290.63 PASS 3620.801 3354.35` -989.72 249.17 3222.88 3072.50 -103.73 -796.49 310.28 1399.22 47.85 1351.37 PASS 3720.801 3436.02, -1045.68 263.26 3300.78 3143.70 -115.63 -825.77 310.50 1461.65 49.55 1412.10 PASS 3820.801- 3517.69 -1101.65 277.35 3378.68 3214.90 -127.54 -855.05 310.70 1524.10 51.29 1472.82 PASS 3920.801 3599.36 -1157.61 291.43 3456.58 3286.10 -139.45 -884.33 310.89 1586.57 53.05 1533.52 PASS 4020.801 3681.02 -1213.57 305.52 3534.48 3357.30 -151.35 -913.61 311.07 1649.06 54.85 1594.21 PASS 4120.801 3762.69 -1269.54 319.61 3612.38 3428.50 -163.26 -942.89 311.231 1711.56 56.68 1654.88 PASS file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 12 of 30 Clearance Report FAILS NFU 42-35 Vers#9 BAKER _ s Cook Inlet Energy_ Closest Approach Page 12 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 • Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 Facility:North Fork Unit(NAD27) Slot:North Fork#24-26 Well:NFU#24-26 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Ifti [ft] lftl [ft] Iftl [ft! Iftl Bearing Clear Dist MASD Sep Status 1°I lftl Iftl Iftl 4220.80t 3844.36 -1325.50 333.70 3690.28 3499.70 -175.16 -972.17 311.38 1774.08 58.53 1715.55 PASS 4320.80t 3926.03 -1381.46 347.79 3768.18 3570.90 -187.07 -1001.45 311.52 1836.61 60.40 1776.21 PASS 4420.80t 4007.69 -1437.43 361.88 3846.08 3642.10 -198.97 -1030.73 311.65 1899.15 62.30 1836.85 PASS 4520.80t 4089.36 -1493.39 375.97 3923.98 3713.30 -210.88 -1060.01 311.77 1961.70 64.21 1897.49 PASS 4620.80t 4171.03 -1549.35 390.06 4001.88 3784.50 -222.79 -1089.29 311.88 2024.26 66.14 1958.12 PASS 4720.80t 4252.70 -1605.32 404.15 4079.78 3855.70 -234.69 -1118.57 311.99 2086.83 68.08 2018.75 PASS 4820.80t 4334.37 -1661.28 418.24 4157.69 3926.90 -246.60 -1147.85 312.09 2149.41 70.04 2079.37 PASS 4920.80t 4416.03 -1717.24 432.33 4235.59 3998.10 -258.50 -1177.13 312.19 2211.99 72.02 2139.98 PASS 5020.80t 4497.70 -1773.21 446.41 4313.49 4069.30 -270.41 -1206.40 312.28 2274.59 74.00 2200.58 PASS 5120.80t 4579.37 -1829.17 460.50 4391.39 4140.50 -282.32 -1235.68 312.36 2337.18 76.00 2261.18 PASS 5220.80t 4661.04 -1885.13 474.59 4469.29 4211.70 -294.22 -1264.96 312.44 2399.78 78.00 2321.78 PASS 5320.80t 4742.70 -1941.10 488.68 4547.19 4282.90 -306.13 -1294.24 312.52 2462.39 80.02 2382.37 PASS 5420.80t 4824.37 -1997.06 502.77 4625.09 4354.10 -318.03 -1323.52 312.59 2525.00 82.04 2442.96 PASS 5520.80t 4906.04 -2053.02 516.86 4702.99 4425.30 -329.94 -1352.80 312.66 2587.62 84.08 2503.54 PASS 5620.80t 4987.71 -2108.99 530.95 4780.89 4496.50 -341.84 -1382.08 312.73 2650.24 86.12 2564.12 PASS 5720.80t 5069.37 -2164.95 545.04 4858.79 4567.70 -353.75 -1411.36 312.79 2712.86 88.16 2624.70 PASS 5820.80t 5151.04 -2220.91 559.13 4936.69 4638.91 -365.66 -1440.64 312.85 2775.49 90.22 2685.27 PASS 5920.80t 5232.71 -2276.88 573.22 5014.59 4710.11 -377.56 -1469.92 312.91 2838.12 92.28 2745.84 PASS 6020.80t 5314.38 -2332.84 587.31 5092.49 4781.31 -389.47 -1499.20 312.97 2900.75 94.35 2806.41 PASS 6120.80t 5396.04 -2388.80 601.39 5170.39 4852.51 -401.37 -1528.48 313.02 2963.39 96.42 2866.97 PASS 6220.80t 5477.71 -2444.77 615.48 5248.30 4923.71 -413.28 -1557.76 313.07 3026.03 98.49 2927.53 PASS 6320.80t 5559.38 -2500.73 629.57 5326.20 4994.91 -425.19 -1587.04 313.12 3088.67 100.58 2988.09 PASS 6420.80t 5641.05 -2556.69 643.66 5404.10 5066.11 -437.09 -1616.32 313.16 3151.32 102.66 3048.65 PASS 6520.80t 5722.72 -2612.66 657.75 5482.00 5137.31 -449.00 -1645.60 313.21 3213.96 104.75 3109.21 PASS 6620.80t 5804.38 -2668.62 671.84 5645.06 5287.59 -472.80 -1704.15 312.74 3276.28 108.72 3167.56 PASS 6720.80t 5886.05 -2724.58 685.93 6000.68 5630.14 -508.05 -1790.84 311.83 3333.59 114.90 3218.69 PASS 6788.56 5941.39 -2762.50 695.47 6249.03 5876.85 -518.18 -1815.75 311.79 3368.58 117.25 3251.34 PASS 6820.801- 5967.84 -2780.38 699.98 6340.04 5967.84 -518.86 -1817.42 311.94 3384.04 117.76 3266.28 PASS 6920.80t 6051.36 -2833.70 713.40 6423.56 6051.36 -518.86 -1817.42 312.45 3429.80 118.60 3311.20 PASS 7020.80t 6137.02 -2883.72 725.99 6509.22 6137.02 -518.86 -1817.42 312.92 3472.96 119.39 3353.58 PASS 7120.80t 6224.69 -2930.36 737.74 6596.88 6224.69 -518.86 -1817.42 313.34 3513.43 120.13 3393.30 PASS 7220.80t 6314.21 -2973.56 748.61 6686.41 6314.21 -518.86 -1817.42 313.73 3551.07 120.83 3430.24 PASS 7320.80t 6405.45 -3013.24 758.60 6777.64 6405.45 -518.86 -1817.42 314.08 3585.78 121.48 3464.30 PASS 7420.80t 6498.25 -3049.34 767.69 6870.45 6498.25 -518.86 -1817.42 314.39 3617.47 122.09 3495.39 PASS 7520.80t 6592.48 -3081.80 775.86 6964.68 6592.48 -518.86 -1817.42 314.66 3646.06 122.65 3523.40 PASS 7620.80t 6687.97 -3110.56 783.10 7060.17 6687.97 -518.86 -1817.42 314.90 3671.46 123.18 3548.28 PASS 7720.80t 6784.58 -3135.58 789.40 7156.78 6784.58 -518.86 -1817.42 315.11 3693.61 123.67 3569.94 PASS 7820.80t 6882.14 -3156.82 794.75 7254.34 6882.14 -518.86 -1817.42 315.28 3712.45 124.11 3588.34 PASS 7920.80t 6980.51 -3174.25 799.14 7352.71 6980.51 -518.86 -1817.42 315.42 3727.93 124.52 3603.41 PASS 8020.80t 7079.51 -3187.84 802.56 7451.71 7079.51 -518.86 -1817.42 315.53 3740.02 124.89 3615.13 PASS 8120.80t 7179.00 -3197.56 805.00 7551.20 7179.00 -518.86 -1817.42 315.61 3748.67 125.22 3623.45 PASS 8220.801- 7278.81 -3203.41 806.48 7651.01 7278.81 -518.86 -1817.42 315.66 3753.88 125.52 3628.36 PASS 8320.80t 7378.79 -3205.36 806.97 7750.99 7378.79 -518.86 -1817.42 315.67 3755.62 125.77 3629.85 PASS 8321.01 7379.00 -3205.36 806.97 7751.20 7379.00 -518.86 -1817.42 315.67 3755.62 125.77 3629.85 PASS 8420.80t 7478.79 -3205.36 806.97 7850.99 7478.79 -518.86 -1817.42 315.67 3755.62 125.99 3629.63 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 13 of 30 Clearance Report rail , , NFU 42-35 Vers#9 BAKER ' `'Cook Inlet Energy_ Closest Approach Page 13 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 Facility:North Fork Unit(NAD27) Slot:North Fork#24-26 Well:NFU#24-26 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft! [ft] Iftl Iftl Ift] [ft] [ft] Bearing Clear Dist MASD Sep Status 101 Iftl [ft' IN 8520.80t 7578.79 -3205.36 806.97 7950.99 7578.79 -518.86 -1817.42 315.67 3755.62 126.21 3629.42 PASS 8620.80t 7678.79 -3205.36 806.97 8050.99 7678.79 -518.86 -1817.42 315.67 3755.62 126.43 3629.19 PASS 8720.80t 7778.79 -3205.36 806.97 8150.99 7778.79 -518.86 -1817.42 315.67 3755.62 126.66 3628.97 PASS 8820.80t 7878.79 -3205.36 806.97 8250.99 7878.79 -518.86 -1817.42 315.67 3755.62 126.89 3628.74 PASS 8920.80t 7978.79 -3205.36 806.97 8350.99 7978.79 -518.86 -1817.42 315.67 3755.62 127.12 3628.50 PASS 9020.80t 8078.79 -3205.36 806.97 8450.99 8078.79 -518.86 -1817.42 315.67 3755.62 127.36 3628.26 PASS 9120.80t 8178.79 -3205.36 806.97 8550.99 8178.79 -518.86 -1817.42 315.67 3755.62 127.60 3628.02 PASS 9220.80t 8278.79 -3205.36 806.97 8650.99 8278.79 -518.86 -1817.42 315.67 3755.62 127.84 3627.78 PASS 9320.80t 8378.79 -3205.36 806.97 8750.99 8378.79 -518.86 -1817.42 315.67 3755.62 128.09 3627.53 PASS 9420.80t 8478.79 -3205.36 806.97 8850.99 8478.79 -518.86 -1817.42 315.67 3755.62 128.34 3627.28 PASS 9520.80t 8578.79 -3205.36 806.97 8950.99 8578.79 -518.86 -1817.42 315.67 3755.62 128.60 3627.02 PASS 9620.80t 8678.79 -3205.36 806.97 9050.99 8678.79 -518.86 -1817.42 315.67 3755.62 128.86 3626.76 PASS 9720.80t 8778.79 -3205.36 806.97 9150.99 8778.79 -518.86 -1817.42 315.67 3755.62 129.12 3626.50 PASS 9820.80t 8878.79 -3205.36 806.97 9250.99 8878.79 -518.86 -1817.42 315.67 3755.62 129.39 3626.24 PASS 9920.80t 8978.79 -3205.36 806.97 9350.99 8978.79 -518.86 -1817.42 315.67 3755.62 129.66 3625.97 PASS 10020.80t 9078.79 -3205.36 806.97 9450.99 9078.79 -518.86 -1817.42 315.67 3755.62 129.93 3625.69 PASS 10120.80t 9178.79 -3205.36 806.97 9550.99 9178.79 -518.86 -1817.42 315.67 3755.62 130.21 3625.42 PASS 10220.80t 9278.79 -3205.36 806.97 9650.99 9278.79 -518.86 -1817.42 315.67 3755.62 130.49 3625.14 PASS 10320.80t 9378.79 -3205.36 806.97 9750.99 9378.79 -518.86 -1817.42 315.67 3755.62 130.77 3624.85 PASS 10420.80t 9478.79 -3205.36 806.97 9850.99 9478.79 -518.86 -1817.42 315.67 3755.62 131.05 3624.57 PASS 10520.80t 9578.79 -3205.36 806.97 9950.99 9578.79 -518.86 -1817.42 315.67 3755.62 131.34 3624.28 PASS 10620.80t 9678.79 -3205.36 806.97 10000.20 9628.00 -518.86 -1817.42 315.67 3755.97 131.48 3624.48 PASS 10621.01 9679.00 -3205.36 806.97 10000.20 9628.00 -518.86 -1817.42 315.67 3755.97 131.48 3624.49 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 Slot Surface Uncertainty @I SD Horizontal 2.00011 Vertical 1.000ft Facility Surface Uncertainty @ISD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] 16in Conductor 20.80 120.25 99.45 20.80 120.25 37.24 -54.34 37.24 -54.34 12.25in Open Hole 20.80 2870.03 2849.23 20.80 2750.00 37.24 -54.34 3.44 -229.52 9.625in Casing Surface 20.80 2870.03 2849.23 20.80 2750.00 37.24 -54.34 3.44 -229.52 8.75in Open Hole 2870.25 10000.20 7129.95 2750.20 9628.00 3.43 -229.55 -139.53 -581.12 7in Casing Production 20.80 10000.20 9979.40 20.80 9628.00 37.24 -54.34 -139.53 -581.12 SURVEY PROGRAM-Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ft] 20.80 2870.25 OnTrak(Standard) NFU#24-26 Wellplan 2870.25 10000.25 OnTrak(Standard) NFU#24-26 Wellplan file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 14 of 30 Clearance Report Irak NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 14 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#24-26 Wellplan Offset Wellpath:NFU#24-26 Ver#3 MD Reference:CIE 37(RT) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 20.80ft file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 15 of 30 Clearance Report Irak . . NFU 42-35 Vers#9 BAKER _ _Cook Inlet Energy_ Closest Approach Page 15 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> Facility:North Fork Unit NAD27) Slot:North Fork#22-35 Well:NF#22-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Iftl IftI Iftl IftI Iftl Iftl Iftl Bearing Clear Dist MASD Sep Status 11 IRI WWI Iftl 20.80 20.80 0.00 0.00 20.55 20.80 0.54 -120.07 270.26 120.07 13.11 106.96 PASS 120.801 120.80 0.00 0.00 120.18 120.43 1.01 -120.22 270.48 120.22 12.99 107.24 PASS 220.801 220.80 0.00 0.00 219.70 219.94 2.28 -120.68 271.08 120.71 13.05 107.66 PASS 320.801 320.80 0.00 0.00 319.60 319.82 3.39 -121.53 271.60 121.58 13.16 108.42 PASS 420.801 420.80 0.00 0.00 419.63 419.85 4.63 -122.20 272.17 122.29 13.31 108.99 PASS 520.801 520.80 0.00 0.00 519.59 519.80 5.82 -122.98 272.71 123.12 13.50 109.63 PASS 620.801 620.80 0.00 0.00 620.93 621.14 5.60 -123.37 272.60 123.50 13.80 109.70 PASS 720.801- 720.80 0.00 0.00 720.66 720.84 3.48 -123.16 271.62 123.21 14.30 108.92 PASS 820.801 820.80 0.00 0.00 815.32 815.42 0.43 -125.24 270.20 125.36 14.69 110.67 PASS 920.801 920.80 0.00 0.00 911.90 911.73 -4.45 -130.59 268.05 130.98 15.38 115.59 PASS 1000.00 1000.00 0.00 0.00 989.23 988.61 -10.61 -136.10 265.54 136.98 15.67 121.31 PASS 1020.80t 1020.80 -0.07 0.02 1009.29 1008.50_ -12.67 -137.63 264.77 138.77 15.74 123.03 PASS 1120.801 1120.76 -2.47 0.62 1103.29 1101.21 -25.43 -146.27 261.12 149.95 16.08 133.87 PASS 1220.801 1220.58 -8.25 2.08 1196.04 1191.78 -41.95 -157.44 258.07 165.56 16.62 148.94 PASS 1320.801. 1320.13 -17.40 4.38 1292.15 1284.82 -62.27 -170.42 255.60 183.89 17.25 166.63 PASS 1420.80t 1419.29 -29.92 7.53 1386.12 1375.07 -84.73 -183.82 254.02 203.90 17.81 186.09 PASS 1520.801 1517.94 -45.78 11.53 1476.73 1461.32 -108.29 -198.52 253.43 226.34 18.48 207.86 PASS 1620.801 1615.95 -64.97 16.36 1565.54 1544.96 -133.00 -215.29 253.64 251.65 19.32 232.33 PASS 1720.801 1713.22 -87.47 22.02 1654.69 1627.96 -159.40 -234.27 254.32 279.51 20.31 259.20 PASS 1820.801 1809.62 -113.25 28.51 1743.11 1709.25 -187.67 -254.53 255.27 309.39 21.43 287.96 PASS 1920.80t 1905.03 -142.27 35.82 1828.28 1786.25 -217.56 -275.27 256.40 341.40 22.69 318.71 PASS 2020.801 1999.34 -174.51 43.93 1909.84 1858.47 -248.76 -296.75 257.70 376.06 24.10 351.96 PASS 2120.801 2092.43 -209.91 52.85 1990.37 1928.46 -281.03 -320.11 259.21 413.57 25.73 387.85 PASS 2220.801 2184.19 -248.45 62.55 2070.63 1997.23 -313.88 -345.23 260.88 453.34 27.57 425.77 PASS 2320.801 2274.50 -290.07 73.03 2149.52 2063.48 -347.92 -371.24 262.58 495.23 29.56 465.67 PASS 2420.801 2363.27 -334.72 84.27 2229.95 2129.54 -384.73 -398.62 264.09 538.81 31.79 507.01 PASS 2520.801 2450.37 -382.34 96.26 2316.02 2199.11 -425.76 -428.36 265.27 583.30 34.39 548.91 PASS 2620.80t 2535.71 -432.89 108.98 2402.63 2268.76 -467.54 -458.42 266.51 628.02 37.21 590.81 PASS 2720.80t 2619.17 -486.29 122.43 2486.47 2336.08 -507.91 -487.88 267.97 673.11 40.16 632.95 PASS 2762.33 2653.26 -509.29 128.22 2520.62 2363.44 -524.32 -500.05 268.63 692.05 41.43 650.62 PASS 2820.80t 2701.01 -542.02 136.46 2573.19 2405.55 -549.60 -518.81 269.34 718.84 43.38 675.45 PASS 2920.801 2782.68 -597.98 150.54 2662.25 2476.88 -592.62 -550.32 270.44 764.69 46.40 718.30 PASS 3020.801, 2864.35 -653.94 164.63 2746.49 2544.38 -633.24 -580.15 271.59 810.86 49.29 761.58 PASS 3120.801 2946.01 -709.90 178.72 2825.50 2607.47 -671.23 -608.75 272.81 858.03 52.08 805.95 PASS 3220.801 3027.68 -765.87 192.81 2906.72 2671.93 -710.55 -638.67 273.81 906.08 55.00, 851.08 PASS 3320.801 3109.35 -821.83 206.90 2994.36 2741.31 -753.08 -671.22 274.48 954.60 57.90' 896.70 PASS 3420.801 3191.02 -877.79 220.99 3081.59 2810.76 -794.87 -703.47 275.13 1003.04 60.81 942.23 PASS 3520.801 3272.69 -933.76 235.08 3170.97 2882.23, -837.14 -736.54 275.68 1051.59 63.73 987.86 PASS 3620.801 3354.35 -989.72 249.17 3262.88 2955.93 -880.49 -770.24 276.12 1099.94 66.7T 1033.17 PASS 3720.801 3436.02 -1045.68 263.26 3359.78 3033.5T -926.79 -805.12 276.35 1147.84 70.01 1077.83 PASS 3820.801- 3517.69 -1101.65 277.35 3450.66 3106.11 -971.18 -837.20 276.68 1195.25 73.11 1122.14 PASS 3920.801 3599.36 -1157.61 291.43 3550.28 3185.59' -1020.21 -871.85 276.74 1242.30 76.52 1165.78 PASS 4020.80t 3681.02 -1213.57 305.52 3647.20 3262.68 -1068.96 -904.64 276.81 1288.58 79.89' 1208.69 PASS 4120.80t 3762.69 -1269.54 319.61 3744.54 3340.37 -1117.86 -937.01 276.88 1334.33 83.31 1251.03 PASS 4220.80f 3844.36 -1325.50 333.70 3843.30 3419.53 -1167.35 -969.20 276.92 1379.51 86.78 1292.73 PASS file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 16 of 30 Clearance Report rd` NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 16 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork _Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> Facility:North Fork Unit(NAD27) Slot:North Fork#22-35 Well:NF#22-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Iftl Iftl Iftl Iftl IRI IRI Iftl Bearing Clear Dist MASD Sep Status 1°1 Iftl Iftl Iftl 4320.801 3926.03 -1381.46 347.79 3911.39 3474.11 -1201.38 -991.56 277.66 1424.96 89.37 1335.59 PASS 4420.80t 4007.69 -1437.43 361.88 3981.57 3529.95 -1236.37 -1015.69 278.30 1471.86 92.02 1379.84 PASS 4520.80t 4089.36 -1493.39 375.97 4066.12 3597.26 -1278.07 -1045.36 278.62 1519.44 95.13 1424.30 PASS 4620.80t 4171.03 -1549.35 390.06 4167.81 3678.61 -1327.94 -1080.51 278.56 1566.55 98.79 1467.76 PASS 4720.801 4252.70 -1605.32 404.15 4257.29 3750.40 -1371.80 -1111.02 278.76 1613.24 102.08 1511.16 PASS 4820.80t 4334.37 -1661.28 418.24 4336.09 3813.43 -1410.54 -1138.12 279.15 1660.27 105.04 1555.24 PASS 4920.80t 4416.03 -1717.24 432.33 4416.19 3877.40 -1449.81 -1166.06 279.50 1707.77 108.04 1599.72 PASS 5020.801 4497.70 -1773.21 446.41 4489.02 3935.49 -1485.35 -1191.89 279.97 1755.84 110.82 1645.03 PASS 5120.801 4579.37 -1829.17 460.50 4573.09 4002.36 -1526.30 -1222.25 280.20 1804.53 113.97 1690.56 PASS 5220.80t 4661.04 -1885.13 474.59 4671.47 4080.87 -1573.97 -1257.48 280.18 1852.97 117.61 1735.36 PASS 5320.801 4742.70 -1941.10 488.68 4755.39 4147.99 -1614.66 -1287.18 280.42 1901.04 120.77 1780.27 PASS 5420.801 4824.37 -1997.06 502.77 4828.77 4206.54 -1650.12 -1313.60 280.81 1949.69 123.57 1826.12 PASS 5520.801 4906.04 -2053.02 516.86 4904.29 4266.49 -1686.78 -1341.26 281.15 1998.94 126.46 1872.49 PASS 5620.801 4987.71 -2108.99 530.95 5001.02 4342.94 -1734.27 -1376.70 281.11 2048.23 130.09 1918.14 PASS 5720.801 5069.37 -2164.95 545.04 5103.14 4423.89 -1784.55 -1413.42 280.99 2096.88 133.92 1962.96 PASS 5820.801 5151.04 -2220.91 559.13 5175.88 4481.60 -1820.23 -1439.64 281.34 2145.64 136.74 2008.90 PASS 5920.80t 5232.71 -2276.88 573.22 5253.79 4543.49 -1858.03 -1468.13 281.60 2194.89 139.72 2055.17 PASS 6020.801 5314.38 -2332.84 587.31 5330.45 4604.62 -1894.60 -1496.45 281.88 2244.51 142.66 2101.85 PASS 6120.801 5396.04 -2388.80 601.39 5408.96 4666.78 -1932.54 -1525.78 282.11 2294.53 145.68 2148.86 PASS 6220.80t 5477.71 -2444.77 615.48 5493.66 4733.48 -1973.93 -1557.60 282.23 2344.75 148.92 2195.82 PASS 6320.80t 5559.38 -2500.73 629.57 5586.65 4806.83 -2019.24 -1592.43 282.23 2394.88 152.47 2242.41 PASS 6420.801 5641.05 -2556.69 643.66 5688.21 4887.28 -2068.53 -1630.02 282.12 2444.60 156.32 2288.28 PASS 6520.80f 5722.72 -2612.66 657.75 5780.10 4960.58 -2112.64 -1663.56 282.16 2493.86 159.83 2334.04 PASS 6620.801 5804.38 -2668.62 671.84 5857.00 5021.95 -2149.35 -1691.85 282.39 2543.39 162.79 2380.60 PASS 6720.80t 5886.05 -2724.58 685.93 5989.74 5127.46 -2214.15 -1739.65 281.88 2592.18 167.75 2424.43 PASS 6788.56 5941.39 -2762.50 695.47 6058.12 5182.06 -2247.67 -1763.55 281.83 2624.58 170.35 2454.23 PASS 6820.801 5967.84 -2780.38 699.98 6080.97 5200.29 -2258.90 -1771.56 281.91 2639.99 171.24 2468.75 PASS 6920.80t 6051.36 -2833.70 713.40 6157.14 5260.75 -2296.56 -1798.53 282.07 2687.63 174.10 2513.53 PASS 7020.80t 6137.02 -2883.72 725.99 6252.02 5336.19 -2343.25 -1832.17 281.93 2734.52 177.48 2557.05 PASS 7120.801 6224.69 -2930.36 737.74 6354.95 5418.38 -2393.65 -1868.23 281.64 2780.15 180.98 2599.17 PASS 7220.801 6314.21 -2973.56 748.61 6440.06 5486.68 -2434.93 -1897.79 281.50 2824.60 183.72 2640.88 PASS 7320.801 6405.45 -3013.24 758.60 6498.87 5533.57 -2463.65 -1918.63 281.60 2868.76 185.40 2683.35 PASS 7420.801 6498.25 -3049.34 767.69 6578.79 5596.85 -2503.00 -1947.54 281.38 2912.64 187.68 2724.96 PASS 7520.801 6592.48 -3081.80 775.86 6679.77 5676.87 -2552.70 -1983.92 280.85 2955.45 190.56 2764.89 PASS 7620.801 6687.97 -3110.56 783.10 6788.60 5763.15 -2606.67 -2022.48 280.18 2996.75 193.55 2803.20 PASS 7720.801 6784.58 -3135.58 789.40 6884.37 5839.51 -2653.78 -2055.95 279.61 3036.66 195.91 2840.75 PASS 7820.801 6882.14 -3156.82 794.75 6976.73 5913.69 -2698.48 -2088.06 279.03 3075.48 197.97 2877.51 PASS 7920.801 6980.51 -3174.25 799.14 7073.90 5992.20 -2744.84 -2121.64 278.36 3113.21 200.00 2913.21 PASS 8020.801 7079.51 -3187.84 802.56 7176.79 6075.86 -2793.34 -2156.79 277.59 3149.71 202.04 2947.67 PASS 8120.80t 7179.00 -3197.56 805.00 7341.39 6211.63 -2869.22 -2210.63 276.21 3183.97 205.77 2978.20 PASS 8220.80t 7278.81 -3203.41 806.48 7490.25 6338.10 -2932.72 -2256.73 275.05 3215.81 208.64 3007.18 PASS 8320.80t 7378.79 -3205.36 806.97 8103.72 6900.16 -3131.73 -2393.08 271.32 3236.48 220.55 3015.94 PASS 8321.01 7379.00 -3205.36 806.97 8104.04 6900.46 -3131.80 -2393.13 271.32 3236.52 220.55 3015.96 PASS 8420.801 7478.79 -3205.36 806.97 8444.67 7233.62 -3188.93 -2432.65 270.29 3248.93 223.62 3025.31 PASS 8520.801 7578.79 -3205.36 806.97 8760.41 7548.42 -3207.46 -2444.63 269.96 3251.74 224.75 3026.99 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 17 of 30 Clearance Report rail 4 . NFU 42-35 Vers#9 BAKER • Cook Inlet Energy_ Closest Approach Page 17 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> Facility:North Fork Unit(NAD27) Slot:North Fork#22-35 Well:NF#22-35 Threshold Value�.00 ft t=interpolated/extrapolated station Ref MI) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [HI [ft] [ft] Ift] [ftI Ift] Iftl [ft] Bearing Clear Dist MASD Sep Status 101 IRI [ft] [ft] 8620.80f 7678.79 -3205.36 806.97 8886.31 7674.31 -3208.72 -2445.07 269.94 3252.05 224.94 3027.10 PASS 8720.80f 7778.79 -3205.36 806.97 8987.31 7775.31 -3209.35 -2445.20 269.93 3252.17 225.11 3027.06 PASS 8820.80j 7878.79 -3205.36 806.97 9089.12 7877.12 -3209.87 -2445.28 269.92 3252.25 225.27 3026.98 PASS 8920.80f 7978.79 -3205.36 806.97 9194.76 7982.76 -3210.33 -2445.26 269.91 3252.23 225.44 3026.79 PASS 9020.80f 8078.79 -3205.36 806.97 9300.94 8088.94 -3210.69 -2445.02 269.91 3252.01 225.59 3026.42 PASS 9120.80f 8178.79 -3205.36 806.97 9403.32 8191.31 -3210.88 -2444.67 269.90 3251.67 225.73 3025.94 PASS 9220.80t 8278.79 -3205.36 806.97 9511.52 8299.51 -3210.92 -2444.12 269.90 3251.15 225.85 3025.31 PASS 9320.80f, 8378.79 -3205.36 806.97 9618.43 8406.42 -3210.78 -2443.31 269.91 3250.40 225.96 3024.44 PASS 9420.80f 8478.79 -3205.36 806.97 9723.98 8511.97 -3210.42 -2442.34 269.91 3249.48 226.06 3023.42 PASS 9520.80f 8578.79 -3205.36 806.97 9832.29 8620.26 -3209.73 -2441.09 269.92 3248.33 226.16 3022.17 PASS 9620.80f 8678.79 -3205.36 806.97 9924.95 8712.92 -3208.97 -2439.92 269.94 3247.06 226.28 3020.79 PASS 9720.80f 8778.79 -3205.36 806.97 10013.01 8800.97 -3208.86 -2439.21 269.94 3246.26 226.41 3019.85 PASS 9820.80f 8878.79 -3205.36 806.97 10110.39 8898.34 -3209.09 -2438.58 269.93 3245.60 226.56 3019.04 PASS 9920.80f 8978.79 -3205.36 806.97 10199.68 8987.63 -3209.79 -2438.13 269.92 3245.11 226.73 3018.38 PASS 10020.80f 9078.79 -3205.36 806.97 10281.06 9069.01 -3210.69 -2438.15 269.91 3245.13 226.92 3018.21 PASS 10120.80f 9178.79 -3205.36 806.97 10366.58 9154.52 -3211.75 -2438.62 269.89 3245.69 227.11 3018.58 PASS 10220.80f 9278.79 -3205.36 806.97 10474.37 9262.30 -3213.03 -2439.27 269.87 3246.29 227.32 3018.97 PASS 10320.80f 9378.79 -3205.36 806.97 10576.35 9364.28 -3213.75 -2439.78 269.85 3246.79 227.51 3019.28 PASS 10420.80f 9478.79 -3205.36 806.97 10681.50 9469.42 -3213.98 -2440.13 269.85 3247.13 227.70 3019.43 PASS 10520.80f 9578.79 -3205.36 806.97 10700.00 9487.93 -3214.01 -2440.19 269.85 3248.44 227.77 3020.66 PASS 10620.80f 9678.79 -3205.36 806.97 10700.00 9487.93 -3214.01 -2440.19 269.85 3252.77 227.65 3025.12 PASS 10621.01 9679.00 -3205.36 806.97 10700.00 9487.93 -3214.01 -2440.19 269.85 3252.78 227.65 3025.14 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> Slot Surface Uncertainty @1 SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] IftI [ft] [ft] [ft! [ftl [ft] [ft] 10.75in Casing Surface 20.55 2992.00 2971.45 20.55 2739.19 0.33 -73.20 -229.03 -240.92 7in Casing Production 20.55 10673.00 10652.45 20.55 9460.68 0.33 -73.20 -979.45 -780.35 ELLPATH COMPOSITION-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] Iftl 20.55 2945.00 NaviTrak(MagCorr) NaviTrak MWD<181-2945'> NF#22-35 2945.00 10700.00 OnTrak(MagCorr) OnTrak MWD<3044- 10700'> NF#22-35 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<181-2945'>OnTrakMWD<3044-10700'> MD Reference:Nabors 99(RTE) Offset TVD&local coordinates use Reference Wellpath settings file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 18 of 30 II(See WELLPATH DATUM on page 1 of this ret,„rt) Ellipse Start MD I20.55ft file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 19 of 30 Clearance Report raki, , NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 18 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> Facility:North Fork Unit(NAD27) Slot:North Fork#32-35(Tyonek) Well:NFU#32-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] IftI [ftI [ft] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status 101 Iftl [ft] [ft] 20.80 20.80 0.00 0.00 20.07 20.17 61.66 -208.68 286.46 217.60 13.37 204.23 PASS 120.80f 120.80 0.00 0.00 116.98 117.06 60.90 -209.91 286.18 218.60 13.21 205.39 PASS 220.80f 220.80 0.00 0.00 214.33 214.35 59.09 -212.87 285.51 221.01 13.20 207.81 PASS 320.80f 320.80 0.00 0.00 313.83 313.76 56.89 -216.57 284.72 224.02 13.40 210.62 PASS 420.80f 420.80 0.00 0.00 415.21 415.04 54.12 -220.25 283.81 226.87 13.57 213.30 PASS 520.80f 520.80 0.00 0.00 515.35 515.01 49.66 -223.83 282.51 229.34 13.79 215.55 PASS 620.80f 620.80 0.00 0.00 614.90 614.19 42.22 -228.01 280.49 231.98 14.06 217.92 PASS 720.80f 720.80 0.00 0.00 713.03 711.60 31.55 -233.06 277.71 235.36 14.40 220.97 PASS 820.80f 820.80 0.00 0.00 811.82 809.06 16.55 -238.91 273.96 239.77 14.81 224.96 PASS 920.80f 920.80 0.00 0.00 910.83 906.06 -2.37 -244.82 269.45 245.28 15.32 229.96 PASS 1000.00 1000.00 0.00 0.00 987.81 980.75 -20.48 -249.03 265.30 250.62 15.76 234.85 PASS 1020.80f 1020.80 -0.07 0.02 1007.25 999.49 -25.57 -250.09 264.18 252.30 15.89 236.41 PASS 1120.80f 1120.76 -2.47 0.62 1099.18 1087.34 -52.08 -255.50 259.04 263.01 16.52 246.49 PASS 1220.80f 1220.58 -8.25 2.08 1189.91 1172.70 -82.18 -261.62 254.34 278.02 17.21 260.80 PASS 1320.80f 1320.13 -17.40 4.38 1278.48 1254.75 -114.86 -268.28 250.33 296.85 17.95 278.90 PASS 1420.80f 1419.29 -29.92 7.53 1365.07 1333.58 -149.82 -276.00 247.08 319.55 18.74 300.81 PASS 1520.80f 1517.94 -45.78 11.53 1449.99 1409.32 -187.26 -284.45 244.45 345.57 19.59 325.98 PASS 1620.80f 1615.95 -64.97 16.36 1535.25 1483.68 -227.98 -293.49 242.25 374.27 20.55 353.72 PASS 1720.80f 1713.22 -87.47 22.02 1616.72 1552.94 -269.93 -302.39 240.65 405.24 21.54 383.70 PASS 1820.80f 1809.62 -113.25 28.51 1697.31 1619.66 -314.08 -312.04 239.47 438.63 22.65 415.98 PASS 1920.80f 1905.03 -142.27 35.82 1777.63 1684.58 -360.20 -322.44 238.69 473.75 23.88 449.87 PASS 2020.80f 1999.34 -174.51 43.93 1856.07 1746.03 -407.84 -332.74 238.22 510.38 25.21 485.17 PASS 2120.80f 2092.43 -209.91 52.85 1939.44 1809.54 -460.71 -343.83 237.70 547.97 26.79 521.19 PASS 2220.80f 2184.19 -248.45 62.55 2030.26 1878.16 -518.92 -356.08 237.13 584.86 28.69 556.16 PASS 2320.80f 2274.50 -290.07 73.03 2122.94 1947.93 -578.58 -368.79 236.86 620.56 30.83 589.73 PASS 2420.80f 2363.27 -334.72 84.27 2219.01 2020.13 -640.65 -381.64 236.71 654.53 33.23 621.30 PASS 2520.80f 2450.37 -382.34 96.26 2323.13 2099.11 -707.17 -395.01 236.53 685.74 36.04 649.70 PASS 2620.80f 2535.71 -432.89 108.98 2417.97 2171.38 -767.40 -406.95 237.04 714.72 38.86 675.86 PASS 2720.80f 2619.17 -486.29 122.43 2507.60 2239.52 -824.50 -418.40 237.98 742.30 41.79 700.52 PASS 2762.33 2653.26 -509.29 128.22 2543.76 2266.91 -847.58 -423.31 238.48 753.58 43.05 710.54 PASS 2820.80f 2701.01 -542.02 136.46 2596.81 2306.99 -881.54 -430.76 239.10 769.58 44.91 724.67 PASS 2920.80f 2782.68 -597.98 150.54 2693.37 2379.86 -943.44 -444.26 239.85 797.12 47.96 749.16 PASS 3020.80f 2864.35 -653.94 164.63 2782.36 2446.95 -1000.47 -457.08 240.87 825.12 50.85 774.27 PASS 3120.80f 2946.01 -709.90 178.72 2873.81 2516.25 -1058.36 -471.57 241.82 853.81 53.92 799.89 PASS 3220.80f 3027.68 -765.87 192.81 2965.13 2585.24 -1116.32 -486.40 242.71 883.12 57.07 826.04 PASS 3320.80f 3109.35 -821.83 206.90 3057.86 2655.08 -1175.45 -501.42 243.47 912.76 60.32 852.44 PASS 3420.80f 3191.02 -877.79 220.99 3152.44 2726.02 -1236.10 -516.73 244.09 942.78 63.67 879.10 PASS 3520.80f 3272.69 -933.76 235.08 3251.85 2800.64 -1299.86 -532.52 244.50 972.66 66.92 905.74 PASS 3620.80f 3354.35 -989.72 249.17 3352.69 2876.79 -1364.09 -548.14 244.85 1001.96 70.20 931.76 PASS 3720.80f 3436.02 -1045.68 263.26 3444.90 2946.09 -1423.27 -562.19 245.42 1031.48 73.29 958.19 PASS 3820.801 3517.69 -1101.65 277.35 3546.80 3022.60 -1488.86 -577.25 245.63 1060.84 76.67 984.17 PASS 3920.80f 3599.36 -1157.61 291.43 3651.49 3101.78 -1555.69 -592.27 245.75 1089.49 80.19 1009.30 PASS 4020.80f 3681.02 -1213.57 305.52 3756.17 3181.56 -1621.87 -606.90 245.89 1117.44 83.78 1033.67 PASS 4120.80f 3762.69 -1269.54 319.61 3839.77 3245.42 -1674.51 -618.64 246.65 1145.38 86.85 1058.53 PASS 4220.80f 3844.36 -1325.50 333.70 3923.40 3308.89 -1727.41 -631.59 247.40 1174.76 89.97 1084.79 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 20 of 30 Clearance Report Irak NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 19 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> Facility:North Fork Unit(NAD27) Slot:North Fork#32-35(Tyonek) Well:NFU#32-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status 101 [ft] [ft] [ft] 4320.80t 3926.03 -1381.46 347.79 4011.72 3376.05 -1783.02 -645.67 247.99 1204.45 93.24 1111.21 PASS 4420.80t 4007.69 -1437.43 361.88 4085.95 3432.03 -1830.07 -658.37 248.95 1235.51 96.12 1139.39 PASS 4520.80t 4089.36 -1493.39 375.97 4211.48 3526.86 -1909.47 -679.78 248.49 1266.54 100.52 1166.02 PASS 4620.80t 4171.03 -1549.35 390.06 4411.08 3685.03 -2028.01 -707.08 246.43 1291.91 106.88 1185.02 PASS 4720.80t 4252.70 -1605.32 404.15 4543.36 3795.51 -2099.06 -722.55 246.34 1312.34 111.52 1200.82 PASS 4820.80t 4334.37 -1661.28 418.24 4713.46 3943.40 -2180.77 -741.82 245.88 1329.84 117.02 1212.81 PASS 4920.80t 4416.03 -1717.24 432.33 4923.56 4135.23 -2264.63 -757.60 245.30 1339.56 123.01 1216.54 PASS 5020.80t 4497.70 -1773.21 446.41 5080.41 4284.43 -2311.93 -767.17 246.06 1344.81 127.98 1216.82 PASS 5120.801 4579.37 -1829.17 460.50 5220.59 4420.61 -2344.46 -773.36 247.33 1346.53 132.66 1213.87 PASS 5220.80t 4661.04 -1885.13 474.59 5394.89 4592.91 -2369.52 -779.00 248.87 1345.65 137.37 1208.28 PASS 5320.80t 4742.70 -1941.10 488.68 5520.93 4718.71 -2376.83 -780.70 251.06 1342.30 141.56 1200.75 PASS 5420.801 4824.37 -1997.06 502.77 5610.48 4808.25 -2378.31 -781.47 253.47 1339.74 145.38 1194.36 PASS 5520.80t 4906.04 -2053.02 516.86 5693.03 4890.78 -2379.57 -782.12 255.89 1339.48 149.08 1190.40 PASS 5620.801 4987.71 -2108.99 530.95 5774.57 4972.30 -2380.98 -782.75 258.30 1341.65 152.54 1189.12 PASS 5720.801 5069.37 -2164.95 545.04 5857.44 5055.16 -2382.56 -783.43 260.70 1346.25 155.72 1190.53 PASS 5820.80t 5151.04 -2220.91 559.13 5937.78 5135.48 -2384.02 -784.06 263.08 1353.15 158.63 1194.51 PASS 5920.80t 5232.71 -2276.88 573.22 6019.90 5217.59 -2385.25 -784.92 265.44 1362.54 161.27 1201.27 PASS 6020.801 5314.38 -2332.84 587.31 6107.97 5305.65 -2384.43 -785.61 267.85 1373.92 163.60 1210.32 PASS 6120.801 5396.04 -2388.80 601.39 6186.45 5384.11 -2383.03 -786.21 270.24 1387.67 165.60 1222.07 PASS 6220.80t 5477.71 -2444.77 615.48 6268.49 5466.14 -2381.48 -786.87 272.58 1403.83 167.30 1236.53 PASS 6320.80t 5559.38 -2500.73 629.57 6345.02 5542.65 -2380.00 -787.57 274.87 1422.38 168.72 1253.65 PASS 6420.801 5641.05 -2556.69 643.66 6427.36 5624.97 -2378.54 -788.39 277.09 1443.18 169.89 1273.29 PASS 6520.801 5722.72 -2612.66 657.75 6507.83 5705.43 -2377.19 -789.10 279.24 1465.99 170.81 1295.18 PASS 6620.80t 5804.38 -2668.62 671.84 6602.93 5800.51 -2375.39 -789.57 281.35 1490.54 171.50 1319.04 PASS 6720.80t 5886.05 -2724.58 685.93 6709.22 5906.78 -2373.55 -788.51 283.39 1515.79 171.95 1343.84 PASS 6788.56 5941.39 -2762.50 695.47 6765.32 5962.87 -2372.91 -787.55 284.72 1533.49 172.17 1361.33 PASS 6820.801 5967.84 -2780.38 699.98 6793.60 5991.14 -2372.58 -787.03 285.34 1542.09 172.23 1369.86 PASS 6920.80t 6051.36 -2833.70 713.40 6875.74 6073.25 -2371.47 -785.39 287.14 1568.60 172.32 1396.28 PASS 7020.801 6137.02 -2883.72 725.99 6964.30 6161.79 -2370.26 -783.66 288.78 1594.77 172.26 1422.51 PASS 7120.801 6224.69 -2930.36 737.74 7049.82 6247.29 -2369.16 -781.95 290.27 1620.15 172.10 1448.05 PASS 7220.801 6314.21 -2973.56 748.61 7141.44 6338.88 -2368.03 -780.12 291.61 1644.47 171.87 1472.60 PASS 7320.801 6405.45 -3013.24 758.60 7223.15 6420.57 -2367.08 -778.51 292.80 1667.48 171.61 1495.87 PASS 7420.80t 6498.25 -3049.34 767.69 7296.68 6494.10 -2367.18 -778.50 293.81 1689.99 171.39 1518.60 PASS 7520.80t 6592.48 -3081.80 775.86 7393.08 6590.49 -2367.50 -778.81 294.68 1710.91 171.26 1539.65 PASS 7620.801 6687.97 -3110.56 783.10 7485.68 6683.10 -2367.48 -779.01 295.44 1729.85 171.09 1558.76 PASS 7720.801 6784.58 -3135.58 789.40 7584.38 6781.80 -2367.26 -779.19 296.10 1746.65 170.95 1575.70 PASS 7820.80t 6882.14 -3156.82 794.75 7690.11 6887.52 -2367.01 -778.85 296.65 1760.70 170.83 1589.87 PASS 7920.801 6980.51 -3174.25 799.14 7785.02 6982.44 -2366.49 -778.38 297.12 1772.30 170.70 1601.61 PASS 8020.801 7079.51 -3187.84 802.56 7883.29 7080.70 -2365.78 -777.83 297.48 1781.40 170.59 1610.82 PASS 8120.801 7179.00 -3197.56 805.00 7982.68 7180.08 -2364.81 -777.26 297.76 1788.03 170.51 1617.52 PASS 8220.801, 7278.81 -3203.41 806.48 8078.33 7275.73 -2364.05 -776.89 297.93 1792.09 170.49 1621.60 PASS 8320.80t 7378.79 -3205.36 806.97 8181.84 7379.23 -2363.31 -776.56 298.00 1793.50 170.54 1622.96 PASS 8321.01 7379.00. -3205.36 806.97 8182.05 7379.45 -2363.31 -776.56 298.00 1793.50 170.54 1622.96 PASS 8420.80t 7478.79 -3205.36 806.97 8280.96 7478.35 -2362.24 -775.98 298.04 1793.49 170.56 1622.93 PASS 8520.801. 7578.79 -3205.36 806.97 8379.71 7577.08 -2360.93 -775.40 298.09 1793.59 170.56 1623.02 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 21 of 30 Clearance Report VP iii NFU 42-35 Vers#9 Inlet Energy_ Closest Approachh Page 20 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> Facility:North Fork Unit(NAD27) Slot:North Fork#32-35(Tyonek) Well:NFU#32-35 Threshold Value=0.00 ft t=interjolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] [ft[ [ft] [ftI [ft[ [ft] [ftI Bearing Clear Dist MASD Sep Status [01 [ftI [ft] IftI 8620.80f 7678.79 -3205.36 806.97 8473.24 7670.61 -2360.47 -775.44 298.10 1793.85 170.64 1623.22 PASS 8720.80f 7778.79 -3205.36 806.97 8581.12 7778.50 -2360.46 -775.77 298.09 1794.14 170.79 1623.35 PASS 8820.80f 7878.79 -3205.36 806.97 8676.97 7874.34 -2360.77 -776.09 298.08 1794.28 170.94 1623.34 PASS 8920.80f 7978.79 -3205.36 806.97 8779.04 7976.41 -2361.82 -776.89 298.04 1794.49 171.17 1623.32 PASS 9020.80f 8078.79 -3205.36 806.97 8880.50 8077.85 -2362.85 -777.54 298.00 1794.57 171.40 1623.17 PASS 9120.80f 8178.79 -3205.36 806.97 8984.33 8181.68 -2363.70 -777.91 297.97 1794.50 171.61 1622.90 PASS 9220.801. 8278.79 -3205.36 806.97 9084.88 8282.23 -2364.26 -778.07 297.95 1794.38 171.79 1622.59 PASS 9320.80f` 8378.79 -3205.36 806.97 9185.96 8383.31 -2364.75 -778.05 297.94 1794.14 171.96 1622.19 PASS 9420.80f 8478.79 -3205.36 806.97 9280.09 8477.44 -2364.95 -778.01 297.93 1794.00 172.09 1621.91 PASS 9520.80f 8578.79 -3205.36 806.97 9361.14 8558.49 -2364.85 -778.53 297.93 1794.63 172.18 1622.44 PASS 9620.80f 8678.79 -3205.36 806.97 9455.90 8653.23 -2364.85 -780.05 297.91 1796.03 172.37 1623.67 PASS 9720.80f 8778.79 -3205.36 806.97 9553.68 8751.00 -2364.60 -781.57 297.89 1797.53 172.55 1624.98 PASS 9820.80f 8878.79 -3205.36 806.97 9674.24 8871.55 -2364.60 -783.02 297.87 1798.61 172.82 1625.79 PASS 9920.80f 8978.79 -3205.36 806.97 9777.96 8975.26 -2365.29 -783.74 297.84 1798.92 173.06 1625.86 PASS 10020.80f 9078.79 -3205.36 806.97 9880.08 9077.38 -2365.78 -784.16 297.82 1799.05 173.27 1625.78 PASS 10120.80f 9178.79 -3205.36 806.97 9984.49 9181.79 -2366.11 -784.28 297.81 1799.01 173.46 1625.55 PASS 10220.80f 9278.79 -3205.36 806.97 10083.45 9280.75 -2366.23 -784.20 297.81 1798.88 173.62 1625.26 PASS 10320.80f 9378.79 -3205.36 806.97, 10190.35 9387.66 -2366.12 -783.81 297.82 1798.61 173.78 1624.83 PASS 10420.80f 9478.79 -3205.36 806.97\ 10271.20 9468.50 -2366.19 -783.64 297.82 1798.42 173.89 1624.53 PASS 10520.80f 9578.79 -3205.36 806.97 10368.11 9565.40 -2367.13 -785.00 297.77 1799.22 174.17 1625.05 PASS 10620.801. 9678.79 -3205.36 806.97 10463.88 9661.15 -2367.81 -786.24 297.73 1800.03 174.42 1625.62 PASS 10621.01 9679.00 -3205.36 806.97 10464.08 9661.35 -2367.81 -786.24 297.73 1800.03 174.42 1625.62 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] _ [ft] IN [ft] [ft] [ft] MI Ift] 16in Conductor 0.00 178.00 178.00 -20.70 157.26 37.60 -127.19 37.05 -128.08 9.625in Casing Surface 0.00 3212.00 3212.00 -20.70 2749.88 37.60 -127.19 -369.62 -223.99 lin Casing Intennediate _ 0.00 5570.00_ 5570.00 -20.70 4746.97 37.60 -127.19 -705.92 -301.70 4.5in Casing Production 0.00 11635.00 11635.00 -20.70 10811.31 37.60 -127.19 -701.01 -307.31 WELLPATH COMPOSITION-Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ftj 0.00 3159.00 OnTrak(Standard) OnTrak MWD<196-3159'> NFU#32-35 3159.00 5754.00 OnTrak(Standard) OnTrak MWD<3266-5754'> NFU#32-35 5754.00 12070.00 OnTrak(Standard) OnTrak MWD<5822- 12070'> NFU#32-35 file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 22 of 30 Clearance Report FS it NFU 42-35 Vers#9 RAKER 'Cook Inlet Energy_ Closest Approach Page 21 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196-12070'> MD Reference:Glacier#1 (RKB) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 0.00ft file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 23 of 30 Clearance Report FA� , NFU 42-35 Vers#9 BAKER _ ; Clearance Report Page 24 of 30 Clearance Report NFU 42-35 Vers#9 BAKER _ Cook Inlet Energy_ Closest Approach Page 23 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#34-26 Offset Wellpath:PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> Facility:North Fork Unit(NAD27) Slot:North Fork#34-26 Well:NFU#34-26 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Ift1 Ift1 Ift1 Ift1 Ift1 Ift1 Ift1 Bearing Clear Dist MASD Sep Status 101 Iftl Iftl Iftl 4320.80f 3926.03 -1381.46 347.79 3937.44 3941.65 -24.96 -310.30 334.12 1507.79 27.88 1479.91 PASS 4420.80f 4007.69 -1437.43 361.88 4022.01 4026.19 -26.55 -311.48 334.49 1563.44 28.37 1535.07 PASS 4520.80f 4089.36 -1493.39 375.97 4107.50 4111.66 -28.26 -312.52 334.83 1618.99 28.88 1590.12 PASS 4620.80f 4171.03 -1549.35 390.06 4194.00 4198.14 -30.17 -313.60 335.15 1674.46 29.41 1645.05 PASS 4720.80f 4252.70 -1605.32 404.15 4281.46 4285.57 -32.14 -314.14 335.46 1729.71 29.96 1699.76 PASS 4820.80f 4334.37 -1661.28 418.24 4364.57 4368.65 -34.16 -314.72 335.75 1784.91 30.50 1754.41 PASS 4920.80f 4416.03 -1717.24 432.33 4444.01 4448.07 -36.02 -315.31 336.03 1840.25 31.04 1809.21 PASS 5020.80f 4497.70 -1773.21 446.41 4526.04 4530.08 -37.80 -315.83 336.29 1895.71 31.60 1864.11 PASS 5120.80f 4579.37 -1829.17 460.50 4611.47 4615.49 -39.65 -316.32 336.53 1951.19 32.20 1918.99 PASS 5220.80f 4661.04 -1885.13 474.59 4697.74 4701.74 -41.66 -316.75 336.77 2006.56 32.81 1973.75 PASS 5320.80f 4742.70 -1941.10 488.68 4779.76 4783.73 -43.66 -317.16 336.99 2061.88 33.41 2028.47 PASS 5420.80f 4824.37 -1997.06 502.77 4858.19 4862.13 -45.45 -317.55 337.20 2117.35 34.00 2083.34 PASS 5520.80f 4906.04 -2053.02 516.86 4945.48 4949.40 -47.36 -318.10 337.40 2172.95 34.65 2138.30 PASS 5620.80f 4987.71 -2108.99 530.95 5029.44 5033.34 -49.48 -318.52 337.59 2228.28 35.30 2192.99 PASS 5720.80f 5069.37 -2164.95 545.04 5114.87 5118.73 -51.68 -319.33 337.75 2283.74 35.96 2247.78 PASS 5820.80f 5151.04 -2220.91 559.13 5197.15 5200.99 -53.82 -319.87 337.92 2339.11 36.62 2302.49 PASS 5920.80f 5232.71 -2276.88 573.22 5275.47 5279.28 -55.79 -320.45 338.08 2394.59 37.26 2357.32 PASS 6020.80f 5314.38 -2332.84 587.31 5354.78 5358.56 -57.74 -321.37 338.23 2450.25 37.92 2412.32 PASS 6120.80f 5396.04 -2388.80 601.39 5434.10 5437.84 -59.65 -322.40 338.37 2506.01 38.59 2467.42 PASS 6220.80f 5477.71 -2444.77 615.48 5513.91 5517.63 -61.45 -323.55 338.50 2561.95 39.27 2522.68 PASS 6320.80f 5559.38 -2500.73 629.57 5604.51 5608.20 -63.61 -324.76 338.62 2617.77 40.03 2577.74 PASS 6420.80f 5641.05 -2556.69 643.66 5688.96 5692.60 -65.80 -326.00 338.73 2673.47 40.75 2632.72 PASS 6520.80f 5722.72 -2612.66 657.75 5785.24 5788.83 -68.57 -327.28 338.83 2728.93 41.56 2687.37 PASS 6620.80f 5804.38 -2668.62 671.84 5861.95 5865.50 -70.87 -328.32 338.94 2784.31 42.25 2742.06 PASS 6720.80f 5886.05 -2724.58 685.93 5946.73 5950.24 -73.39 -329.69 339.04 2839.79 43.00 2796.79 PASS 6788.56 5941.39 -2762.50 695.47 6002.20 6005.67 -75.05 -330.50 339.11 2877.35 43.50 2833.85 PASS 6820.80f 5967.84 -2780.38 699.98 6027.78 6031.25 -75.80 -330.87 339.14 2895.07 43.73 2851.34 PASS 6920.80f 6051.36 -2833.70 713.40 6107.28 6110.70 -78.06 -332.11 339.22 2947.90 44.45 2903.45 PASS 7020.80f 6137.02 -2883.72 725.99 6192.36 6195.73 -80.43 -333.72 339.29 2997.47 45.23 2952.24 PASS 7120.80f 6224.69 -2930.36 737.74 6287.99 6291.32 -83.15 -335.30 339.35 3043.44 46.06 2997.38 PASS 7220.80f 6314.21 -2973.56 748.61 6381.60 6384.87 -85.95 -336.67 339.40 3085.64 46.85 3038.78 PASS 7320.80f 6405.45 -3013.24 758.60 6481.34 6484.56 -88.88 -337.98 339.45 3124.20 47.67 3076.53 PASS 7420.80f 6498.25 -3049.34 767.69 6587.78 6590.93 -92.55 -339.11 339.48 3158.51 48.51 3110.01 PASS 7520.80f 6592.48 -3081.80 775.86 6687.35 6690.42 -96.13 -340.28 339.50 3188.98 49.28 3139.70 PASS 7620.80f 6687.97 -3110.56 783.10 6806.52 6809.50 -100.79 -341.29 339.52 3215.23 50.15 3165.08 PASS 7720.80f 6784.58 -3135.58 789.40 6901.80 6904.69 -104.89 -342.16 339.53 3237.27 50.84 3186.43 PASS 7820.80f 6882.14 -3156.82 794.75 6996.87 6999.68 -108.86 -342.98 339.53 3255.51 51.50 3204.01 PASS 7920.80f 6980.51 -3174.25 799.14 7101.94 7104.64 -113.37 -343.98 339.52 3269.73 52.20 3217.53 PASS 8020.80f 7079.51 -3187.84 802.56 7211.32 7213.91 -118.31 -344.85 339.50 3279.73 52.89 3226.84 PASS 8120.80f 7179.00 -3197.56 805.00 7319.64 7322.10 -123.49 -345.60 339.48 3285.47 53.55 3231.91 PASS 8220.80f 7278.81 -3203.41 806.48 7424.47 7426.80 -128.69 -346.25 339.45 3287.03 54.16 3232.87 PASS 8320.80f 7378.79 -3205.36 806.97 7519.44 7521.64 -133.48 -346.82 339.41 3284.52 54.67 3229.86 PASS 8321.01 7379.00 -3205.36 806.97 7519.65 7521.86 -133.49 -346.82 339.41 3284.51 54.67 3229.84 PASS 8420.80f 7478.79 -3205.36 806.97 7619.05 7621.14 -138.32 -347.39 339.38 3280.18 55.14 3225.04 PASS 8520.80f 7578.79 -3205.36 806.97 7719.02 7720.99 -143.09 -347.72 339.34 3275.83 55.61 3220.22 PASS file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 25 of 30 Clearance Report Wait ," ..,�. NFU 42-35 Vers#9 BAKER ., 'Cook Inlet Energy_ Closest Approach Page 24 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#34-26 Offset Wellpath:PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> Facility:North Fork Unit(NAD27) Slot:North Fork#34-26 Well:NFU#34-26 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl lftl Iftl Iftl [ft] lftl lftl lftl Bearing Clear Dist MASD Sep Status 11 Iftl IN lftl 8620.80f 7678.79 -3205.36 806.97 7819.27 7821.13 -147.70 -347.74 339.31 3271.53 56.08 3215.45 PASS 8720.80f 7778.79 -3205.36 806.97 7920.60 7922.35 -152.38 -347.52 339.29 3267.14 56.56 3210.57 PASS 8820.80f 7878.79 -3205.36 806.97 8023.89 8025.54 -157.03 -346.91 339.27 3262.71 57.05 3205.66 PASS 8920.80f 7978.79 -3205.36 806.97 8126.37 8127.91 -161.69 -346.12 339.25 3258.19 57.54 3200.65 PASS 9020.80f 8078.79 -3205.36 806.97 8237.48 8238.89 -166.77 -344.64 339.24 3253.44 58.08 3195.36 PASS 9120.80f 8178.79 -3205.36 806.97 8345.23 8346.51 -171.87 -342.80 339.24 3248.41 58.59 3189.82 PASS 9220.80f 8278.79 -3205.36 806.97 8452.25 8453.38 -177.04 -340.47 339.25 3243.12 59.10 3184.02 PASS 9320.80f 8378.79 -3205.36 806.97 8560.89 8561.85 -182.36 -337.64 339.26 3237.62 59.62 3178.00 PASS 9420.80f 8478.79 -3205.36 806.97 8675.47 8676.23 -188.24 -334.13 339.28 3231.74 60.17 3171.57 PASS 9520.80f 8578.79 -3205.36 806.97 8765.06 8765.64 -192.70 -330.86 339.31 3225.79 60.56 3165.23 PASS 9620.80f 8678.79 -3205.36 806.97 8864.54 8864.93 -197.28 -326.72 339.35 3220.01 61.00 3159.01 PASS 9720.80f 8778.79 -3205.36 806.97 8978.23 8978.39 -202.63 -321.70 339.40 3214.05 61.53 3152.53 PASS 9820.80f 8878.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3208.34 61.64 3146.70 PASS 9920.80f 8978.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3205.46 61.49 3143.97 PASS 10020.80f 9078.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3205.70 61.34 3144.36 PASS 10120.80f 9178.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3209.06 61.18 3147.88 PASS 10220.80f 9278.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3215.52 61.02 3154.50 PASS 10320.80f 9378.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3225.08 60.87 3164.21 PASS 10420.80f 9478.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3237.70 60.72 3176.98 PASS 10520.80f 9578.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3253.34 60.58 3192.77 PASS 10620.80f 9678.79 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3271.97 60.44 3211.53 PASS 10621.01 9679.00 -3205.36 806.97 9021.00 9021.06 -204.76 -319.79 339.42 3272.01 60.44 3211.57 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#34-26 Offset Wellpath:PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft WELLPATH COMPOSITION- Offset Wellbore:NFU#34-26 Offset Wellpath:PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore NFU#34-26 (ft] IN 2500.00 Gyrodata standard-Continuous gyro GyroData PGMS<100-2500'> 2500.00 9021.00 ISCWSA MWD,Rev.2(Standard) MWD(HAL)<2550-9021'> NFU#34-26 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#34-26 Offset Wellpath:PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> MD Reference:Rig on slot:34-26(RKB) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 0.00ft file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 26 of 30 Clearance Report Fail i NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 25 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-123345 Facility:NF#41-35(NAD27) Slot:North Fork#41-35 Well:NF#41-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR IftI Iftl [ft] Iftl [ft] Iftl Iftl [ft' Bearing Clear Dist MASD Sep Status I°I [ft] Iftl [ft] 20.80 20.80 0.00 0.00 125.50 24.10 -1266.92 797.82 147.80 1497.20 122.10 1375.10 PASS 120.80? 120.80 0.00 0.00 226.03 124.63 -1266.76 797.63 147.80 1496.97 121.94 1375.02 PASS 220.80? 220.80 0.00 0.00 326.30 224.90 -1266.62 797.33 147.81 1496.69 121.67 1375.02 PASS 320.80? 320.80 0.00 0.00 425.62 324.22 -1266.57 796.96 147.82 1496.44 121.68 1374.76 PASS 420.80420.80 0.00 0.00 524.82 423.42 -1266.56 796.57 147.83 1496.23 121.69 1374.54 PASS 520.80? 520.80 0.00 0.00 620.72 519.32 -1266.66 796.24 147.85 1496.14 121.70 1374.44 PASS 620.80? 620.80 0.00 0.00 710.53 609.12 -1267.19 796.18 147.86 1496.60 121.71 1374.89 PASS 720.80? 720.80 0.00 0.00 805.57 704.16 -1268.15 796.36 147.87 1497.55 121.72 1375.83 PASS 820.80? 820.80 0.00 0.00 905.20 803.79 -1269.31 796.62 147.89 1498.68 121.73 1376.95 PASS 920.80? 920.80 0.00 0.00 1007.35 905.93 -1270.52 796.73 147.91 1499.74 121.75 1377.99 PASS 1000.00 1000.00 0.00 0.00 1087.97 986.54 -1271.46 796.67 147.93 1500.49 121.77 1378.72 PASS 1020.80? 1020.80 -0.07 0.02 1109.33 1007.90 -1271.70 796.63 147.94 1500.60 121.78 1378.82 PASS 1120.80? 1120.76 -2.47 0.62 1212.60 1111.16 -1272.79 796.32 147.94 1498.98 121.81 1377.17 PASS 1220.80? 1220.58 -8.25 2.08 1311.75 1210.31 -1273.82 795.94 147.90 1493.99 121.86 1372.13 PASS 1320.80? 1320.13 -17.40 4.38 1413.54 1312.09 -1274.73 795.66 147.82 1485.62 121.91 1363.71 PASS 1420.80? 1419.29 -29.92 7.53 1513.13 1411.68 -1275.52 795.39 147.69 1473.87 121.96 1351.90 PASS 1520.80? 1517.94 -45.78 11.53 1610.82 1509.37 -1276.27 795.20 147.51 1458.88 122.02 1336.86 PASS 1620.80? 1615.95 -64.97 16.36 1708.69 1607.23 -1276.98 795.20 147.28 1440.71 122.08 1318.62 PASS 1720.80] 1713.22 -87.47 22.02 1810.44 1708.98 -1277.51 795.23 146.99 1419.17 122.15 1297.03 PASS 1820.80j 1809.62` -113.25 28.51 1910.35 1808.89 -1277.65 795.31 146.63_ 1394.20 122.22 1271.98 PASS 1920.80? 1905.03 -142.27 35.82 2005.20 1903.74 -1277.71 795.34 146.22 1366.05 122.14 1243.91 PASS 2020.80? 1999.34 -174.51 43.93 2098.96 1997.50 -1277.80 795.39 145.74 1334.90 122.22 1212.68 PASS 2120.80? 2092.43 -209.91 52.85 2190.65 2089.19 -1277.87 795.60 145.18 1300.86 122.32 1178.54 PASS 2220.80? 2184.19 -248.45 62.55 2282.72 2181.26 -1277.99 795.83 144.54 1263.99 122.42 1141.57 PASS 2320.80? 2274.50 -290.07 73.03 2374.73 2273.27 -1278.11 795.95 143.81 1224.27 122.54 1101.73 PASS 2420.80? 2363.27 -334.72 84.27 2462.81 2361.35 -1278.16 796.03 142.97 1181.82 122.67 1059.14 PASS 2520.80? 2450.37 -382.34 96.26 2550.44 2448.98 -1278.21 796.23 142.00 1136.90 122.83 1014.07 PASS 2620.80? 2535.71 -432.89 108.98 2638.27 2536.81 -1278.21 796.25 140.89 1089.46 123.02 966.44 PASS 2720.80? 2619.17 -486.29 122.43 2723.42 2621.96 -1278.06 796.14 139.61 1039.61 123.24 916.38 PASS 2762.33 2653.26 -509.29 128.22 2757.03 2655.57 -1277.99 796.09 139.02 1018.31 123.34 894.97 PASS 2820.80? 2701.01 -542.02 136.46 2804.23 2702.77 -1277.91 796.04 138.13 988.23 123.50 864.73 PASS 2920.80? 2782.68 -597.98 150.54 2886.12 2784.66 -1277.75 795.98 136.48 937.38 123.61 813.77 PASS 3020.80? 2864.35 -653.94 164.63 2968.78 2867.32 -1277.47 795.95 134.65 887.33 123.87 763.46 PASS 3120.80? 2946.01 -709.90 178.72 3048.74 2947.27 -1277.09 795.97 132.58 838.27 124.21 714.06 PASS 3220.80? 3027.68 -765.87 192.81 3128.01 3026.54 -1276.81 796.25 130.26 790.70 124.65 666.05 PASS 3320.80? 3109.35 -821.83 206.90 3208.74 3107.28 -1276.53 796.69 127.63 744.72 125.20 619.52 PASS 3420.80? 3191.02 -877.79 220.99 3289.13 3187.67 -1276.16 797.34 124.65 700.63 125.89 574.74 PASS 3520.80? 3272.69 -933.76 235.08 3370.71 3269.24 -1275.75 798.11 121.28 658.76 126.75 532.02 PASS 3620.80? 3354.35 -989.72 249.17 3453.23 3351.75 -1275.47 798.73 117.47 619.42 127.79 491.62 PASS 3720.80? 3436.02 -1045.68 263.26 3536.11 3434.63 -1275.29 799.11 113.19 582.98 129.04 453.94 PASS 3820.80? 3517.69 -1101.65 277.35 3618.49 3517.01 -1274.85 799.43 108.35 550.07 130.51 419.56 PASS 3920.80? 3599.36 -1157.61 291.43 3700.56 3599.08 -1274.37 799.64 102.94 521.45 132.17 389.28 PASS 4020.80? 3681.02 -1213.57 305.52 3781.12 3679.64 -1274.03 799.84 96.97 498.00 133.96 364.05 PASS 4120.80? 3762.69 -1269.54 319.61 3862.31 3760.83 -1273.79 800.14 90.51 480.55 135.77 344.78 PASS 4220.80? 3844.36 -1325.50 333.70 3944.38 3842.90 -1273.59 800.45 83.65 469.62 137.46 332.17 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 27 of 30 Clearance Report FAIN NFU 42-35 Vers#9 BAKER Cook Inlet Energy_ Closest Approach Page 26 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>lnclination ONLY<10070-12334'> Facility:NF#41-35(NAD27) Slot:North Fork#41-35 Well:NF#41-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Ift] Ift] Iftl Iftl lftl Iftl Iftl Ift] Bearing Clear Dist MASD Sep Status l°l Iftl Iftl lft] 4320.80f 3926.03 -1381.46 347.79 4026.33 3924.85 -1273.61 800.63 76.60 465.51 138.88 326.63 PASS 4327.69f 3931.66 -1385.32 348.76 4031.60 3930.12 -1273.61 800.65 76.11 465.49 138.97 326.52 PASS 4343.63f 3944.67 -1394.24 351.01 4044.60 3943.12 -1273.60 800.69 74.98 465.58 139.16 326.42 PASS 4420.80f 4007.69 -1437.43 361.88 4106.64 4005.15 -1273.51 800.96 69.53 468.69 139.93 328.77 PASS 4520.80f 4089.36 -1493.39 375.97 4191.61 4090.13 -1273.61 801.20 62.67 478.67 140.53 338.14 PASS 4620.80f 4171.03 -1549.35 390.06 4273.54 4172.05 -1273.86 801.13 56.17 494.85 140.72 354.13 PASS 4720.80f 4252.70 -1605.32 404.15 4357.24 4255.75 -1273.98 800.89 50.13 516.91 140.55 376.36 PASS 4820.80j 4334.37 -1661.28 418.24 4439.48 4337.99 -1274.59 800.58 44.68 543.81 140.13 403.68 PASS 4920.80f 4416.03 -1717.24 432.33 4518.57 4417.08 -1275.04 800.59 39.79 575.47 139.55 435.92 PASS 5020.80f 4497.70 -1773.21 446.41 4598.09 4496.60 -1275.32 800.95 35.45 611.22 138.89 472.33 PASS 5120.80f 4579.37 -1829.17 460.50 4677.43 4575.94 -1275.39 801.57 31.63 650.39 138.22 512.18 PASS 5220.80f 4661.04 -1885.13 474.59 4758.13 4656.63 -1275.24 802.30 28.25 692.38 137.56 554.82 PASS 5320.80f 4742.70 -1941.10 488.68 4839.65 4738.15 -1274.95 802.88 25.25 736.55 136.94 599.60 PASS 5420.80f 4824.37 -1997.06 502.77 4922.44 4820.94 -1274.66 803.39 22.59 782.47 136.38 646.08 PASS 5520.80f 4906.04 -2053.02 516.86 5007.55 4906.05 -1274.64 803.80 20.24 829.59 135.88 693.71 PASS 5620.80f 4987.71 -2108.99 530.95 5088.41 4986.91 -1274.73 804.19 18.14 877.86 135.43 742.43 PASS 5720.80f 5069.37 -2164.95 545.04 5169.89 5068.39 -1274.78 804.62 16.26 927.25 135.04 792.20 PASS 5820.80f 5151.04 -2220.91 559.13 5250.23 5148.72 -1274.78 805.05 14.57 977.58 134.70 842.88 PASS 5920.80f 5232.71 -2276.88 573.22 5330.71 5229.20 -1274.62 805.51 13.05 1028.83 134.41 894.42 PASS 6020.80f 5314.38 -2332.84 587.31 5412.82 5311.31 -1274.41 805.73 11.66 1080.74 134.16 946.58 PASS 6120.80f 5396.04 -2388.80 601.39 5495.04 5393.53 -1274.22 805.87 10.40 1133.18 133.95 999.23 PASS 6220.80f 5477.71 -2444.77 615.48 5575.21 5473.70 -1274.02 806.00 9.24 1186.15 133.78 1052.38 PASS 6320.80f 5559.38 -2500.73 629.57 5653.24 5551.73 -1273.67 806.06 8.19 1239.71 133.62 1106.08 PASS 6420.80f 5641.05 -2556.69 643.66 5728.85 5627.34 -1273.05 806.01 7.21 1293.94 133.49 1160.45 PASS 6520.80f 5722.72 -2612.66 657.75 5802.34 5700.82 -1272.05 806.02 6.31 1348.96 133.38 1215.58 PASS 6620.80f 5804.38 -2668.62 671.84 5884.73 5783.20 -1270.76 806.12 5.49 1404.45 133.33 1271.12 PASS 6720.80f 5886.05 -2724.58 685.93 5968.91 5867.37 -1269.59 806.25 4.73 1460.08 133.31 1326.77 PASS 6788.56 5941.39 -2762.50 695.47 6027.67 5926.13 -1268.91 806.34 4.25 1497.78 133.32 1364.46 PASS 6820.80f 5967.84 -2780.38 699.98 6056.59 5955.04 -1268.64 806.37 4.03 1515.53 133.33 1382.21 PASS 6920.80f 6051.36 -2833.70 713.40 6144.52 6042.98 -1268.08 806.39 3.40 1568.40 133.36 1435.03 PASS 7020.80f 6137.02 -2883.72 725.99 6232.02 6130.47 -1267.65 806.30 2.85 1618.07 133.42 1484.65 PASS 7120.80f 6224.69 -2930.36 737.74 6321.06 6219.51 -1267.39 806.61 2.37 1664.41 133.51 1530.90 PASS 7220.80f 6314.21 -2973.56 748.61 6406.07 6304.52 -1267.05 807.39 1.97 1707.56 133.60 1573.96 PASS 7320.80f 6405.45 -3013.24 758.60 6489.73 6388.17 -1266.42 808.22 1.63 1747.61 133.69 1613.92 PASS 7420.80f 6498.25 -3049.34 767.69 6592.56 6491.00 -1265.67 809.04 1.33 1784.16 133.85 1650.31 PASS 7520.80f 6592.48 -3081.80 775.86 6685.40 6583.84 -1265.29 808.98 1.05 1816.83 133.96 1682.87 PASS 7620.80f 6687.97 -3110.56 783.10 6771.58 6670.01 -1264.67 807.91 0.77 1846.14 134.03 1712.11 PASS 7720.80f 6784.58 -3135.58 789.40 6868.91 6767.33 -1263.64 806.86 0.53 1872.10 134.13 1737.97 PASS 7820.80f 6882.14 -3156.82 794.75 6977.49 6875.90 -1262.92 806.12 0.34 1893.95 134.27 1759.68 PASS 7920.80f 6980.51 -3174.25 799.14 7079.02 6977.42 -1262.72 805.34 0.19 1911.55 134.39 1777.16 PASS 8020.80f 7079.51 -3187.84 802.56 7174.96 7073.36 -1262.51 804.56 0.06 1925.34 134.48 1790.87 PASS 8120.80f 7179.00 -3197.56 805.00 7276.70 7175.10 -1262.20 803.78 359.96 1935.37 134.58 1800.79 PASS 8220.80f 7278.81 -3203.41 806.48 7387.14 7285.53 -1262.25 802.91 359.90 1941.18 134.70 1806.48 PASS 8320.80f 7378.79 -3205.36 806.97 7483.41 7381.80 -1262.54 802.02 359.85 1942.83 134.77 1808.07 PASS 8321.01 7379.00 -3205.36 806.97 7483.61 7382.00 -1262.54 802.02 359.85 1942.83 134.77 1808.07 PASS file://C:AWellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 28 of 30 / Clearance Report FA t { NFU 42-35 Vers#9 BAKER • Cook Inlet Energy_ Closest Approach Page 27 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> Facility:NF#41-35(NAD27 Slot:North Fork#41-35 Well:NF#41-35 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR IN IftI IftI IftI IftI Ifti IN IftI Bearing Clear Dist MASD Sep Status 11 IN Iftl IN 8420.80t 7478.79 -3205.36 806.97 7588.67 7487.05 -1262.80 800.94 359.82 1942.59 134.83 1807.76 PASS 8520.80t 7578.79 -3205.36 806.97 7690.61 7588.98 -1263.30 799.91 359.79 1942.10 134.89 1807.22 PASS 8620.801 7678.79 -3205.36 806.97 7789.52 7687.89 -1263.80 798.88 359.76 1941.60 134.94 1806.66 PASS 8720.80t 7778.79 -3205.36 806.97 7886.43 7784.79 -1264.19 797.74 359.73 1941.21 134.98 1806.22 PASS 8820.80t 7878.79 -3205.36 806.97 7984.85 7883.21 -1264.45 796.74 359.70 1940.94 135.04 1805.91 PASS 8920.80t 7978.79 -3205.36 806.97 8081.91 7980.27 -1264.61 796.08 359.68 1940.79 135.10 1805.69 PASS 9020.80t 8078.79 -3205.36 806.97 8187.51 8085.86 -1264.80 795.59 359.66 1940.61 135.18 1805.43 PASS 9120.80t 8178.79 -3205.36 806.97 8285.14 8183.50 -1265.13 795.35 359.66 1940.28 135.25 1805.02 PASS 9220.80t 8278.79 -3205.36 806.97 8382.06 8280.41 -1265.28 795.40 359.66 1940.11 135.33 1804.79 PASS 9320.80t 8378.79 -3205.36 806.97 8479.69 8378.04 -1265.30 795.35 359.66 1940.09 135.30 1804.80 PASS 9420.80t 8478.79 -3205.36 806.97 8580.47 8478.82 -1265.27 795.16 359.65 1940.13 135.38 1804.75 PASS 9520.80t 8578.79 -3205.36 806.97 8678.41 8576.76 -1265.24 794.72 359.64 1940.16 135.46 1804.71 PASS 9620.801 8678.79 -3205.36 806.97 8777.52 8675.87 -1265.11 794.31 359.63 1940.30 135.54 1804.77 PASS 9720.80t 8778.79 -3205.36 806.97 8875.20 8773.55 -1264.91 793.88 359.61 1940.50 135.61 1804.89 PASS 9820.80t 8878.79 -3205.36 806.97 8982.24 8880.59 -1264.76 793.55 359.60 1940.65 135.72 1804.93 PASS 9920.80t 8978.79 -3205.36 806.97 9080.85 8979.20 -1264.86 793.30 359.60 1940.55 135.81 1804.74 PASS 10020.80t 9078.79 -3205.36 806.97 9184.60 9082.94 -1264.95 792.79 359.58 1940.47 135.90 1804.56 PASS 10120.80t 9178.79 -3205.36 806.97 9290.68 9189.03 -1265.35 792.18 359.56 1940.10 136.01 1804.09 PASS 10220.80t 9278.79 -3205.36 806.97 9406.31 9304.64 -1266.42 791.24 359.54 1939.17 136.13 1803.05 PASS 10320.80t 9378.79 -3205.36 806.97 9512.56 9410.88 -1268.02 789.91 359.50 1937.69 136.21 1801.47 PASS 10420.80t 9478.79 -3205.36 806.97 9619.73 9518.01 -1270.04 788.18 359.44 1935.81 136.30 1799.51 PASS 10520.80t 9578.79 -3205.36 806.97 9720.83 9619.07 -1272.10 786.33 359.39 1933.79 136.37 1797.42 PASS 10620.80t 9678.79 -3205.36 806.97 9827.43 9725.63 -1274.57 784.22 359.33 1931.50 136.45 1795.05 PASS 10621.01 9679.00 -3205.36 806.97 9827.65 9725.84 -1274.57 784.22 359.33 1931.49 136.45 1795.05 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>lnclination ONLY<10070-12334'> Slot Surface Uncertainty @I SD Horizontal 2.000ft _Vertical 1.000ft Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] IN [ft] [ft] [ft] [ft] IN [ft] 20in Conductor 0.00 246.00 246.00 -122.20 123.80 -772.38 486.44 -772.28 486.34 13.375in Casing Surface 0.00 2000.00 2000.00 -122.20 1877.74 -772.38 486.44 -775.62 485.65 9.625in Casing Intennediate 0.00 8451.00 8451.00 -122.20 8328.55 -772.38 486.44 -771.85 485.66 7in Liner 8330.00 109851.00 101521.00 8207.55 NA -771.82 485.67 NA NA WELLPATH COMPOSITION- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> StarttMD I End MD Positional Uncertainty Model I Log Name/Comment I Wellbore file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 29 of 30 0.00GyroDa►. _SMS<I00-9932'> NF#41-35 I 9932.00 I 9932.00 12334.00 I Gyrodata standart. ,ontinuous gyro Custom Drift Indicator(7°Maximum Inclination) I Inclination ONLY<246-12334'> I NF#41-35 file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 Clearance Report Page 30 of 30 Clearance Report FIR 1 NFU 42-35 Vers#9 Cook Inlet Energy_ Closest Approach BAKER Page 28 of 28 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#42-35 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#42-35 Field North Fork Wellbore NFU#42-35 Facility North Fork Unit(NAD27) OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> MD Reference:Rig on North Fork#41-35(RKB) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD O.00ft file://C:\WellArchitectData\NFU #42-35 CR.xml 10/8/2014 —xl L E ,h _ 1 1 (I k e 1 cco E ,2 ci d u-i a.i tri I § 11 >•-• N 1- o $ — 2 in at cr.; -cii o N CO 13 W 0 N. 0 2 Q 0CD CO 0 LICr 1 e , A ris a) UD (±, tii 1 f. 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Cook Inlet Energy_ DRILLING OPERATIONS SUMMARY Cook Inlet Energy 0 North Fork Unit #42-35 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.: 214 ??? Start Depth Seat Depth Casing Interval Hole Size MD TVD MD TVD Size Wt(lb/ft) Grade Conn Burst Collapse Tension Drive/ Structural Driven 0 0 120 120 16 0.5 N8OHC Welded N/A N/A NO Conductor Surface 12.25 0 0 2881 2750 9.625 40 N/L 80 SP DRFT BTC 5750 3090 916 Prod 8.75 0 0 10621 • 9679 7 26 N/L 80 BTC-M 7240 5410 604 * =minimum of body and connection strengths Note: AOGCC MUST be notified 48 hrs prior to each diverter function and BOPe test. See AOGCC instructions for clarification and contact methodology. Conductor: 1. Drill/Drive 16" conductor to 4- 120ft. RKB. RD conductor rig. Install cellar. 2. MIRU rig. NOTE the following for the CIE Rig 37 i. The RKB is 20'7"ABGL with the Rig sitting on matts. ii. Well head/BOP Connection to be at 18"-20"above Ground level with the rig's rental BOP. 3. Install starting head 16" SLC x 21 %4", 2M flange. 4. Nipple up bell nipple and flow line. NOTE: A variance to not use the diverter has been requested. If not granted, Nipple up 21 %4", 2M diverter, 16" diverter valve and 16" diverter line. Function test diverter and diverter valve. (AOGCC 48 hr notice) 5. Build spud mud. 6. Inspect bha equipment. 7. Install mud loggers per logging program. Instruct same regarding dry ditch samples for AOGCC. Surface: 1. PU 5" drill pipe, bit and BHA w/ GR/RES per bit/directional proposal. Set up WEEKLY STATUS Report for the Commission. 2. Drill w/ low rpm, gpm until stabilizers have exited drive pipe. Run max gpm, rotary, etc as allowed. Set up logging (if any) as per evaluation section. 3. Continue to drill a 13 %2" hole to 2881' MD/ 2750' TVD short tripping and pumping sweeps as considered necessary. At hole section TD, pump a HIGH VIS sweep and circulate the hole clean. Strap out of hole. 4. Evaluate hole as per program. NOTE: Make sure that "for all casings" that landing jts and csg ram test jts and cross overs for them ARE ON SITE. 5. TIH. Short trip. Circulate hole clean at max rpm and gpm. 6. Condition mud to lower YP and gels. Monitor pill lag and mud log lag times to aid in adjusting cement volumes for hole washout. 7. Prep for excess mud, cement, rinse water, etc disposal. Prep for stab-in cementing job. 8. Calculate landing equipment to make sure we have proper space out with top of landing jt ±4-6' above rotary. Run 9 5/8" surface casing as follows Baker-Locking the shoe track: a) Shoe b) Sting-in collar c) Casing With centralizers placed as follows: d) 2 bow-springs with stop collars in center of bottom 2 jts e) Centralizers across the bottom 2 couplings f) 1 centralizer across the coupling of every third jt g) NO CENTRALIZER INSIDE CONDUCTOR AS CASING NEEDS TO BE CENTERED IN ROTARY h) ESTIMATED TOTAL centralizers = ±40 w/2 stop collars 9. Perform a running tag. Reciprocate casing. Circulate and condition mud at a rate not to exceed the AV around the collars while drilling. 10. RU stab-in equipment. RIH w/ DP and stab in sub, stab in float collar and break circulation. Circulate while rigging up cementing equipment. 11. RU cementing head and lines. Test to 500/5000psi. Cement 9 5/8" casing PER cementing proposal with the inner string, cut off cementing when cement reaches surface, dump 2-5 bbls on top of sting-in collar. Circulate clean. Cement volumes are presently designed with 100% excess. Adjust as necessary to allow for cement returns to surface. NOTE: Have casing running company supervisor and cementing supervisor ASSIST in filling out Casing and Cementing form. 12. Cut casings. 13. Install 9 5/8" slip lock connection X 11" 10M* flanged multibowl wellhead. Test to 50% of casing collapse or 1500 psi whichever is greater. * Note: 5k designs but local stock directed toward 10k universality 14. NU adapter spool. NU 13 5/8" 5M Shaffer LWS BOPs. Test BOPs and choke manifold to 250/3si, annular to 250/2500 psi. (AOGCC 48 hr notice). Pipe rams are to be 2 7/8" x 5"VBR's, blind rams, 5" pipe rams (may have variable as well). • NOTE: (BOPe MUST be tested every 7 days during the remainder of the well. AOGCC must be notified at least 48 hours before) NOTE: Maintain good communications with regulatory. Communicate with the inspector every couple of days just to let regulatory know current opns. 15. Set wear bushing. Run CBL. Production: 1. PU 8 3/4" PDC bit and BHA w/ LWD per directional evaluation program. Clean out casing to float equipment. Test casing to 3000 psi recording on a chart. 2. Drill out float equipment and at least 20' of new formation. Circulate hole clean. 3. Contact AOGCC. Perform FIT on a chart. Email results. Estimated Leak Off EMW is 14.0 ppg emw. If test is less, discuss with office. A minimum of 12.5 is acceptable. 4. Condition existing mud to or displace with one with desired mud properties (study is ongoing to assist in minimizing formation damage). 5. Drill ahead per plan. Monitor hole conditions, torque and drag, etc. 6. Continue to drill to ±10621'MD / ±9679'TVD as per program, short tripping and pumping HIGH VIS sweeps as required. MINIMUM flow rate should be 500gpm. Higher if possible. 7. At hole section TD, pump a HIGH VIS sweep and circulate the hole clean. Make wiper trip. Again pump a sweep and circulate hole clean. Make sure pump is at MAX rate. Hole will require more than just circulating bottoms up. Strap out of hole. 8. Evaluate hole as per program. 9. TIH. Condition hole as before. Condition mud to lower YP and gels. Monitor pill lag and mud log lag times to aid in adjusting cement volumes for hole washout and compare to elog value. 10. TOOH. Pull wear bushing. 11. Change out pipe ram with 7" casing rams in upper ram. Run test joint and test casing ram to 3000 psi. Make sure the appropriate x-over with FOSV is on the rig floor for casing run. 12. Calculate space out and prep as per previous. Run casing as follows Baker-Locking the shoe track: a) Shoe b) 2 jts casing c) Collar d) casing With centralizers placed as follows: e) 3 bow-springs TURBOLIZERS with stop collars in center of bottom 3 jts f) TURBOLIZERS across the bottom 3 couplings g) 1 TURBOLIZER across the coupling of every third jt for the next ±5500' (±45) but will be adjusted across potentially productive zones h) 1 TURBOLIZERS across the coupling of every third jt to surface shoe (±14) i) ESTIMATED TOTAL TURBOLIZER centralizers = ±65 w/3 stop collars 13. Run and cement 7" casing per cementing procedure (cement design is to address low fluid loss, formation compatibility of filtrate, RIGHT HAND SET) while reciprocating. Land hanger. Cement volumes are presently designed for ±6600' of fill (TOC ±4000'MD) with 40% excess. Adjust as necessary to insure top of cement to ±4000' MD. NOTE: Have casing running company supervisor and cementing supervisor ASSIST in filling out Casing and Cementing form. 14. Back out landing joint. Install packoff and test to 5000 psi. Run test plug and test BOPs to 250/4000 psi, hydril to 250/2500 psi. (AOGCC 48 hr notice) If AOGCC approves, casing may be tested here while testing BOPe. 15. Set wear bushing. 16. PU 2 7/8" tubing/workstring. Clean out and test to 4000 psi (w/ 9.6 ppg mud) -adjusted for mud wt in use at test. POOH. 17. Run CBL. Well Test/ Completion: 1. TIH w/mill and scrapers. Work same. 2. Test 7" casing to 4000 psi adjusting for mud weight. (Production MASP). 3. Run CBL. 4. Displace with completion fluid 5. Completion Procedure will follow with a Sundry. 6. Rig down and move out drilling rig or test/complete with existing. Cook Inlet Energy rrp North Fork#42-35 • Cook Inlet Energy HUGHES RIG:Miller 37 BOTTOM HOLE ASSEMBLY#2 8.75"Hole DEPTH IN 3,095' DEPTH OUT _ 10,563' TOTAL 7,468' OBJECTIVE: ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO. DESCRIPTION PROVIDER OD OD ID CONN CONN LENGTH LENGTH 1 8 3/4"(HCC)QD505X BHI 8.750 4 1/2 Reg Pin 1.20 1.20 2 6.3/4"Ultra XTreme Motor 8 5/8"UBHS(AKO1.2°)W/Float BHI 8.625 7.30 2.50 4 1/2 Reg B 4 1/2 IF B 23.00 24.20 3 6 3/4"NM String Stab w/8 5/8" Straight Blades BHI 8.625 6.75 2.81 4 1/2"IF P 4 1/2 IF B 5.00 29.20 4 6.3/4"NMCSDP BHI 6.75 2.81 4 1/2"IF P 4 1/2 IF B 10.00 39.20 5 Stop Sub BHI 6.75 2.81 4 1/2"IF P 6 3/4"T2 B 2.00 41.20 6 Ontrak - ��,r -C" / BHI 6.75 6 3/4"T2 P 6 3/4"T2 B 16.84 58.04 7 Modular Stabalizer BHI 8.625 6.75 2.81 6 3/4"T2 P 6 3/4"T2 B 3.94 61.98 8 BCPM, BHI 6.75 2.81 6 3/4"T2 P 6 3/4"T2 B 10.61 72.59 9 Stop Sub BHI 6.75 2.81 6 3/4"T2 P 4 1/2"IF B 2.45 75.04 10 NM Downhole Filter Sub BHI 6.75 2.88 4 1/2"IF P 4 1/2 IF B 5.27 80.31 11 2 Joints 6.3/4"NMCSDP BHI 6.75 2.813 4 1/2"IF P 4 1/2 IF B 62.00 142.31 12 8 Joints 5"HWDP RIG 5.00 3.00 4 1/2"IF P 4 1/2"IF B 248.00 390.31 13 Jars WFD 6.25 2.25 4 1/2"IF P 4 1/2"IF B 32.23 422.54 14 12Joints 5"HWDP RIG 5.00 3.00 4 1/2"IF P 4 1/2"IF B 372.00 794.54 15 5"Drill Pipe RIG 5.00 4.28 4 1/2"IF P 4 1/2"IF B 9768.09 10562.63 16 17 18 19 20 21 Notes and Comments 1.2 AKO yields 6.6 doglegs and can be rotated 80 max RPM Technical and Mechanical Specifications FLOW RATES:6.75 Ultra X-treme(265-660)Normal Flow BCPM Pulser(380/455-660) BHA AIR WEIGHT: MUD WEIGHTS: BHA WEIGHT IN MUD: MUD TYPE: BELOW JAR IN MUD AT 0°: RPM: BELOW JAR IN MUD AT 0°: WOB: BELOW JAR IN MUD AT 0°: Sensor Distance Information Survey: 52.2' ECD: 42.5' VSS: 52.2' Gamma Ray: 43.4' NonMag Below: 28.0' Resistivity: 47.4' NonMag Above: 90.1' NFU#42-35(Oct 7 2014)BHA's xlsx Cook Inlet Energy Mall North Fork#42-35 BAKER _ Cook Inlet Energy_ HUGHES RIG:Miller 37 BOTTOM HOLE ASSEMBLY#1 12.25"Hole DEPTH IN 0' DEPTH OUT 3,095' TOTAL 3,095' OBJECTIVE: ITEMS EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO.I DESCRIPTION PROVIDER OD OD ID CONN CONN LENGTH LENGTH 1 12.25"(HCC)VMD-3 BHI 12.25 6 5/8 Reg P 1.02 1.02 2 8"XTreme Motor 12 1/8"UBHS(AKO1.2 0)W/Float BHI 12.125 8.11 6 5/8 Reg B 6 5/8 Reg B 28.90 29.92 3 8"NM String Stab w/12 1/8" Straight Blades BHI 12.125 8.00 2.88 6 5/8 Reg P 6 5/8 Reg B 5.00 34.92 4 8"NMCSDP BHI 8.00 2.75 6 5/8 Reg P 6 5/8 Reg B 10.00 44.92 5 Stop Sub BHI 8.25 2.81 6 5/8 Reg P 8 1/4"T2 B 2.00 46.92 6 Ontrak(Gam/Res/PresNSS/Survey) ' BHI 8.39 2.76 8 1/4"T2 P 8 1/4"T2 B 18.96 65.88 7 12 1/8"Modular Stabalizer BHI 12.125 8.27 3.03 8 1/4"T2 P 8 1/4"T2 B 5.74 71.62 8 BCPM(Pulser) BHI 8.40 2.76 8 1/4"T2 P 8 1/4"T2 B 11.75 83.37 9 Stop Sub BHI 8.25 2.81 8 1/4"T2 P 6 5/8 Reg B 2.00 85.37 10 NM Downhole Filter Sub BHI 8.00 3.00 6 5/8 Reg P 6 5/8 Reg B 5.11 90.48 11 2 Joints 8"NMCSDP BHI 8.00 2.75 6 5/8 Reg P 6 5/8 Reg B 62.00 152.48 12 XO BHI 8.00 2.75 6 5/8 Reg P 4 1/2 IF B 3.00 155.48 13 8 Joints 5"HWDP RIG 5.00 3.00 4 1/2"IF P 4 1/2"IF B 248.00 403.48 14 Jars WFD 6.25 2.25 4 1/2"IF P 4 1/2"IF B 32.23 435.71 15 12Joints 5"HWDP RIG 5.00 3.00 4 1/2"IF P 4 1/2"IF B 372.00 807.71 16 5"Drill Pipe RIG 5.00 4.28 4 1/2"IF P 4 1/2"IF B 2300.00 3107.71 17 18 19 20 Notes and Comments 1.2AKO Yeilds 5.3 doglegs and can be rotated ata max RPM of 85 RPM Technical and Mechanical Specifications FLOW RATES:8"X-treme Motor 395-900 gpm 8.25"OnTrak MWD(Normal Flow config)530-925 gpm BHA AIR WEIGHT: MUD WEIGHTS: BHA WEIGHT IN MUD: MUD TYPE: BELOW JAR IN MUD AT 0°: RPM: BELOW JAR IN MUD AT 0°: WOB: BELOW JAR IN MUD AT 0°: Sensor Distance Information Survey: 60.4' ECD: 49.0' VSS: 60.4' Gamma Ray: 48 2' NonMag Below: 30.5' Resistivity: 53.6' NonMag Above: 92.1' NFU#42-35(Oct 7 2014)BHA's.xlsx G GE Oil & Gas I" 47.r 0 30.2" 2-9/16"5M NI 1 2-8/18'BM !! 7 41111-tv, 2-9/1r 5M —1 2-9/18'5M 111111 1 45.8' iiiii 11111 ) 11 2-9/16'5M 12 1 1l"5M 77" "1 791:5 , -Tr 26.5 to c 19.0• CCI 0 - al ■ Ns r w .7 11"5M J�. t46. 2-1/18'51.4 u, E [._.128.5to1. •_ � �# 0 LI ill : _ 31.7. -lr ' ii„ jai- r a_ 2-106'5M II ,_ r t III 26.O.D.Base Plate li 9-5/8"Casing 7'Casing 2-7/8'Tubing 1/4'Control Line ALL DIMENSIONS ARE APPROXIMATE This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved In writing, COOK INLET EN ERGY42-35 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. 9-5/8" x 7" x 2-7/8" 5M SH2 Wellhead Assembly, DRAWN CR 080CT14 With T-M40-CCL Tubing Hanger and Adapter Flange APP RFOR REF KN 080CT14 P gREFERENCE ONLY DRAWING NO. 1001107-2 _ Cook Inlet Energy_ Rig 37 Formerly Glacier 1 BOP Stack Flow Nipple -____ _ Flow Line r 1 2 7/8"x 5"variable 13 5/8"5M Annular t. Preventer Blind I— 1 < � 13 5/8"5M Double Ram Preventer Pipe R am 2 1/16"5M Blind Ram 2 1/16"5M Manually 3 1/8"5M Manually 5"pipe Operated Valves 7 < Operated Valve rail II Ill' ' _ ® Choke IT•-X'T. MIEN I 13 5/8"5M Cross 3 1/8"5M Hydraulically - Pipe Ram . Operated Valve 13 5/8"5M Single ____---► Bottom of Single gate must be Ram Preventer 24-45"from ground level for Glacier 1 rig placement. -._ 13 518"5M x 13 5/8"5M =1.1iinimmism Drilling Spool --- 11"5M x 13 5/8"5M DSA Glacier 1 Choke Manifold To Gas Buster To Blooey Line Bleed off Line to Shakers mom ‘117 ra Wir n 1 II II II I II I1 0DO 000 — 000 I it II Il I II It I IjI II' II I 1 Ir iim %II © I �I u u �TIP re I-1 1 TN © INNEN NEMu 101011 ° © _-11411\ / I I 3"5M Valves0 t 2 9/16" 10M Swaco l J 3 1/8"5M Manually Hydraulically Operated Adjustable Choke Choke Gauge Block Choke Hose to HCR � � (from BOP Stack) 0-6,000 psi Choke Control Pressure Gauge Pressure Sensor C O f. 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''••••111211111" 11'''''''.%..1111111111 o _ilii1 •,;iii s. isE E 'me ..._. 1 w II 111111101111110111M....."NI 11111111111101 I -7 • 1 IL n 74. n — — + I P iA .1 r.,1 ` , .. _ IL o -fix; .�/.- '.a- ... ' L N VI _ X 8) 0 o 12 _ 11 1•111,111111 W "l-a. .Y__ — — - U to 1 0 J ..1 NFU 42-35 Cuttings Handling Drill cuttings are centrifuged dry using the BOS solids handling package and bagged waiting on testing for hydrocarbons. The cuttings exiting the BOS unit are sufficiently dry to pass the paint filter test. If not, either sawdust or cement will be added. They will be stored in containment on site and sent to the Borough Land fill in Soldotna once cleared for disposal. Liquids will be injected in the disposal annulus of NFU 34-26 and or taken to one of CIE's Class 1 disposal wells at the Osprey Platform or West McArthur River Field. BOS SOLUTIONS REDEFINING EFFICIENCY •:.,4,4:4.4';'/'y4ffil, ._______.._________ .:-_-=-=----------"------1 \ - -- - f --`'. .,..„,•4.. . ic--- ------ _ ) ., ' ,,,4.',.*•'''' ___ t.,'' ,- __------ --.;'---S------------ I , , /... ., i /4 ; t ,.!:...' 7 -% 4.--74 ... . . .. .- • ,,%'' • . ' I- ill W 4.111, 'A BS * _21 1 , , a 1 1 / 1 , II ANL .., . _ F047- sx BOS TANK SYSTEM IV SHIPPING DIMENSIONS WORKING DIMENSIONS SHIPPING DESCRIPTION LXWXH LXWXH WEIGHT Patented Fluids Management Process 2 - 20 bbl(3.2 m3)Polymer Injection Tanks 423"x 126"x 9'4" 473"x 12'6"x 1711" ' 33,000 lb 216 bbl(34.3 m3)Flocculation Tank 25 hp 4" Mud Gun Pump Hydraulic Dual Centrifuge Platform 12.9 m x 3.8 m x 2.9 m 14.4 m x 3.8 m x 5.5 m 14,969 kg Power Required 1 - 480v, 100amp, 3w4p www.bos-solutions.com Equipment 4hrf 1.877.267.3434 Specifications Schwartz, Guy L (DOA) From: Stephen Hennigan <shennigan@peiinc.com> Sent: Tuesday, October 21, 2014 12:10 PM To: Schwartz, Guy L (DOA) Subject: RE: North Fork 24-26 (PTD 214-166) To confirm or telephone conversation, no variance is requested re surveys on the 42-35. On BOTH the 24-26 and the 42-35, the surface hole will be drilled entirely with a 12 %" bit. T, ui ra acrd 4aec a Arad 4it�./ Stephen F. Hennigan Project Engineer/Manager 500 Dover Boulevard, Suite 310 l Lafayette, LA 70503 w: 337-984-2603 le: 337-849-5345 (mobile) ,'s=;;• Petroleum ,t4 SIERRA :%=% Engineers ;: HAMILTON Sierra-Hamilton Confidentiality Notice:The information transmitted is intended only for the person(s)or entity to which it is addressed. It may contain confidential and/or privileged information or material.Any review, retransmission,dissemination to other use of,or taking of any action in reliance upon this information by persons or entities other than the intended recipient is prohibited. If you received this in error, please contact the sender and delete the material from any computer. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. I TRANSMITTAL LETTER CHECKLIST WELL NAME: .lam 0--,. (.._ 1;7 L 1 1 67z—..3S PTD: 2/ V /7e/ / Development Service Exploratory Stratigraphic Test Non-Conventional er FIELD: 44144POOL: /V 7 " ' le-71�= L/4"1M1 -1 —" ` Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . 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. 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V. cnV , 00a. �, a. �, o, m, 03, �. 5, ) M, a0tn, n, 0,, n) W a 0 N M ,C) (O N. a0 O) O N M ,f) O )� CC O) O N M (C) Is- CO 0) VEO N__ M V' U) (O I� a0 T N N N N N N N N N N M M M M M M 4) M_ M M_ U V V a C_ O O O c G O C w N I O (.9 O N U D as 10 a) O O 0 co O N 0 NO O ."/1) d '4R o 0 0 I'. = J N Nc O O C U aa �jpE aw a) J a Q a C w a C7 0 a U) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. North Fork Unit 42-35 Kenai Peninsula Borough, Alaska January 11, 2015 to January 17, 2015 Provided by: Approved by: Greg Kirkland Compiled by: Ralph Winkelman B r i t t e n A d a m s Distribution Date: February 06, 2015 NFU 42-35 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 GENERAL WELL DETAILS...................................................................................................................3 2.1 Well Objectives...............................................................................................................................3 2.2 Well Resume ..................................................................................................................................3 2.3 Hole Data........................................................................................................................................3 3 GEOLOGICAL DATA.............................................................................................................................4 3.1 Lithostratigraphy .............................................................................................................................4 3.2 Lithology Review.............................................................................................................................5 3.3 Sampling Program........................................................................................................................17 4 DRILLING DATA..................................................................................................................................18 4.1 Daily Activity Summary.................................................................................................................18 4.2 Surveys.........................................................................................................................................21 4.3 Bit Record.....................................................................................................................................25 4.4 Mud Record ..................................................................................................................................26 4.5 Drilling Progress Chart..................................................................................................................27 5 DAILY REPORTS ................................................................................................................................28 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Combo Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) Final Well Data on CD NFU 42-35 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Computer – Drill Floor Monitor Pason Computer – Pit Monitor Pason Computer for Company Man Pason Computer for Tool Pusher Pason Computers for Mudloggers (4) Rigwatch Server, Rigwatch Data, DML Edit, Sample Catcher Ditch gas Air Motor, Flame Ionization Total Gas & Chromatography. Hook Load / Weight on bit Pason WITS feed Mud Flow In Pason WITS Feed Mud Flow Out Pason WITS Feed Pit Volumes, Pit Gain/Loss Pason WITS Feed Pump Pressure Pason WITS Feed Pump Stroke Counters (3) Pason WITS Feed Rate of Penetration Pason WITS Feed RPM Pason WITS Feed Torque Pason WITS Feed 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML032 Mud Loggers Years *1 Days *2 Sample Catchers Years Days Technician Days Ralph Winkelman 24 21 Tyler Harris 1 11 Britten Adams 4 24 Dickey Hudgins 6 11 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. NFU 42-35 3 2 GENERAL WELL DETAILS 2.1 Well Objectives The objective of NFU 42-35 is to drill and log a multiple zone gas development well in the Kenai Peninsula, North Fork Unit, Anchor Point with a minimum of hole problems or other concerns. 2.2 Well Resume Operator: Cook Inlet Energy Well Name: North Fork Unit #42-35 Field: North Fork Field County: Kenai Borough State: Alaska Company Representatives: Al Lunda, Rod Maniaci, Stephen Ratcliff, Monie Sainz Location: Surface Coordinates 588 FSL 1453 FEL, Sec 26 T4S R14W SM, X = 199958 Y = 2121128 Ground Elevation 657.80’ AMSL Rotary Table Elevation 678.38’ AMSL Classification: Development Gas, Multiple Zone API #: 50 – 231 – 20046 – 00 – 00 Permit #: 214 – 170 Activity Code: AFE # 146005 Rig Name / Type: Miller #37 / Land / Telescopic Double Spud Date January 2, 2015 Total Depth Date: January 17, 2015 Total Depth 9968’ Primary Targets 4900 SD, 5600 SD, 6000 SD, 7800 SD, 8100 SD, Primary Target Depths MD/ TVD 5517’/ 4903’, 6354’/ 5586’, 6830’/ 5975’, 8774’/ 7832’, 9000’/ 8058’ Total Depth Formation: Tyonek LWD-MWD and Directional Services. Baker Hughes Inteq Wireline Logging Services Pollard Wireline Services (CBL only) Drilling Fluids Service MI Swaco CANRIG Logging Geologists: Ralph Winkelman, Britten Adams CANRIG Sample Catchers: Dickey Hudgins, Tyler Harris 2.3 Hole Data Maximum Depth Shoe Depth Hole Section ( “ ) MD (ft) TVD(ft) T.D. Formation Mud Weight (ppg) Dev. (oinc) Casing (dia “) MD (ft) TVD (ft) LOT (ppg) (Conductor) 16 138 137.99 Recent 8.8 0.93 16 138 137 n/a 12 ¼ 2920 2786.19 Beluga 9.2 35.10 9 ⅝ 2920 2786 15.1 8 ¾ 9968 9046.04 Tyonek 9.4 4.11 7 9950 9028 NFU 42-35 4 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All formations or markers provided by Cook Inlet Exploration Senior Geologist Greg Kirkland. Zone or Horizon Actual Depth (ft) Tops or Markers MD TVD SSTVD Beluga 1390 1326 647 Green coal 2474 2409 1731 Gray/Orange Coal 4992 4464 3785 Tyonek 5300 4716 4037 4900' "A" Sd 5520 4896 4218 4900' "B" Sd 5588 4952 4273 5300' Sd 5970 5266 4587 5450' SD 6190 5448 4769 5600' Sd 6370 5596 4917 5600' "B" Sd 6462 5673 4995 Coal Mkr 6547 5742 5063 6000' Sd 6858 6007 5329 6100' Sd 6980 6116 5437 6700' Sd 7655 6746 6068 6800' Sd 7748 6836 6157 7200' Sd 8150 7230 6552 Mid TY 8518 7597 6919 7800' Sd 8889 7968 7290 7950' Sd 8948 8027 7349 8000' Sd 8980 8059 7381 8150' Sd 9100 8179 7501 Ty Blue Mkr 9360 8439 7760 8400' Sd 9392 8471 7792 8500' Sd 9478 8557 7878 Base Sd & Potential to date 9544 8623 7944 9000' Sd 9546 8625 7946 9100' Sd 9728 8807 8128 Est Base Sd 9758 8837 8158 NFU 42-35 5 3.2 Lithology Review Tuffaceous Claystone/ Tuffaceous Siltstone (2920' - 3010') = medium to medium light gray with light brownish gray secondary hues; very soft and sticky; shape less, amorphous cuttings; silty to clayey texture; dull to earthy luster; hydrophilic; very soluble and expansive; poor cohesiveness; fair to good adhesiveness non calcareous; firmer pieces have dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds throughout. Sand/ Sandstone (3010' - 3080') = medium to medium dark gray overall with individual grains dominantly medium to dark gray, dark greenish gray, black, clear to translucent quartz and volcanic glass very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; loose grains dominant with trace dark gray sandstone with salt and pepper appearance; very hard; shattered fragments; very fine to fine grain very calcareous cement; trace thin coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (3080' - 3160') = medium to medium light gray with medium dark gray and light brownish gray secondary hues; soft to slightly firm to fragile; mushy to pasty; shapeless, globular to irregular shaped cuttings; silty to clayey texture; dull to earthy luster; moderate to very soluble and expansive; hydrophilic; poor to fair cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions in firmer fragments; continued thin (1' - 3') coal beds throughout. Coal/ Carbonaceous Shale (3160'-3220') = black with brownish black secondary hues platy to splintery to blocky; hard and brittle to slightly malleable; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant with trace conchoidal and birdeye; sub bituminous; trace prolonged out gassing bubbles from harder fragments; coal present as 1' - 3' beds with trace 5' or larger in dominantly claystone/siltstone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (3220' - 3290') = medium to medium light gray with light brownish gray secondary hues; very soft and sticky; shapeless, amorphous cuttings; silty to clayey texture; dull to earthy luster; hydrophilic; very soluble and expansive; poor cohesiveness; fair to good adhesiveness non calcareous; firmer pieces have dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds throughout. Tuffaceous Claystone/ Tuffaceous Siltstone (3290' - 3350') = medium light gray with medium gray and light brownish gray secondary hues; shapeless, globular cuttings; mushy to clumpy; silty to clayey texture; dull, earthy to slightly greasy luster; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Tuffaceous Claystone/ Tuffaceous Siltstone (3350' - 3420') = medium to medium light gray with medium dark gray and light brownish gray secondary hues; soft to slightly firm to fragile; mushy to clumpy; shapeless, globular to irregular shaped cuttings; silty to clayey texture; dull to earthy luster; moderate to very soluble and expansive; hydrophilic; poor cohesiveness; fair to good adhesiveness; non calcareous. Tuffaceous Claystone (3420' - 3460') = medium dark gray with slight bluish gray hues colors; lumpy to clotted consistency; malleable tenacity; earthy to irregular fracture; nodular to massive cutting habits; dull to earthy when and waxy when wet luster; colloidal to clayey texture; thick to massive bedding structure; adhesive to expansive clay properties; no HCL reaction. NFU 42-35 6 Sand/ Sandstone (3475' - 3530') = clear to translucent with gray to black lithic color, light olive brown hues, and medium gray to dark gray hues color; unconsolidated sands to firm friable consolidated sandstones; quartz dominated framework; fine to very fine grain size; angular to subangular angularity; low sphericity; overgrowth to grain enlargement cement for sandstone; thin bedding structure; weak HCL reaction in bulk sample. Tuffaceous Siltstone (3540' - 3590') = medium grey to medium dark gray with medium bluish grey hues colors; very fine grain to fine grain size; very well to well sorting; easily friable to friable hardness; brittle tenacity; earthy fracture; tabular to wedgelike cutting habits; dull to earthy when dry and waxy when wet luster; silty to matte texture; thin to laminae bedding structure; very weak HCL reaction in bulk sample. Tuffaceous Claystone (3620' - 3695') = medium gray to dark gray with bluish dark gray hues, slight brownish gray hue colors; adhesive to expansive clay properties; lumpy to clotted consistency; malleable to pulverulent tenacity; earthy to irregular fracture; massive to nodular cutting habits; waxy when wet and earthy to dull when dry luster; clayey to silty with occasional smooth texture; thick to massive bedding structure; weak to moderate HCL reaction in bulk sample. Sand/ Sandstone (3705' - 3770') = translucent to clear with medium dark gray hues, dark gray hues, milky white minerals, light brownish gray mineral hue colors; quartz dominant with calcareous minerals framework; very fine to fine grain size; well to fair sorting; angular to subangular angularity; very low to low sphericity; unconsolidated sand and consolidated sandstone with friable to firm friable hardness; overgrowth and grain enlargement cement; thin bedding structure; moderate to high HCL reaction in bulk sample. Tuffaceous Claystone/ Tuffaceous Siltstone (3770' - 3850') = medium to medium light gray with light brownish gray and light olive gray secondary hues; very soft and sticky; irregular to shapeless; mushy to clumpy; silty to clayey texture dull to earthy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions in firmer fragments; trace thin coal/ carbonaceous shale beds. Coal/ Carbonaceous Shale (3850'-3910') = black with brownish black secondary hues platy to splintery to blocky; hard and brittle to slightly malleable; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant with trace conchoidal and birdeye; sub bituminous; trace prolonged out gassing bubbles from harder fragments; coal present as 1' - 3' beds with trace 5' or larger in dominantly claystone/ siltstone formation. Sand/ Sandstone (3910' - 3980') = medium to medium dark gray overall with trace salt and pepper appearance, individual grains dominantly medium to dark gray to black and clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; dominantly unconsolidated with trace very hard sandstone; medium gray; very fine; very calcareous cement; trace salt and pepper sandstone; fine to medium; angular; very hard; very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (3980' - 4050') = medium light gray with medium gray and light brownish gray secondary hues; shapeless, globular cuttings; mushy to clumpy; silty to clayey texture; dull, earthy to slightly greasy luster; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/ Sandstone (4050' - 4110') = medium to medium dark gray overall with individual grains dominantly medium to dark gray, dark greenish gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; loose grains dominant with trace dark gray sandstone with salt and pepper appearance; very hard; shattered fragments; very fine to fine grain; very calcareous cement; trace thin coal beds throughout. NFU 42-35 7 Coal/ Carbonaceous Shale (4110'-4170') = black with brownish black secondary hues platy to splintery to blocky; hard and brittle to slightly malleable; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant sub bituminous grading to carbonaceous shale; trace out gassing bubbles from hard fragments; present as thin beds in dominantly tuffaceous claystone/ siltstone formation. Tuffaceous Claystone/ Tuffaceous Siltstone (4170' - 4240') = medium to medium light gray with light gray, light brownish gray and light olive gray secondary hues; very soft to trace firm; irregular to shapeless, globular cuttings; very sticky; silty to clayey texture; mushy to clumpy; dull, earthy to greasy luster; hydrophilic; very soluble; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (4240' - 4300') = medium to medium light gray with light brownish gray and light olive gray secondary hues; very soft and sticky; irregular to shapeless; mushy to clumpy; silty to clayey texture dull to earthy luster; hydrophilic; very soluble and moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations. Sand/ Sandstone (4300' - 4360') = medium to medium dark gray overall with trace medium light to light gray, individual grains dominantly medium to dark gray to black and clear to translucent quartz and volcanic glass; very fine upper to fine upper, dominantly lower; angular to subangular; fair to good sorting; dominantly unconsolidated with trace very hard sandstone; medium light gray; fine very calcareous cement. Coal/ Carbonaceous Shale (4360'-4420') = black with brownish black secondary hues; hard and brittle to trace crumbly; platy to blocky; planar fracture dominant; earthy to vitreous luster; smooth to slightly gritty texture; sub bituminous to bituminous, occasionally grading to carbonaceous shale; trace out gassing bubbles from larger fragments. Tuffaceous Claystone/ Tuffaceous Siltstone (4420' - 4490') = medium light gray with medium gray and light brownish gray secondary hues; shapeless, globular cuttings; mushy to clumpy; silty to clayey texture; dull, earthy to slightly greasy luster; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; continued trace thin coal/ carbonaceous shale beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (4490' - 4550') = medium to medium light gray with light gray and light brown and light brownish gray secondary hues; soft, mushy to slightly firm and fragile; irregular, wedgelike to shapeless cuttings; silty to clayey texture; dull to earthy luster; very soluble and moderately expansive; hydrophilic; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black micro-thin laminations and inclusions. Sandstone (4550' - 4620') = medium to medium dark gray overall with trace medium light to light gray, individual grains dominantly medium to dark gray to black and clear to translucent quartz and volcanic glass; very fine upper to fine upper, dominantly lower; angular to subangular; fair to good sorting; hard; angular shattered fragments; fine; very calcareous cement. Coal/ Carbonaceous Shale (4620'-4670') = black with brownish black secondary hues platy to splintery to blocky; hard and brittle to slightly malleable; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant sub bituminous grading to carbonaceous shale; trace out gassing bubbles from hard fragments; present as thin beds in dominantly tuffaceous claystone/ siltstone formation. NFU 42-35 8 Tuffaceous Claystone/ Tuffaceous Siltstone (4670' - 4740') = medium to medium light gray with light gray, light brownish gray and light olive gray secondary hues; very soft to trace firm; irregular to shapeless, globular cuttings; very sticky; silty to clayey texture; mushy to clumpy; dull, earthy to greasy luster hydrophilic; very soluble; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; abundant thin coal beds. Tuffaceous Claystone (4745' - 4795') = medium gray to medium dark gray with light gray hues color; cohesive to expansive clay properties; clotted to clumpy consistency; malleable to pulverulent tenacity; earthy to irregular cutting habits; dull to earthy when dry and waxy luster when wet; clayey to smooth texture; massive to thick bedding structure; very weak HCL reaction in bulk sample. Sandstone/ Sand (4805' - 4870') = clear to translucent with dark gray minerals, milky white minerals, light brownish gray minerals hues colors; quartz dominant with few coal and lithics contacts framework; very fine to medium grain size; angular to subrounded angularity; well to fair sorting; low to moderate sphericity; unconsolidated sands and friable to consolidated sandstone hardness; overgrowth to grain enlargement cement; matrix and cement grain support; thin bedding structure; moderate HCL reaction in bulk sample. Coal (4880' - 4915') = black to grayish black with dark brown grayish hues colors; dense to crunchy tenacity; hackly to splintery fracture; wedgelike to bladed edges cutting habits; polished luster; abrasive to matte texture; thin laminae bedding structure; very weak HCL reaction in bulk sample. Tuffaceous Siltstone (4925' - 4970') = medium gray to dark medium gray with light brownish hues, dark brownish gray laminae interbedded colors; crumbly to brittle tenacity; blocky to earthy fracture; tabular to wedgelike cutting habits; dull to earthy when dry luster; silty to matte texture; banded to thick bedding structure; moderate HCL reaction in bulk sample. Coal (4980' - 5015') = black to grayish black with dark brown grayish hues colors; tough to crunchy tenacity; hackly to splintery fracture; wedgelike to bladed edges cutting habits; polished luster; abrasive to smooth texture; thin laminae bedding structure; very weak HCL reaction in bulk sample. Tuffaceous Claystone (5025' - 5075') = medium gray to medium dark gray with light gray hues color; cohesive to expansive clay properties; clotted to clumpy consistency; malleable to pulverulent tenacity; earthy to irregular cutting habits; dull to earthy when dry and waxy luster when wet; clayey to smooth texture; thick bedding structure; very weak HCL reaction in bulk sample. Tuffaceous Claystone/ Tuffaceous Siltstone (5080' - 5180') = medium to medium light gray and light brownish gray with brown secondary hues; soft to slightly firm; irregular to shapeless with trace pdc bit action shaped cuttings; silty to clayey texture; dull to earthy luster; moderately soluble and expansive; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Tuffaceous Claystone/ Tuffaceous Siltstone (5180' - 5240') = medium to medium light gray with light gray, light brownish gray and light olive gray secondary hues; very soft to trace firm; irregular to shapeless, globular cuttings; very sticky; silty to clayey texture; mushy to clumpy; dull, earthy to greasy luster hydrophilic; very soluble; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations. Sand/ Sandstone (5240' - 5310') = medium to medium dark gray overall with individual grains dominantly medium to dark gray, dark greenish gray, black, clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; loose grains dominant with trace light gray sandstone with salt and pepper appearance; hard; fine grain; very calcareous cement. NFU 42-35 9 Tuffaceous Claystone/ Tuffaceous Siltstone (5310' - 5370') = note a gradual shift in color to medium light to light gray with light olive gray and light yellowish gray secondary hues; soft and fragile; irregular shaped with trace pdc bit action cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; moderately soluble and expansive; poor to fair adhesiveness and cohesiveness; non calcareous; trace dark brown to black carbonaceous micro-thin laminations and inclusions. Sand/ Sandstone/ Tuffaceous Sandstone (5370' - 5440') = medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; dominantly unconsolidated with trace light gray, salt and pepper sandstone; fine; hard; very calcareous cement; trace ashy tuff supporting loose sand grains. Tuffaceous Sandstone/ Sand (5440' - 5500') = very light gray to bluish white overall with abundant very light gray, light yellowish gray and light brownish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; well sorted; unconsolidated to very loose ashy tuff supporting matrix; very fragile pulverulent; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (5500' - 5560') = medium light to light gray with very light brownish gray secondary hues; soft to slightly firm; irregular to shapeless, globular cuttings silty to clayey texture; dull luster; hydrophilic; moderately soluble and expansive; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/ Tuffaceous Sandstone (5560' - 5620') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to medium gray and dark gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported by ash matrix; very fragile and pulverulent; multihued, dominantly grayish white; non calcareous. Coal/ Carbonaceous Shale (5620' - 5680') = black with brownish black secondary hues platy to splintery to blocky; hard and brittle to slightly crumbly; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant with trace conchoidal and birdeye; sub bituminous to bituminous; weak trace out gassing bubbles on larger fragments. Tuffaceous Sandstone/ Sand (5680' - 5740') = very light gray to grayish white with a mottled appearance, individual grains dominantly clear to translucent quartz and volcanic glass with trace dark lithics; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted; loosely consolidated in ashy matrix; very fragile; pulverulent; crumbly to crunchy; non calcareous; trace light gray sandstone; fine grain; hard; well sorted; very calcareous cement. Sand/ Tuffaceous Sandstone (5740' - 5800') = very light gray overall with weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace darker lithics; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted; unconsolidated to very loosely consolidated in ashy tuff matrix; very light gray to grayish white with a mottled appearance; fragile to pulverulent; crumbly to crunchy; trace glass shards visible; non calcareous. Coal/ Carbonaceous Shale (5800’ - 5870') = black with brownish black secondary hues; platy to splintery to blocky; hard and brittle to slightly crumbly; earthy to vitreous luster; smooth to slightly earthy texture; planar fracture dominant with trace conchoidal and birdeye; sub bituminous to bituminous; weak trace out gassing bubbles on larger fragments; coal commonly grades to carbonaceous shale. NFU 42-35 10 Tuffaceous Sandstone/ Sand (5870' - 5930') = very light gray to grayish white overall with abundant very light gray, light yellowish gray and light brownish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; well sorted; unconsolidated to very loose ashy tuff supporting matrix; very fragile pulverulent; non calcareous. Sand/ Tuffaceous Sandstone (5930' - 6000') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to medium gray and dark gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported by ash matrix; very fragile and pulverulent; multihued, dominantly grayish white; non calcareous; trace sandstone; light gray; hard; fine; very calcareous cement. Tuffaceous Claystone/ Tuffaceous Siltstone (6000' - 6070') = medium to medium light gray with very light gray and very light brownish gray secondary hues; firm to moderately hard; irregular to wedgelike cuttings, trace pdc bit action shaped; silty to clayey to slightly gritty texture; dull to earthy luster; poor adhesiveness; fair to good cohesiveness; slight to moderately soluble; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; light gray siltstone commonly grades between silty sandstone and sandy siltstone. Tuffaceous Sandstone/ Sand (6070' - 6130') = very light gray to grayish white with a mottled appearance, individual grains dominantly clear to translucent quartz and volcanic glass with trace dark lithics; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted; loosely consolidated in ashy matrix; very fragile; pulverulent; crumbly to crunchy; non calcareous. Sand/ Tuffaceous Sandstone (6130' - 6190') = very light gray overall with a weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace darker lithics; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted; unconsolidated to very loosely consolidated in ashy tuff matrix; very light gray to grayish white with a mottled appearance; fragile to pulverulent. Tuffaceous Siltstone (6195' - 6235') = medium dark gray to medium gray with brownish gray hues color; brittle to crumbly; earthy fracture; tabular to wedgelike with slight blocky cutting habits; dull to earthy when dry and waxy when wet luster; matte to silty texture; thick bedding structure; very weak HCL reaction in bulk sample. Tuffaceous Sandstone (6245' - 6310') = clear to translucent with milky white minerals, black minerals, medium dark gray mineral, occasional pale yellowish orange mineral and dark brownish black banded interbedded with colors; quartz dominant framework; very fine to fine grain size; well to very well sorting; subrounded to subangular ; low to moderate sphericity; consolidated to friable hardness; matrix grain support; thick and occasional banded bedding structure; weak HCL reaction in sample. Coal (6320' - 6330') = black to grayish black with dark brownish yellow hues color; tough to dense and stiff tenacity; hackly to splintery with occasional conchoidal fractures; bladed edge and wedgelike cutting habits; sparkling to polished luster; smooth to abrasive texture; thin lenticular bedding structure; weak HCL reaction in bulk sample. Tuffaceous Sandstone (6370' - 6435') = translucent to clear with milky white minerals, black minerals, medium dark gray mineral, occasional pale yellowish orange mineral and dark brownish black bands interbedded within colors; quartz dominant framework; very fine to fine grain size; well to very well sorting; subrounded to subangular; low to moderate sphericity; consolidated to friable hardness; matrix grain support; thick to occasional laminae bands bedding structure; weak HCL reaction in sample. NFU 42-35 11 Tuffaceous Sandstone (6445' - 6505') = milky white to medium light gray minerals, black minerals, medium dark gray mineral, translucent to clear minerals hues colors; quartz dominant with lithic framework; very fine to fine grain size; well to very well sorting; subrounded to subangular angularity; low to very low sphericity; consolidated with easily friable to friable hardness; matrix grain support; thick bedding structure; moderate to strong HCL reaction in bulk sample. Coal (6530 - 6580') = black to grayish black with dark brownish yellow hues color; tough to dense and stiff tenacity; hackly to splintery with occasional conchoidal fractures; bladed edge and wedgelike cutting habits; sparkling to polished luster; smooth to abrasive texture; thin lenticular bedding structure; weak HCL reaction in bulk sample. Sand/ Sandstone (6580' - 6630') = medium light to light gray with weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted weak to moderate calcareous cement. Tuffaceous Sandstone/ Sand (6630' - 6690') = very light gray with mottled appearance from very light brown. light gray, light greenish and light bluish gray secondary hues; fragile to slightly firm; crunchy to crumbly; sparkly luster from ash; gritty texture; moderate to very calcareous cement; acts as supporting matrix for loose sand grains. Tuffaceous Claystone/ Tuffaceous Siltstone (6690' - 6750') = light gray to light brownish gray with light olive gray secondary hues; firm to fragile and crumbly; irregular to wedgelike with pdc bit action shaped cuttings common; silty to clayey texture; dull to earthy luster; non calcareous; trace light to very light gray siltstone grades between silty sandstone and sandy siltstone; firm to hard; moderate to very calcareous. Coal/ Carbonaceous Shale (6750' - 6810') = black with brownish black and grayish black secondary hues; hard and brittle to crumbly; platy to flaky; blocky to planar fracture with trace conchoidal and birdeye present; vitreous to trace earthy luster; smooth to trace silty texture; bituminous; coal occasionally grades to carbonaceous shale; weak trace visible out gassing bubbles observed. Tuffaceous Siltstone/ Tuffaceous Claystone (6810' - 6880') = light gray to light brownish gray with olive gray secondary hues; irregular, wedgelike with pdc bit action shaped cuttings; very firm and brittle to very soft; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; light gray siltstone commonly grades to sandy siltstone/ silty sandstone; moderately hard; very calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (6880' - 6940') = light gray to light brownish gray with light olive gray secondary hues; firm to fragile and crumbly; irregular to wedgelike with pdc bit action shaped cuttings common; silty to clayey texture; dull to earthy luster; non calcareous; trace light to very light gray siltstone grades between silty sandstone and sandy siltstone; firm to hard; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (6940' - 7000') = medium light to light gray to light brownish gray with light olive gray and light yellowish gray secondary hues; very soft and fragile to firm; irregular shaped with pdc bit action shaped cuttings common; silty to clayey texture; dull, earthy to slightly waxy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sand/ Tuffaceous Sandstone (7000' - 7070') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to medium gray and dark gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported by ash matrix; very fragile and pulverulent; multihued, dominantly grayish white; non calcareous; trace sandstone; light gray; hard; fine; very calcareous cement. NFU 42-35 12 Coal/ Carbonaceous Shale (7070' - 7120') = black with brownish black and grayish black secondary hues; hard and brittle to crumbly; platy to flaky; blocky to planar fracture with trace conchoidal and birdeye present; vitreous to trace earthy luster; smooth to trace silty texture; bituminous; coal occasionally grades to carbonaceous shale; weak trace visible out gassing bubbles observed. Sand (7130' - 7185') = clear to translucent with light gray to medium dark gray minerals, light brownish mineral, slight milky white minerals, and black lithics color; quartz dominant with lithic and calcareous framework; very fine to fine grain size; well to very well sorting; subangular to angular angularity; low sphericity; unconsolidated sands; thin to contorted bedding structure; moderate HCL reaction in bulk sample. Tuffaceous Sandstone (7195' - 7195') = light gray to milky white with medium gray hue, medium dark gray hues, very pale orange hues, pale yellowish orange hues, and pale yellowish brown hues colors; crumbly to brittle fracture; wedgelike to tabular cutting habits; silty to sucrosic texture; quartz dominant framework; very fine to fine grain size; well sorting; subangular to subrounded angularity; low to moderate sphericity; consolidated sand with easily friable to friable hardness; tuff matrix grain support; thin to thick bedding structure; moderate HCL reaction in bulk sample. Tuffaceous Siltstone (7280' - 7325) = medium dark gray to medium gray with occasional brownish gray hues, dark yellowish gray hues, and brownish black hues colors; stiff to brittle tenacity; earthy fracture; elongated to tabular cutting habits; dull to earthy when dry luster; matte to silty texture; thick bedding structure; weak to moderate HCL reaction in bulk sample. Coal (7355 - 7395') = black to grayish black with dark brownish yellow hues color; tough to crunchy and stiff tenacity; hackly to splintery with occasional conchoidal fractures; bladed edge and wedgelike cutting habits; resinous to polished luster; smooth to abrasive texture; thin bedding structure; gas bubbles appear on coal; weak HCL reaction in bulk sample. Sand (7410' - 7460') = clear to translucent with light brownish minerals, light gray minerals, light brownish gray minerals, and dark gray minerals colors; quartz dominant with calcareous framework; very to fine grain size; well to very well sorting; subangular to subrounded angularity; low sphericity; unconsolidated sands; thin bedding structure; moderate HCL reaction in bulk sample. Tuffaceous Siltstone (7470' - 7520') = medium dark gray to medium gray with occasional brownish gray hues, dark yellowish gray hues, and brownish black hues colors; crumbly to stiff tenacity; earthy fracture; elongated to tabular cutting habits; dull to earthy when dry luster; matte to silty texture; thick with occasional dark brown bands interbedded bedding structure; weak HCL reaction in bulk sample. Sandstone (7530' - 7590') = medium dark gray to light medium gray with clear to translucent minerals, light olive gray hues, and light brownish gray hues color; quartz dominant framework; very fine to fine grain size; well to fair sorting; subrounded to subangular angularity; low to moderate sphericity; consolidated sands with friable to firm friable hardness; grain enlargement cement; matrix and cement grain support; thin bedding structure; moderate to strong HCL reaction in bulk sample. Tuffaceous Siltstone (7600' - 7645') = medium dark gray to medium gray with occasional brownish gray hues, dark yellowish gray hues, and brownish black hues colors; stiff to brittle tenacity; earthy fracture; elongated to tabular cutting habits; dull to earthy when dry luster; matte to silty texture; thick bedding structure; moderate to strong HCL reaction in bulk sample. Coal (7655 - 7700') = black to grayish black with dark brownish yellow hues color; tough to dense with stiff tenacity; hackly to splintery with occasional conchoidal fractures; bladed edge and wedgelike cutting habits; resinous to polished luster; smooth to abrasive texture; thin bedding structure; gas bubbles appear on coal; weak to moderate HCL reaction in bulk sample. NFU 42-35 13 Sand/ Tuffaceous Sandstone (7710' - 7770') = medium light to light gray with light greenish gray secondary hues and weak salt and pepper appearance overall, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and light greenish gray, trace black; very fine lower to medium lower, dominantly fine lower; angular to subangular; moderately well sorted; dominantly unconsolidated with ash matrix supported grains; very light gray with mottled appearance; fragile; calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (7770' - 7830') = medium to medium light gray with gray and light brownish gray secondary hues; irregular with pdc bit action shaped cuttings; silty to clayey to slightly gritty texture; dull to earthy to slightly waxy luster; firm to fragile; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Coal/ Carbonaceous Shale (7830' - 7890') = black with brownish black and grayish black secondary hues; hard and brittle to crumbly; platy to flaky; blocky to planar fracture with trace conchoidal and birdeye present; vitreous to trace earthy luster; smooth to trace silty texture; bituminous; coal occasionally grades to carbonaceous shale; weak trace visible out gassing bubbles observed. Sand/ Sandstone (7890' - 7950') = medium light gray with weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and black; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted; well consolidated; blocky fragments; hard; slight to moderate calcareous cement; trace very light gray siltstone grades between sandy siltstone and silty sandstone; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (7950' - 8010') = medium light to light gray to light brownish gray with light olive gray and light yellowish gray secondary hues; very soft and fragile to firm; irregular shaped with pdc bit action shaped cuttings common; silty to clayey texture; dull, earthy to slightly waxy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Tuffaceous Claystone/ Tuffaceous Siltstone (8010' - 8080') = medium gray to grayish brown with light yellowish gray and light gray secondary hues; soft to very firm to hard; irregular to wedgelike and massive cuttings; silty to clayey texture; dull to earthy to waxy luster; poor adhesiveness; fair to good cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; medium light gray siltstone grades between silty sandstone and sandy siltstone; very firm to hard. Coal/ Carbonaceous Shale (8080' - 8140') = black with brownish black and grayish black secondary hues; hard and brittle to crumbly; platy to flaky; blocky to planar fracture with trace conchoidal and birdeye present; vitreous to trace earthy luster; smooth to trace silty texture; bituminous; coal occasionally grades to carbonaceous shale; none to very weak out gassing observed. Tuffaceous Sandstone/ Sand (8140' - 8200') = very light gray to light grayish white with mottled appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark lithics; very fine to medium lower, dominantly fine; angular to subangular; well sorted; sandstone is very fragile to pulverulent; crunchy to crumbly; glass shards visible; non to very calcareous; interbedded between coal beds; black; hard; trace out gassing observed. Tuffaceous Sandstone/ Sand (8200' - 8270') = very light gray with mottled appearance from very light brown. light gray, light greenish and light bluish gray secondary hues; fragile to slightly firm; crunchy to crumbly; sparkly luster from ash; gritty texture; moderate to very calcareous cement; acts as supporting matrix for loose sand grains; clear to translucent quartz and volcanic glass with trace dark lithics; very fine lower to medium lower, dominantly fine; angular to subangular; well sorted. NFU 42-35 14 Sand/ Tuffaceous Sandstone (8270' - 8330') = medium light to light gray with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray, greenish gray; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; unconsolidated to very loosely supported by ash matrix; very fragile and pulverulent; multihued, dominantly grayish white; non to very calcareous; trace glass shards visible. Tuffaceous Claystone/ Tuffaceous Siltstone (8330' - 8400') = medium light to light gray to light brownish gray with light olive gray and light yellowish gray secondary hues; very soft and fragile to firm; irregular shaped with pdc bit action shaped cuttings common; silty to clayey texture; dull, earthy to slightly waxy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Coal (8400' - 8420') = black to grayish black with brownish black hues, and dark brown yellowish hues colors; stiff to dense with occasional brittle tenacity; hackly to splintery fracture; bladed edges to wedgelike cutting habits; polished luster; smooth to abrasive texture; thin to lenticular bedding structure; gas bubbles on surface of coal; weak HCL reaction in bulk sample. Tuffaceous Sandstone (8460' - 8530') = white to milky white with light gray hues, dark medium gray hues, medium gray hues, slight pale yellowish orange hues, very pale orange hues, clear to translucent minerals colors; quartz with lithic and calcareous minerals framework; very fine to fine grains size; well to very well sorting; subangular to subrounded angularity; moderate to low sphericity; consolidated sands with friable to easily friable hardness; tuff matrix grain support; thick to laminated banded lithics bedding structure; moderate to strong HCL reaction in bulk sample. Tuffaceous Siltstone/ Tuffaceous Claystone (8530' - 8640') = medium to medium light gray to grayish brown with light yellowish gray and light olive gray secondary hues; firm to soft and fragile; irregular, wedgelike with pdc bit action shaped cuttings common; silty to clayey to slightly gritty texture; dull to earthy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Sandstone/ Sand (8640' - 8700') = light gray to very light gray with salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, black and greenish gray; very fine lower to fine upper; angular to subangular; well sorted; well consolidated with calcareous cement; sandstone fragments are blocky; hard to very hard; trace black micro-thin carbonaceous laminations and inclusions in sandstone. Tuffaceous Claystone/ Tuffaceous Siltstone (8700' - 8770') = medium gray to grayish brown with light yellowish gray and light gray secondary hues; soft to very firm to hard; irregular to wedgelike and pdc bit action; silty to clayey texture; dull to earthy to waxy luster; poor adhesiveness; fair to good cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Tuffaceous Sandstone/ Sand (8770' - 8820') = very light gray to light grayish white with mottled appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark lithics; very fine to medium lower, dominantly fine; angular to subangular; well sorted; sandstone is very fragile to pulverulent; crunchy to crumbly; glass shards visible; non to very calcareous; salt and pepper sandstone; fine; hard; non calcareous to very calcareous. Coal/ Carbonaceous Shale (8820' - 8890') = black with brownish black and grayish black secondary hues; hard and brittle to crumbly; platy to flaky; blocky to planar fracture with trace conchoidal and birdeye present; vitreous to trace earthy luster; smooth to trace silty texture; bituminous; coal occasionally grades to carbonaceous shale; none to very weak out gassing observed. NFU 42-35 15 Sand/ Tuffaceous Sandstone (8890' - 8960') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, greenish gray and black; very fine lower to medium lower, dominantly fine lower; angular to subangular; moderately well sorted; loosely consolidated in grayish white ash matrix; very fragile and pulverulent; crunchy to crumbly; non to very calcareous; abundant sandstone fragments; light gray with salt and pepper appearance; fine grain; hard; non calcareous cement to very calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (8530' - 8640') = medium to medium light gray to grayish brown with light yellowish gray and dark brown secondary hues; firm to hard to soft and fragile; irregular, wedgelike with pdc bit action shaped cuttings common; silty to clayey to slightly gritty texture; dull to earthy to slightly waxy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations. Coal (8640' - 9080') = black with brownish black secondary hues; brittle to crumbly; blocky to platy and flaky; planar fracture dominant with trace conchoidal and birdeye; vitreous luster; smooth to slightly silty texture; bituminous; occasionally grades to an earthy carbonaceous shale; moderate to strong, prolonged out gassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (9080' - 9150') = medium light to light gray with light brownish gray and light olive gray secondary hues; very soft and sticky to moderately hard and brittle; shapeless, globular to irregular and pdc bit action shaped cuttings; silty to clayey texture; dull, earthy to slightly waxy luster; slight to moderately soluble and expansive; poor to fair adhesiveness; fair to good cohesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; light gray siltstone grades between sandy siltstone/silty sandstone. Sand/ Tuffaceous Sandstone (9150' - 9200') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, greenish gray and black; very fine lower to medium lower, dominantly fine lower; angular to subangular; moderately well sorted; loosely consolidated in grayish white ash matrix; very fragile and pulverulent; crunchy to crumbly; non to very calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (9200' - 9270') = medium to medium light gray with light grayish brown secondary hues; firm to soft and fragile; irregular, wedgelike with pdc bit action shaped cuttings common; silty to clayey to slightly gritty texture; dull to earthy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; light gray siltstone commonly grades between sandy siltstone and silty sandstone. Coal (9290' -9300') = black to slight brownish black with grayish black hues, and dark yellowish brown hues colors; tough to dense tenacity; hackly to splintery fractures; elongated with bladed edges and platy cutting habits; polished with occasional resinous luster; smooth to abrasive texture; thin to lenticular bedding structure; moderate HCL reaction in bulk sample. Tuffaceous Sandstone (9335' - 9395') = milky white to light medium gray with grayish black hues, pale yellowish orange hues, light brown hues, clear to translucent mineral colors; quartz dominant with calcareous minerals and lithic interbedded framework; very fine to fine grain size; very well to well sorting; subangular to angular angularity; low to moderate sphericity; consolidated sands with easily friable to friable hardness; tuff matrix grain support; thin banded bedding structure; moderate HCL reaction in bulk sample. Tuffaceous Siltstone (9410' - 9470') = dark medium gray to dark brownish gray with occasional brownish black laminated banded interbedded, and light medium gray hues colors; stiff to brittle tenacity; slight hackly to earthy fracture; tabular to wedgelike cutting habits; dull to earthy luster; silty to matte and sucrosic texture; massive to thick with contorted banded of lithic interbedded bedding structure; moderate to strong HCL reaction bulk sample. NFU 42-35 16 Sand/ Tuffaceous Sandstone (9470' - 9580') = light to very light gray, individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, black, orange and light translucent green; very fine lower to trace very coarse upper with fragments to 5mm, dominantly fine lower; angular to subangular; well sorted overall; unconsolidated with trace white ashy supported grains; very fragile; fine to medium grain; moderate to very calcareous; trace thin/ lithic coals. Sand/ Tuffaceous Sandstone (9580' - 9650') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace medium to dark gray, greenish gray and black; very fine lower to trace very coarse upper, dominantly fine lower; angular to subangular; well sorted in lower range; disaggregated with trace to common ash supported grains; grayish white; fragile to pulverulent; fine grain; non to very calcareous. Tuffaceous Sandstone/ Sand (9650' - 9710') = very light gray to light grayish white with mottled appearance, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark lithics; very fine lower to very coarse upper, dominantly fine; angular to subangular; well sorted in fine range; disaggregated with ash acting as supporting matrix; very fragile to pulverulent; crunchy to crumbly; trace visible glass shards; non to very calcareous. Coal (9710' - 9780') = black with brownish black secondary hues; brittle to crumbly, very hard at times; platy to flaky, occasionally splintery; planar fracture dominant with trace conchoidal and birdeye; vitreous luster; smooth to slightly silty texture; bituminous with occasional grading to an earthy carbonaceous shale; firm to moderately hard; irregular shaped; silty texture; earthy luster; no to weak out gassing bubbles. Tuffaceous Sandstone/ Sand (9780' - 9840') = very light gray to light grayish white with very light yellowish gray, very light brownish gray and very light greenish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, trace dark lithics; very fine lower to medium lower, dominantly fine lower; angular to subangular; well sorted; disaggregated to very loosely consolidated with ashy matrix; very fragile to pulverulent; crunchy to crumbly; non to very calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (9840' - 9900') = medium to medium light gray with light grayish brown secondary hues; firm to soft and fragile; irregular, wedgelike with pdc bit action shaped cuttings common; silty to clayey to slightly gritty texture; dull to earthy luster; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; light gray siltstone commonly grades between sandy siltstone and silty sandstone. Coal (9900' - 9968') = black with brownish black secondary hues; brittle to crumbly, very hard at times; platy to flaky, occasionally splintery; planar fracture dominant with trace conchoidal and birdeye; vitreous luster; smooth to slightly silty texture; bituminous with occasional grading to an earthy carbonaceous shale; firm to moderately hard; irregular shaped; silty texture; earthy luster; no to weak out gassing bubbles. NFU 42-35 17 3.3 Sampling Program SAMPLE MANIFEST: Cook Inlet Energy NFU 42-35: Washed and Dried Samples TOTAL: 10 Vial Cases 2 Sets of 5 Vial Cases each Operator: Cook Inlet Energy Well Name: North Fork Unit #42-35 Field: North Fork Field County: Kenai Borough State: Alaska Company Representatives: Al Lunda, Rod Maniaci, Stephen Ratcliff, Monie Sainz Location: 588 FSL 1453 FEL, Sec 26 T4S R14W SM, X = 199958 Y = 2121128 Ground Elevation 657.80’ AMSL Rotary Table Elevation 678.38’ AMSL Classification: Development Gas, Multiple Zone API #: 50 – 231 – 20046 – 00 – 00 Permit #: 214 – 170 Activity Code: AFE # 146005 Rig Name / Type: Miller #37 / Land / Telescopic Double Total Depth 9968’ Total Depth Formation: Tyonek Total Depth Date: January 17, 2015 CANRIG Logging Geologists: Ralph Winkelman, Britten Adams CANRIG Sample Catchers: Dickey Hudgins, Tyler Harris Set Type and Purpose Interval Frequency Distribution A Washed and Dried 2920’ – 9968’ 30’ Cook Inlet Energy 601 West 5th Street, Suite 310 Anchorage, AK 99501 Attn: Barb Kruk (907) 952 1151 B Washed and Dried 2920’ – 9968’ 30’ AOGCC 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Attn: Howard Okland (907) 793 1235 Vial Case Intervals: 2920’ – 4410’, 4410’ – 5910’, 5910’ – 7410’, 7410’ – 8910, 8910’ – 9968’’TD NFU 42-35 18 4 DRILLING DATA 4.1 Daily Activity Summary 1/7/2015: Finish rigging up to run 9 5/8” casing and safety meeting with Weatherford. Pick up to shoe, float collar, and break circulation to test both shoe and float collar. Shutdown on operation because, ice was plugged in mud-line. Thaw out of mud-line. Circulated through the shoe. Run in hole with 9 5/8” casing to 2881’MD. Rig up circulated head on last joint. Run in hole to tag at 2920’MD. Pick up and circulate (5BBL min at 350PSI). Rig down Weatherford and rig up cementers. Circulate and condition mud. Rigging up for cement returns. Laying down mouse hole. Circulate with condition mud. Rig up cement head. Rig up hard line for Halliburton. Blow down rig cement lines to pits. PJSM with crew. Pressure test lines to 3000PSI. Pumped cement back to surface. Cement returns pumped from cellar to boxes. 297BBLS of cement pumped. 1/8/2015: Flush out stack, flush cellar holes to screw pump, and blow down hoses. Wait on cement and move mud boxes which are full of cement. Break down diverter line. Flush mud pumps. Rig down hoses to drilling nipple and trip tank. Continue to wait on cement. Rig down flow-line exit, trip tank returns valve, and take knife valve off. Clean pits and work on 9 5/8” thread protectors. Replaced lube on #2 mud pump and function tested. Casing set at 2920’MD and rig down cementing head. Cut casing, nipple down riser and diverter. Kill and clean lines. Remove casing head. Make final cut on conductor and casing. Installing well head and welding up BOPE in yard. Dressed mud pumps #1 and #2 with 4 ½” liners. Replaced rubber on mud mixer #2 suction. Took on 250BLLS and 9.4 PPG mud, while waiting on well head to cool down. 1/9/2015: Finish welding on well head and pressure up to 2000PSI. Pressure held at 2000PSI. Nipple up BOP stack. Worked on rigging down elevators, casing slips, and spiders long bale. Rig up short bales hydro-elevators. Nipple up BOPE, work on top-drive, and link tilt float. Clean up work area. Weld on pitcher nipple. Continue nipple up BOPE and hooked up koomey lines. Finish dressing weld on drilling nipple. House-keeping at cellar. Function the test rams. Move up the test joint to attempt shell test. Repair and seal on the test pump. Secure stack and rig up trip tank valve. Shell test good. Testing BOPE annular, rams, and valves. 1/10/2015: Test BOPE lower pipe, test #3-#4 choke manifold, test blinds, work on check valves, and test koomey. Break down test joints and pull test plug. Reset test plug and blow-down choke manifold. Strap drill pipe and pick it up. Finish nipple up soon. Rig up and test casing (3000K for 30 minutes). Replace check valve with new valve. Continue to test BOPE. Change valve in pits. Blow on choke and mud line. Pick up BHA and PJSM. Load the source and test tools. Run in hole with BHA. Pick up 5” drill pipe and single in. Run in hole with 56 joints total to 2504’MD. 1/11/2015: Single in 5” drill pipe to 2822’MD. Start displacement of mud at 170SPM and totaled 214BBLS. Cement tag at 2828’MD. Drill to 2919’MD. Started new hole at 2920’MD. Drilled 20’ft and circulated bottom up. Started FIT test (17.5EMW and held for 15 minutes). Drilled ahead to 2960’MD and circulated bottom up. Started another FIT test and completed at 15.1EMW. Service top-drive and rig. Drill ahead from 2960’- 3669’MD. Circulate and condition hole. Bottom up and pull out of hole from 3669’-3546’MD. 1/12/2015: Pull out of hole from 3546’-3381’MD. Washout from 3381’-2915’MD (shoe). Repair leak on top- drive hydraulics O ring. Fix pipe grabber stopper, service top-drive, fix suction valve in pit #2. Run in hole from 2915’-3668’ MD and continue to drill ahead. Slide from 4240’-4258’MD, 4556’-4572’MD, and 4936’- 4958’MD. Drill to 5122’MD and start wiper trip. 1/13/2015: Pull out of hole from 5122’-3545’MD. Circulate and wipe hole. Service block, carrier, and top- drive. Clean rig floor surface. Run in hole from 3545’-4970’MD. Pull up 48 singles 5” drill pipe. Wash down from 4970’-5122’MD. Drill ahead from 5122’-6568’MD. NFU 42-35 19 1/14/2015: Drill from 6568’-6630’MD. Circulate and condition at 500GPM with 2400PSI. Sweep showed at 1000STK past count. Monitor well static and fill trip tank. Pull out of hole from 6630’-5055’MD and monitor well again. Rig up to pick up 50 singles. Run in hole with singles from 5055’-6567’MD. Fill pipe with mud. Malfunction with #3 mud pump. Pump #3 fixed. Wash from 6567’-6630’MD. Drill ahead from 6690’- 7382’MD. 1/15/2015: Troubleshoot issue with #2 shaker. Continue to drill and reduce drilling rate due to sliding per Baker rep. During drilling, pull up and move up stands in mouse hole. Continue to drill until 8586’MD. Start to pull out of hole. 1/16/2015: Pull out of hole from 8398’-6500’MD. Perform a BOP drill and monitor well. Service top-drive, block, and carrier on top-drive. Run in hole with singles from 6567’-7657’MD. Fix O-ring on top drive. Continue to run in from 7657’- 8586’MD. Drill and slider per Baker representative. Drill to 9492’MD and notice pump pressure drop. Check surface and trouble shoot with MWD tool. Start to pull out of hole. Problem with top drive function. 1/17/2015: Pull out of from to find washout. At 7699’ MD, washout was on top of stand #110. Lay down joint and service rig. Run in hole to 9466’MD and wash/ream from 9466’-9522’MD. Continue to drill and slide per Baker. Drill to 9968’MD (TD). Circulate and clean hole with 2 bottom ups. Continue to pull from 9968’-7450’MD. 1/18/2015: Pull out the hole from 7450’-6410’MD. Monitor well (OK). Continue to pull out to 5798’MD. Blow down top-drive. Pull out to 3231’MD and monitor well (OK). Replace hydraulic valve on top-drive. Prepare test for BOPs. Run up test plug to drill string. Test BOPs annular, rams, and valves. Finish BOP test (good). Monitor well. Hang block and slip/cut drilling line. Run in hole from 2914’-5373’MD. 1/19/2015: Continue to run in hole from 5373’-9968’MD with washing and cleaning. Monitor well (OK). Pull out of hole from 9968’-2011’MD. Lay down agitator and shock sub. Continue to pull out from 2011’-752’MD. Pull up singles joint 5” drill pipe. Lay down jars and heavy weight. Safety meeting and remove radioactive source. Lay down sub and #1 DC. Download MWD data off tool. 1/20/2015: Finish downloading data from MWD tool. Lay down BHA. Monitor well and clean rig floor. Strap new tally and BHA. Have safety meeting with Halliburton’s e-line crew. Halliburton ran two e-lines (TripleCombo and Side-Core-Gun). Halliburton log are good. Halliburton break rig down tool. Monitor well. Pick up BHA with 8 ¾” bit. Run in hole with 5”drill pipe. 1/21/2015: Run in hole from 1287’-9593’MD. Can’t rotate top-drive in hole. Attempt to work free and not freeing. Pull back stand to free pipe. Jars still not freeing. Pump 30BBLs of lube pills. Work pipe and it freed up. Continue to wash and clean to 9659’MD. Rig up head pin to safety valve on stump circulated. Replaced T.D. grabber die’s and tighten bolts. Install safety wire on top-drive grabber. Wash and rotate and tag bottom at 9973’MD. 1/22/2015: Back ream from 9973’-9700’MD. Attempt to pull out the hole at 9700’MD on hooks (no good). Continue to back ream from 9700’-9280’MD. Attempt to pull out of hole with hooks (go good). Continue to ream to 8712’MD. Pull out of hole from 8712’-8460’MD with no pumps or rotation (good). Continue to pull out to 5592’MD. Rig up to lay down singles from 5592’-1160’MD. Lay down BHA. 1/23/2015: Continue to lay down BHA. Install casing tool and pick up 7” casing. Replace rams and pressure tests them. Have safety meeting with crew, and run 7” casing. Circulated bottom at 2930’MD and continue to run in hole. 1/24/2015: Continue to run in the hole with 7” casing. At 8920” MD, casing stop running in hole. Driller work casing for several hour (no good). Pull 7” casing out of hole to 4796”Md and lay casing down. NFU 42-35 20 1/25/2015: Continue to pull out the hole with 7” casing. Fill pipe every 5 stands. Joint #106 is bad. Continue to pull out from 2446’-95’MD. Rig down Weatherford tools. Change out upper pipe ram. Rig up to test BOP. Move up test joint. Test BOP stack. 1/26/2015: Continue to test BOP. Test gas alarms (good). Rig-down test equipment tools. Pull up BHA and prepare rig floor for running in hole. Run in hole with HWDP and rack drill pipe. RIH to 2942’MD. Slip and cut drill line and adjust torque tube. 1/27/2015: Run in the hole to 9968’MD to clean and condition hole. Pull out of hole to 7152’MD and trip in hole to 8970’MD. Ream hole from 8970’-9117’MD. Continue back in hole to 9497’-9968’MD and ream. Move mud weight up to 9.7LB/GAL. 1/28/2015: Circulate and condition mud. Wipe hole to 8500'MD. Run in hole to 9967'MD. Circulate bottoms up to clean hole. Pull out of hole to surface. Lay down BHA and change pipe rams. Testing BOP stack at time of report. 1/29/2015: Continue BOPE test. Lay down test joint and rig up casing equipment. Run in casing to 8000’MD and circulate two bottoms up. Continue casing to 9955’MD. Rig up cementers. 1/30/2015: Canrig Mudloggers - Released NFU 42-35 21 4.2 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 20.8 20.8 175.00 0.59 0.89 175.00 0.79 0.01 -0.77 0.38 233.00 0.81 352.61 232.99 1.50 -0.04 -1.46 0.42 295.00 0.99 354.40 294.99 2.47 -0.14 -2.43 0.29 358.00 0.94 345.84 357.98 3.51 -0.32 -3.48 0.24 419.00 1.00 356.47 418.97 4.53 -0.48 -4.51 0.31 484.00 0.99 354.45 483.96 5.65 -0.57 -5.62 0.06 545.00 1.06 351.27 544.95 6.73 -0.70 -6.70 0.15 608.00 0.56 6.32 607.94 7.62 -0.76 -7.57 0.86 671.00 0.43 60.23 670.94 8.04 -0.52 -7.92 0.74 733.00 0.39 50.43 732.94 8.29 -0.16 -8.08 0.13 798.00 0.45 35.43 797.94 8.64 0.16 -8.34 0.19 861.00 0.31 51.60 860.93 8.94 0.44 -8.57 0.28 923.00 0.10 118.94 922.93 9.02 0.62 -8.60 0.46 988.00 1.05 159.48 987.93 8.44 0.88 -7.97 1.50 1050.00 2.05 166.76 1049.91 6.83 1.33 -6.29 1.64 1114.00 3.20 164.33 1113.84 3.99 2.07 -3.36 1.80 1177.00 4.32 161.26 1176.70 0.05 3.31 0.76 1.81 1241.00 5.22 162.10 1240.48 -5.00 4.98 6.07 1.41 1304.00 6.45 161.99 1303.15 -11.09 6.96 12.46 1.95 1367.00 7.81 166.36 1365.66 -18.62 9.06 20.27 2.32 1429.00 9.14 169.33 1426.99 -27.55 10.97 29.40 2.26 1492.00 10.27 166.69 1489.08 -37.94 13.18 40.01 1.93 1553.00 11.13 162.63 1549.02 -48.85 16.19 51.32 1.87 1617.00 12.45 162.60 1611.67 -61.33 20.10 64.38 2.06 1679.00 13.85 163.13 1672.04 -74.81 24.25 78.46 2.27 1742.00 14.86 164.55 1733.08 -89.81 28.59 94.07 1.70 1805.00 16.16 166.82 1793.78 -106.13 32.75 110.91 2.28 1867.00 17.35 166.93 1853.15 -123.54 36.80 128.79 1.92 1930.00 18.55 166.51 1913.08 -142.43 41.27 148.20 1.92 1993.00 19.78 165.19 1972.59 -162.49 46.33 168.88 2.07 2056.00 20.92 166.02 2031.66 -183.71 51.77 190.79 1.87 2121.00 22.01 168.31 2092.15 -206.90 57.04 214.56 2.11 2184.00 23.05 167.85 2150.34 -230.51 62.03 238.68 1.67 2248.00 24.41 167.09 2208.93 -255.65 67.62 264.43 2.18 2311.00 25.77 167.20 2265.98 -281.70 73.56 291.13 2.16 2373.00 27.05 168.17 2321.51 -308.64 79.44 318.70 2.18 NFU 42-35 22 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 2437.00 28.45 167.76 2378.15 -337.78 85.66 348.47 2.21 2500.00 29.95 167.85 2433.14 -367.82 92.15 379.19 2.38 2562.00 30.50 168.94 2486.71 -398.40 98.42 410.37 1.25 2626.00 31.53 168.86 2541.56 -430.76 104.77 443.30 1.61 2690.00 32.54 167.08 2595.82 -463.95 111.86 477.22 2.16 2754.00 33.35 167.21 2649.52 -497.89 119.60 512.02 1.27 2816.00 34.52 166.24 2700.96 -531.57 127.55 546.62 2.08 2863.00 35.10 166.70 2739.55 -557.65 133.83 573.45 1.35 2923.90 34.83 166.04 2789.46 -591.57 142.05 608.35 0.76 2986.54 35.09 166.49 2840.79 -626.43 150.57 644.24 0.58 3049.22 36.06 166.05 2891.77 -661.86 159.22 680.71 1.60 3110.45 36.85 166.08 2941.02 -697.17 167.98 717.09 1.29 3174.34 37.33 166.12 2991.98 -734.57 177.24 755.62 0.75 3237.20 37.72 165.80 3041.84 -771.71 186.53 793.91 0.69 3300.51 37.99 166.64 3091.83 -809.45 195.78 832.75 0.91 3363.23 38.16 166.86 3141.20 -847.10 204.65 871.43 0.34 3427.00 38.01 166.08 3191.39 -885.34 213.85 910.76 0.79 3489.00 38.01 165.67 3240.24 -922.36 223.17 949.12 0.40 3552.25 37.22 165.16 3290.35 -959.72 232.89 987.55 1.34 3614.92 36.17 165.43 3340.59 -995.95 242.39 1024.99 1.69 3679.10 36.34 165.80 3392.35 -1032.71 251.82 1062.95 0.43 3742.21 35.69 165.06 3443.40 -1068.63 261.16 1100.05 1.23 3804.91 35.72 164.54 3494.31 -1103.94 270.75 1136.64 0.48 3867.35 35.47 164.61 3545.08 -1138.98 280.42 1172.97 0.40 3930.72 35.64 164.02 3596.64 -1174.45 290.38 1209.81 0.60 3993.67 35.34 163.96 3647.89 -1209.58 300.46 1246.33 0.47 4056.65 35.15 164.48 3699.33 -1244.55 310.34 1282.66 0.56 4120.18 34.87 164.39 3751.36 -1279.67 320.12 1319.10 0.44 4184.31 34.76 164.20 3804.01 -1314.91 330.03 1355.70 0.24 4246.32 35.05 164.10 3854.87 -1349.05 339.72 1391.17 0.47 4309.96 34.58 163.99 3907.12 -1383.98 349.71 1427.48 0.74 4373.66 34.36 163.82 3959.63 -1418.62 359.71 1463.51 0.37 4437.19 34.66 164.11 4011.98 -1453.21 369.65 1499.49 0.53 4499.38 34.76 163.99 4063.11 -1487.26 379.38 1534.88 0.19 4562.54 34.88 164.40 4114.96 -1521.96 389.20 1570.93 0.41 4625.30 34.95 165.69 4166.42 -1556.67 398.47 1606.85 1.18 4688.89 35.31 165.49 4218.43 -1592.11 407.58 1643.44 0.59 4755.00 35.57 164.76 4272.29 -1629.15 417.42 1681.77 0.75 4816.72 35.84 164.83 4322.41 -1663.91 426.87 1717.78 0.44 4879.29 36.26 165.10 4373.00 -1699.48 436.42 1754.60 0.71 NFU 42-35 23 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 4942.32 36.08 165.57 4423.88 -1735.46 445.84 1791.80 0.52 5002.29 35.74 166.46 4472.45 -1769.59 454.34 1828.73 1.03 5069.93 35.82 166.42 4527.33 -1808.04 463.61 1866.52 0.12 5123.77 35.42 166.50 4571.09 -1838.52 470.95 1897.87 0.74 5186.24 34.50 167.85 4622.29 -1873.42 478.90 1933.66 1.92 5249.90 34.67 166.56 4674.70 -1908.66 486.90 1969.78 1.18 5313.15 34.68 167.02 4726.72 -1943.69 495.13 2005.76 0.41 5375.68 34.69 167.07 4778.14 -1978.37 503.10 2041.34 0.04 5438.68 34.96 166.34 4829.85 -2013.38 511.38 2077.31 0.78 5502.06 35.10 166.24 4881.75 -2048.72 520.00 2113.69 0.23 5564.99 35.03 166.51 4933.26 -2083.86 528.52 2149.84 0.27 5628.04 35.20 166.41 4984.83 -2119.12 537.01 2186.11 0.28 5691.82 34.75 165.56 5037.10 -2154.59 545.86 2222.67 1.03 5755.48 34.59 165.45 5089.45 -2189.65 554.92 2258.88 0.26 5817.90 34.92 164.99 5140.74 -2224.06 564.00 2294.46 0.67 5881.97 35.05 165.05 5193.23 -2259.54 573.50 2331.19 0.20 5945.52 34.38 164.99 5245.47 -2294.50 582.85 2367.38 1.05 6007.91 33.83 165.92 5297.13 -2328.36 591.64 2402.36 1.21 6070.90 34.11 165.65 5349.37 -2362.48 600.28 2437.56 0.50 6133.57 34.35 165.97 5401.18 -2396.66 608.92 2472.81 0.47 6197.07 34.34 165.67 5453.61 -2431.39 617.70 2508.63 0.26 6260.95 34.54 165.89 5506.29 -2466.41 626.57 2544.76 0.36 6324.87 34.88 165.52 5558.84 -2501.68 635.56 2581.16 0.62 6387.24 35.13 165.51 5609.93 -2536.33 644.51 2616.93 0.40 6450.96 34.36 165.25 5662.28 -2571.46 653.68 2653.25 1.23 6512.78 33.76 165.06 5713.50 -2604.93 662.55 2687.87 0.98 6576.91 33.67 164.78 5766.84 -2639.30 671.81 2723.46 0.28 6635.38 33.68 164.43 5815.50 -2670.56 680.41 2755.87 0.33 6699.04 31.40 165.38 5869.16 -2703.61 689.34 2790.11 3.67 6761.88 30.00 164.70 5923.20 -2734.61 697.62 2822.18 2.29 6825.45 29.02 164.44 5978.52 -2764.79 705.95 2853.49 1.55 6888.42 27.36 165.67 6034.02 -2793.53 713.63 2883.23 2.79 6951.71 25.95 166.56 6090.58 -2821.09 720.44 2911.62 2.31 7013.56 24.99 166.11 6146.42 -2846.94 726.73 2938.22 1.58 7077.22 23.69 166.55 6204.42 -2872.43 732.93 2964.45 2.06 7140.17 22.93 167.21 6262.23 -2896.69 738.59 2989.36 1.27 7203.86 22.57 166.75 6320.97 -2920.68 744.13 3013.98 0.63 7267.82 21.90 167.64 6380.17 -2944.28 749.50 3038.18 1.17 7330.64 21.04 168.52 6438.63 -2966.78 754.25 3061.15 1.46 7393.50 19.97 167.04 6497.51 -2988.30 758.91 3083.16 1.89 7455.72 18.95 166.46 6556.17 -3008.47 763.65 3103.88 1.66 7520.52 17.95 168.25 6617.64 -3028.48 768.15 3124.38 1.77 NFU 42-35 24 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 7582.48 17.13 168.91 6676.72 -3046.78 771.85 3143.04 1.36 7645.76 16.73 169.58 6737.26 -3064.89 775.29 3161.43 0.70 7708.23 15.69 168.64 6797.24 -3082.01 778.58 3178.84 1.71 7771.44 14.80 168.21 6858.23 -3098.29 781.91 3195.44 1.41 7835.51 13.26 168.63 6920.38 -3113.51 785.03 3210.96 2.40 7899.52 11.67 168.94 6982.88 -3127.06 787.72 3224.76 2.48 7963.19 10.39 169.48 7045.38 -3139.03 790.01 3236.92 2.01 8026.23 8.90 167.96 7107.52 -3149.38 792.06 3247.47 2.39 8089.34 7.62 164.41 7169.98 -3158.19 794.21 3256.53 2.18 8151.73 6.30 159.97 7231.91 -3165.39 796.49 3264.07 2.28 8215.74 5.18 152.66 7295.60 -3171.26 799.02 3270.38 2.08 8278.36 4.64 147.32 7357.99 -3175.90 801.69 3275.53 1.12 8340.69 3.39 150.98 7420.16 -3179.63 803.94 3279.70 2.04 8403.58 2.34 170.30 7482.97 -3182.53 805.06 3282.78 2.24 8467.11 1.40 211.47 7546.47 -3184.47 804.87 3284.61 2.49 8523.65 1.11 223.74 7603.00 -3185.45 804.13 3285.39 0.69 8586.23 0.40 239.71 7665.57 -3186.00 803.53 3285.77 1.17 8648.90 0.55 356.16 7728.24 -3185.81 803.32 3285.54 1.29 8712.13 0.96 353.61 7791.47 -3184.98 803.24 3284.71 0.65 8775.33 1.18 346.50 7854.65 -3183.82 803.03 3283.54 0.40 8840.12 1.76 355.87 7919.42 -3182.18 802.80 3281.89 0.96 8903.90 1.51 7.44 7983.18 -3180.37 802.84 3280.14 0.64 8966.26 1.49 20.51 8045.52 -3178.80 803.23 3278.71 0.54 9029.49 1.86 12.03 8108.72 -3177.02 803.73 3277.12 0.70 9092.77 1.72 11.76 8171.97 -3175.09 804.14 3275.34 0.22 9155.82 1.47 8.69 8234.99 -3173.36 804.45 3273.74 0.41 9219.01 1.79 5.87 8298.16 -3171.58 804.68 3272.07 0.52 9281.33 2.07 4.20 8360.44 -3169.49 804.86 3270.09 0.45 9345.19 2.83 357.72 8424.24 -3166.76 804.88 3267.45 1.26 9408.89 3.54 357.39 8487.85 -3163.23 804.73 3263.98 1.11 9471.76 3.37 0.15 8550.60 -3159.44 804.64 3260.29 0.37 9533.17 2.31 7.18 8611.94 -3156.41 804.80 3257.39 1.81 9598.09 2.21 10.68 8676.80 -3153.88 805.20 3255.03 0.26 9661.49 2.60 6.49 8740.15 -3151.25 805.59 3252.58 0.67 9725.27 3.04 3.20 8803.85 -3148.12 805.85 3249.61 0.73 9787.44 3.35 0.97 8865.92 -3144.66 805.97 3246.28 0.53 9850.78 3.65 359.98 8929.15 -3140.79 806.00 3242.54 0.48 9912.97 4.11 356.44 8991.198 -3136.59 805.86 3238.43 0.83 9968.00** 4.11 356.44 9046.04 **Projected NF U 4 2 - 3 5 25 4. 3 B i t R e c o r d BI T NO . SI Z E “ TY P E S/ N JE T S / TF A IN OU T FT HR S AV E RO P Ft / H R CONDITION RR 3 1 2 . 2 5 ” HC C MX L 1 52 3 1 9 7 1 . 9 9 7 1 3 8 ’ 2 5 7 3 ’ 2 4 3 5 ’ 4 3 6 2 . 9 8 - 3 - C l - N - F - 1 6 / 1 6 ” - P N - T Q #2 1 2 . 2 5 ” NO V M4 6 8 6 C P B1 6 2 1 9 6 . 6 6 9 2 5 7 3 ’ 2 9 2 0 ’ 3 4 7 ’ 9 . 5 8 34 . 3 1 - 1 - N O - A - E - I - N O - T D 3 8 . 7 5 ” NO V SK H 5 1 9 M A2 0 6 7 1 2 5 X 1 3 , 2 X 1 2 2 9 2 0 9 9 6 8 ’ 7 0 4 8 ’ 6 3 . 42 1 1 1 . 1 1 - 2 - W T - H - X - I - C T - T D 4 9 . 7 5 ” NO V TC H 1 1 C P B1 9 6 4 6 9 3 X 2 0 , 1 2 9 9 6 8 9 9 6 8 0 0 0 C L E A N O U T R U N NF U 4 2 - 3 5 26 4. 4 M u d R e c o r d Co n t r a c t o r : M I S w a c o M u d T y p e s : S p u d M u d 13 8 ’ – 2 9 2 0 ’ ; K l a - S h i e l d 29 2 0 ’ – 9 9 6 8 ’ Da t e De p t h MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l (% ) O/ W Ra t i o Sd (% ) MB T pH Cl (ml/l) Ca (ml/l) 1/ 8 / 2 0 1 5 2 9 2 0 9 . 4 6 2 1 8 2 2 4 / 5 / 6 4 . 7 1 6 2 / 9 2 0 6 9 . 5 1 9 0 0 0 4 0 1/ 9 / 2 0 1 5 2 9 2 0 9 . 3 7 0 1 7 2 4 4 / 5 / 6 4 . 6 1 5 2 / 9 3 0 6 9 . 8 1 8 0 0 0 4 0 1/ 1 0 / 2 0 1 5 2 9 2 0 9 . 2 5 2 1 0 1 7 3 / 4 / 5 4 . 4 1 5 2 / 9 3 0 6 1 0 1 6 0 0 0 4 0 1/ 1 1 / 2 0 1 5 3 5 4 1 9 . 3 7 2 2 1 2 6 5 / 7 / 8 4 1 6 2 / 9 2 0 5 9 . 8 2 0 0 0 0 4 0 1/ 1 2 / 2 0 1 5 4 8 7 1 9 . 4 6 1 1 8 2 3 6 / 8 / 1 0 3 . 7 1 6 1 / 9 3 0 7 9 . 7 2 2 0 0 0 4 0 1/ 1 3 / 2 0 1 5 6 2 5 2 9 . 5 6 7 2 4 2 3 7 / 8 / 1 0 4 . 2 1 6 0 / 9 4 0 . 2 5 7 9 . 7 2 8 0 0 0 4 0 1/ 1 4 / 2 0 1 5 7 2 1 4 9 . 6 6 2 2 0 2 6 6 / 1 0 / 1 2 3 . 9 1 7 0 / 9 3 0 . 2 5 7 9 . 4 2 8 0 0 0 2 0 0 1/ 1 5 / 2 0 1 5 8 5 2 3 9 . 4 6 5 2 3 2 7 7 / 9 / 1 1 4 . 3 1 7 0 / 9 3 0 . 2 5 7 . 5 9 . 7 2 7 0 0 0 1 4 0 1/ 1 6 / 2 0 1 5 9 3 6 8 9 . 4 6 0 2 0 2 6 5 / 7 / 1 0 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 5 9 . 7 2 7 5 0 0 1 4 0 1/ 1 7 / 2 0 1 5 9 9 6 8 9 . 4 5 9 2 0 2 6 6 / 8 / 1 0 4 . 1 1 7 0 / 9 3 0 . 2 5 7 1 0 2 8 0 0 0 1 2 0 1/ 1 8 / 2 0 1 5 9 9 6 8 9 . 4 6 0 2 0 2 6 6 / 8 / 1 0 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 7 5 1 0 2 8 0 0 0 1 2 0 1/ 1 9 / 2 0 1 5 9 9 6 8 9 . 4 6 5 2 0 2 6 6 / 8 / 1 0 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 7 5 1 0 2 8 0 0 0 1 2 0 1/ 2 0 / 2 0 1 5 9 9 6 8 9 . 4 7 2 2 0 2 6 6 / 8 / 1 0 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 7 5 1 0 2 8 0 0 0 1 2 0 1/ 2 1 / 2 0 1 5 9 9 6 8 9 . 3 5 8 1 7 2 2 5 / 8 / 9 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 5 1 0 2 6 5 0 0 1 6 0 1/ 2 2 / 2 0 1 5 9 9 6 8 9 . 3 6 3 1 7 2 2 5 / 8 / 9 4 1 7 0 / 9 3 0 . 2 5 7 . 5 1 0 2 7 0 0 0 1 6 0 1/ 2 3 / 2 0 1 5 9 9 6 8 9 . 3 8 9 1 7 2 1 5 / 8 / 9 4 1 7 0 / 9 3 0 . 2 5 7 . 5 1 0 2 7 0 0 0 1 6 0 1/ 2 4 / 2 0 1 5 9 9 6 8 9 . 3 7 7 1 9 2 2 5 / 7 / 9 4 . 1 1 7 0 / 9 3 0 . 2 5 7 . 5 9 . 8 2 7 0 0 0 1 6 0 1/ 2 5 / 2 0 1 5 9 9 6 8 9 . 4 7 0 1 6 2 1 5 / 7 / 9 4 . 3 1 7 0 / 9 3 0 . 2 5 7 . 5 9 . 6 2 5 0 0 0 1 6 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t VI S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y YP = Y i e l d P o i n t Ge l s = Gel Strength n/ r = n o t r e c o r d e d FL = W a t e r o r F i l t r a t e L o s s FC = F i l t e r C a k e So l = S o l i d s O/ W = O i l t o W a t e r r a t i o Sd = S a n d c o n t e n t MB T = M e t h y l e n e B l u e pH = A c i d i t y / B a s i c i t y Al , P m = A l k a l i n i t y , M u d Cl = C h l o r i d e s Ca = H a r d n e s s C a l c i u m NF U 4 2 - 3 5 27 4. 5 D r i l l i n g P r o g r e s s C h a r t DA Y S V E R S U S D E P T H 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 50 0 0 55 0 0 60 0 0 65 0 0 70 0 0 75 0 0 80 0 0 85 0 0 90 0 0 95 0 0 10 0 0 0 10 5 0 0 11 0 0 0 1 / 8 / 2 0 1 5 1 / 9 / 2 0 1 5 1 / 1 0 / 2 0 1 5 1 / 1 1 / 2 0 1 5 1 / 1 2 / 2 0 1 5 1 / 1 3 / 2 0 1 5 1 / 1 4 / 2 0 1 5 1 / 1 5 / 2 0 1 5 1 / 1 6 / 2 0 1 5 1 / 1 7 / 2 0 1 5 1 / 1 8 / 2 0 1 5 1 / 1 9 / 2 0 1 5 1 / 2 0 / 2 0 1 5 1 / 2 1 / 2 0 1 5 1 / 2 2 / 2 0 1 5 1 / 2 3 / 2 0 1 5 1 / 2 4 / 2 0 1 5 1 / 2 5 / 2 0 1 5 1 / 2 6 / 2 0 1 5 1 / 2 7 / 2 0 1 5 1/28/2015 1/29/2015 1/30/2015 1/31/2015 D E P T H ( F T ) 8 3/4" Hole N o r t h F o r k U n i t 4 2 - 3 5 NFU 42-35 28 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph)193 257 187 473 WOB 11 10 20 22 RPM 32 32 31 40 Mud Weight 9.5 9.5 9.5 9.5 Chloride 28,000 28,000 28,000 28,000 Total Gas 49 139 45 178 C1 (ppm)9,809 26,591 8,950 34,147 C2 (ppm)1 24 1 34 C3 (ppm)0 20 1 34 C4 (ppm)- - - C5 (ppm)- - - Lithology Cuttings Analysis Odor Fluorescencenone Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intensity Color Color Show Rating Free Oil in Mud Comments Report by: SAND/ TUFFACEOUS SANDSTONE: MEDIUM LIGHT TO LIGHT GRAY WITH INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, TRACE LIGHT TO MEDIUM GRAY AND DARK GRAY; VERY FINE LOWER TO MEDIUM LOWER, DOMINANTLY FINE; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; POOR VISIBLE POROSITY AND PERMEABILITY; UNCONSOLIDATED TO VERY LOOSELY CONSOLIDATED IN ASHY MATRIX; VERY FRAGILE AND PULVERULENT; MULTIHUED, DOMINANTLY GRAYISH WHITE; NON CALCAREOUS; TRACE LIGHT GRAY SANDSTONE FRAGMENTS; FARD; FINE GRAIN; VERY CALCAREOUS CEMENT. Kenai Pennensula Borough Alaska USA Cook Inlet Energy 50-231-20046-00-00NFU 42-35 North Fork Miller 37 January 13, 2015 18:19 Ralph Winkelman Gas Show 5975' MD 6002 MD 5269.62' TVD 5292.12' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph)189 211 242 473 WOB 16 19 18 22 RPM 31 33 33 40 Mud Weight 9.5 9.5 9.5 9.5 Chloride 28,000 28,000 28,000 28,000 Total Gas 65 113 148 134 C1 (ppm)13,409 23,315 30,555 27,858 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - C5 (ppm)- - - Lithology Cuttings Analysis Odor Fluorescencenone Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intensity Color Color Show Rating Free Oil in Mud Comments Report by: 6390' MD 6403' MD 5612.37' TVD 5623.01' TVD Britten Adams Gas Show Kenai Pennensula Borough Alaska USA Cook Inlet Energy 50-231-20046-00-00NFU 42-35 North Fork Miller 37 January 13, 2015 20:15 TUFFACEOUS SANDSTONE - TRANSLUCENT TO CLEAR WITH MILKY WHITE MINERALS, BLACK MINERALS, MEDIUM DARK GRAY MINERAL, OCCASIONAL PALE YELLOWISH ORANGE MINERAL AND DARK BROWNISH BLACK BANDS INTERBEDDED WITHIN; QUARTZ DOMINANT FRAMEWORK WITH TUFF; VERY FINE TO FINE GRAIN SIZE; WELL TO VERY WELL SORTING; SUBROUNDED TO SUBANGULAR ANGULAITY; LOW TO MODERATE SPHERICITY; CONSOLIDATED TO FRIABLE HARDNESS; MATRIX GRAIN SUPPORT; THICK TO OCCASIONAL LAMINAE BANDS BEDDING STRUCTURE; WEAK HCL REACRTION IN SAMPLE. Pixler Plot 1 10 100 1000 10000 100000 1000000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph)104 226 173 497 WOB 13 9 15 19 RPM 7 22 29 33 Mud Weight 9.5 9.5 9.5 9.5 Chloride 28,000 28,000 28,000 28,000 Total Gas 80 161 57 218 C1 (ppm)164,443 31,098 10,917 41,786 C2 (ppm)4 40 19 56 C3 (ppm)- - - - C4 (ppm)- - - C5 (ppm)- - - Lithology Cuttings Analysis Odor Fluorescencenone Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intensity Color Color Show Rating Free Oil in Mud Comments Report by: TUFFACEOUS SANDSTONE - MILKY WHITE TO MEDIUM LIGHT GRAY MINERALS, BLACK MINERALS, MEDIUM DARK GRAY MINERAL, TRANSLUCENT TO CLEAR MINERALS HUES COLORS; QUARTZ DOMINANT WITH LITHIC FRAMEWORK; VERY FINE TO FINE GRAIN SIZE; WELL TO VERY WELL SORTING; SUBROUNDED TO SUBANGULAR ANGULAITY; LOW TO VERY LOW SPHERICITY; CONSOLIDATED WITH EASILY FRIABLE TO FRIABLE HARDNESS; TUFF MATRIX GRAIN SUPPORT; THICK BEDDING STRUCTURE; MODERATE TO STRONG HCL REACTION IN BULK SAMPLE. Kenai Pennensula Borough Alaska USA Cook Inlet Energy 50-231-20046-00-00NFU 42-35 North Fork Miller 37 January 13, 2015 22:30 Britten Adams Gas Show 6455' MD 6499' MD 5665.58' TVD 5701.92' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph)91 132 123 129 WOB 21 18 23 RPM 21 38 39 Mud Weight 9.4 9.4 9.4 9.4 Chloride 28,000 28,000 28,000 28,000 Total Gas 28 82 34 129 C1 (ppm)5,526 15,883 6,505 24,761 C2 (ppm)6 30 15 45 C3 (ppm)6 27 12 43 C4 (ppm)- - - C5 (ppm)- - - Lithology Cuttings Analysis Odor Fluorescencenone Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intensity Color Color Show Rating Free Oil in Mud Comments Report by: 7532' MD 7556' MD 6628.41' TVD 6650.30' TVD Britten Adams Gas Show Kenai Pennensula Borough Alaska USA Cook Inlet Energy 50-231-20046-00-00NFU 42-35 North Fork Miller 37 January 15, 2015 05:30 SANDSTONE = MEDIUM DARK GRAY TO LIGHT MEDIUM GRAY WITH CLEAR TO TRANSLUCENT MINERALS, LIGHT OLIVE GRAY HUES, AND LIGHT BROWNISH GRAY HUES COLOR; QUARTZ DOMINANT FRAMEWORK; VERY FINE TO FINE GRAIN SIZE; WELL TO FAIR SORTING; SUBROUNDED TO SUBANGULAR ANGULAITY; LOW TO MODERATE SPHERICITY; CONSOLIDATED SANDS WITH FRIABLE TO FIRM FRIABLE HARDNESS; GRAIN ENLARGEMENT CEMENT; MATRIX AND CEMENT GRAIN SUPPORT; THIN BEDDING STRUCTURE. Pixler Plot 1 10 100 1000 10000 100000 1000000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #5 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph)126 130 142 231 WOB 17 17 14 21 RPM 15 28 91 37 Mud Weight 9.4 9.4 9.4 9.4 Chloride 28,000 28,000 28,000 28,000 Total Gas 49 130 51 392 C1 (ppm)9,890 24,643 9,677 71,630 C2 (ppm)8 48 6 158 C3 (ppm)7 27 3 110 C4 (ppm)- - - C5 (ppm)- - - Lithology Cuttings Analysis Odor Fluorescencenone Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intensity Color Color Show Rating Free Oil in Mud Comments Report by: 8165' MD 8200' MD 7244.82' TVD 7279.61' TVD Britten Adams Gas Show Kenai Pennensula Borough Alaska USA Cook Inlet Energy 50-231-20046-00-00NFU 42-35 North Fork Miller 37 January 15, 2015 15:35 TUFFACEOUS SANDSTONE: VERY LIGHT GRAY TO LIGHT GRAYISH WHITE WITH MOTTLED APPEARANCE, INDIVIDUAL GRAINS DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS, TRACE DARK LITHS; VERY FINE LOWER TO MEDIUM LOWER, DOMINANTLY FINE; ANGULAR TO SUBANGULAR; WELL SORTED; LOOSELY CONSOLIDATED IN ASHY MATRIX; SANDSTONE IS VERY FRAGILE TO PULVERULENT; CRUNCHY TO CRUMBLY; GLASS SHARDS VISIBLE; NON TO VERY CALCAREOUS. SANDSTONE IS INTERBEDDED BETWEEN 2 COAL BEDS; BLACK; HARD AND TRACE OUTGASSING. Pixler Plot 1 10 100 1000 10000 100000 1000000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 NFU 42-35 29 6 DAILY REPORTS Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan. 8, 2015 DEPTH 2920.00000 PRESENT OPERATION Cementing TIME 00:00:00 YESTERDAY 24 HOUR FOOTAGE CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING FLUIDS REPORT DEPTH 2920' MW 9.2 VIS 35 PV 14 YP 14 FL 7.6 Gels 5/7/8 CL- 200 FC 2 SOL 4 SD 0.1 OIL 0/96 MBT 10 pH 8.5 Ca+ 40 Alk 0.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish rigging up to run 9 5/8” casing and safety meeting with Weatherford. Pick up to shoe, float collar, and break circulation to test both shoe and float collar. Shutdown on operation because, ice was plugged in mud-line. Ice was thaw out of mud-line. Circulated through the shoe. Run in hole with 9 5/8” casing to 2881’MD. Rig up circulated head on last joint. Run in hole to tag at 2920’MD. Pick up and circulate (5BBL min at 350PSI). Rig down Weatherford and rig up cementers. Circulate and condition mud. Rigging up for cement returns. Laying down mouse hole. Circulate with condition mud. Rig up cement head. Rig up hard line for Halliburton. Blow down rig cement lines to pits. PJSM with crew. Pressure test lines to 3000PSI. Pumped cement back to surface. Cement returns pumped from cellar to boxes. 297BBLS of cement pumped. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2000.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan. 9, 2015 DEPTH 2920.00000 PRESENT OPERATION R/U BOP. TIME 00:00:00 YESTERDAY 2920.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.4 VIS 62 PV 18 YP 22 FL 4.7 Gels 4/5/6 CL- 19000 FC 1/- SOL 6 SD 0 OIL 2/92 MBT 6 pH 9.5 Ca+ 40 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Flush out stack, flush cellar holes to screw pump, and blow down hoses. Wait on cement and move mud boxes which are full of cement. Break down diverter line. Flush mud pumps. Rig down hoses to drilling nipple and trip tank. Continue to wait on cement. Rig down flow-line exit, trip tank returns valve, and take knife valve off. Clean pits and work on 9 5/8” thread protectors. Replaced lube on #2 mud pump and function tested. Casing set at 2920’MD and rig down cementing head. Cut casing, nipple down riser and diverter. Kill and clean lines. Remove casing head. Make final cut on conductor and casing. Installing well head and welding up BOPE in yard. Dressed mud pumps #1 and #2 with 4 ½” liners. Replaced rubber on mud mixer #2 suction. Took on 250BLLS and 9.4 PPG mud, while waiting on well head to cool down. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2000.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan. 10, 2015 DEPTH 2920.00000 PRESENT OPERATION BOP Testing TIME 00;00:00 YESTERDAY 2920.00000 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.3 VIS 70 PV 17 YP 24 FL 4.6 Gels 4/5/6 CL- 18000 FC 1/- SOL 5 SD 0 OIL 2/93 MBT 6 pH 9.8 Ca+ 40 Alk 2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish welding on well head and pressure up to 2000PSI. Pressure held at 2000PSI. Nipple up BOP stack. Worked on rigging down elevators, casing slips, and spiders long bale. Rig up short bales hydro-elevators. Nipple up BOPE, work on top-drive, and link tilt float. Clean up work area. Weld on pitcher nipple. Continue nipple up BOPE and hooked up koomey lines. Finish dressing weld on drilling nipple. House-keeping at cellar. Function the test rams. Move up the test joint to attempt shell test. Repair and seal on the test pump. Secure stack and rig up trip tank valve. Shell test good. Testing BOPE annular, rams, and valves. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2800.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan. 11, 2015 DEPTH 2920.00000 PRESENT OPERATION RIH 5" Drill Pipe TIME 00:00:00 YESTERDAY 2920.00000 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.2 VIS 52 PV 10 YP 17 FL 4.4 Gels 3/4/5 CL- 16000 FC 1/- SOL 5 SD 0 OIL 2/93 MBT 6 pH 10 Ca+ 40 Alk 2.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Test BOPE lower pipe, test #3-#4 choke manifold, test blinds, work on check valves, and test koomey. Break down test joints and pull test plug. Reset test plug and blow-down choke manifold. Strap drill pipe and pick it up. Finish nipple up soon. Rig up and test casing (3000K for 30 minutes). Replace check valve with new valve. Continue to test BOPE. Change valve in pits. Blow on choke and mud line. Pick up BHA and PJSM. Load the source and test tools. Run in hole with BHA. Pick up 5” drill pipe and single in. Run in hole with 56 joints total to 2504’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2800 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan 11, 2015 DEPTH 3669 PRESENT OPERATION POOH TIME 23:59:00 YESTERDAY 2920 24 HOUR FOOTAGE 749 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3300.51 37.99 166.64 3091.83 3363.23 38.16 166.86 3141.2 3427 38.01 166.08 3191.4 3489.29 38.01 165.67 3240.48 3552.25 37.22 165.16 3290.35 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 619.5 @ 3134 3.9 @ 3165 163.3 195.97823 FT/HR SURFACE TORQUE 8 @ 3503 0 @ 3555 6.0 7.71000 AMPS WEIGHT ON BIT 35 @ 3556 0 @ 2946 17.5 22.09000 KLBS ROTARY RPM 134 @ 3652. 0 @ 3056 36.6 27.75000 RPM PUMP PRESSURE 2301 @ 3110 1105 @ 2925 1857.9 1852.05005 PSI DRILLING FLUIDS REPORT DEPTH 3541' MW 9.3 VIS 72 PV 21 YP 26 FL 4 Gels 5/7/8 CL- 20000 FC 1/- SOL 6 SD 0 OIL 2/92 MBT 5 pH 9.8 Ca+ 40 Alk 2.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 53 @ 3512 0 @ 2923.00000 19.2 TRIP GAS CUTTING GAS 0 @ 3669 0 @ 3669.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10099 @ 3512 200 @ 2943 3734.5 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 3669 0 @ 3669. 0.0 AVG PROPANE (C-3) 0 @ 3669 0 @ 3669 0.0 CURRENT BUTANE (C-4) 0 @ 3669 0 @ 3669 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 3669 0 @ 3669 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous Clayston 70% Tuffaceous Siltstone 30% DAILY ACTIVITY SUMMARY Single in 5” drill pipe to 2822’MD. Start displacement of mud at 170SPM and totaled 214BBLS. Cement tag at 2828’MD. Drill to 2919’MD. Started new hole at 2920’MD. Drilled 20’ft and circulated bottom up. Started FIT test (17.5EMW and held for 15 minutes). Drilled ahead to 2960’MD and circulated bottom up. Started another FIT test and completed at 15.1EMW. Service top-drive and rig. Drill ahead from 2960’-3669’MD. Circulate and condition hole. Bottom up and pull out of hole from 3669’-3546’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2900.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda, Monie Sainz DATE Jan 12, 2015 DEPTH 5122.00000 PRESENT OPERATION Wiper trip. TIME 23:59:00 YESTERDAY 3669.00000 24 HOUR FOOTAGE 1453 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4879.29 36.26 165.10 4373.00 4942.32 36.08 165.57 4423.88 5002.29 35.74 166.46 4472.46 5069.93 35.82 166.42 4527.33 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 667.4 @ 4113.00000 3.5 @ 4124. 156.1 404.73801 FT/HR SURFACE TORQUE 11 @ 5090.00000 0 @ 4303 7.5 9.92000 AMPS WEIGHT ON BIT 35 @ 4559.00000 2 @ 4048 20.3 22.75000 KLBS ROTARY RPM 136 @ 4191.00000 18 @ 4123 64.4 36.33000 RPM PUMP PRESSURE 2767 @ 4814.00000 1397 @ 3670 2579.1 2696.64990 PSI DRILLING FLUIDS REPORT DEPTH 4871' MW 9.4 VIS 61 PV 18 YP 23 FL 3.7 Gels 6/8/10 CL- 2200 FC 1/- SOL 6 SD 0 OIL 1/93 MBT 7 pH 9.7 Ca+ 40 Alk 2.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 136 @ 4834.00000 2 @ 3688 42.0 TRIP GAS CUTTING GAS 0 @ 5122.00000 0 @ 5122. 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 27701 @ 4834.00000 554 @ 3688 8182.7 CONNECTION GAS HIGH ETHANE (C-2) 20 @ 5067.00000 0 @ 5005 0.8 AVG PROPANE (C-3) 0 @ 5122.00000 0 @ 5122 0.0 CURRENT BUTANE (C-4) 0 @ 5122.00000 0 @ 5122 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 5122.00000 0 @ 5122. 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% Tuffaceous Claystone, 30% Sandstone, 30% Tuffaceous Siltstone. DAILY ACTIVITY SUMMARY Pull out of hole from 3546’-3381’MD. Washout from 3381’-2915’MD (shoe). Repair leak on top-drive hydraulics O- ring. Fix pipe grabber stopper, service top-drive, fix suction valve in pit #2. Run in hole from 2915’-3668’ MD and continue to drill ahead. Slide from 4240’-4258’MD, 4556’-4572’MD, and 4936’-4958’MD. Drill to 5122’MD and start wiper trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY BrittenAdams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 13, 2015 DEPTH 6510' PRESENT OPERATION Drilling Ahead TIME 23:59:00 YESTERDAY 5122' 24 HOUR FOOTAGE 1388' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5945.52 34.38 164.99 5245.47 6070.90 34.11 165.65 5349.37 6197.07 34.34 165.67 5453.61 6324.87 34.88 165.52 5558.84 6512.78 33.76 165.06 5713.50 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 670.6 @ 5426 4.0 @ 5494 203.7 170.87642 FT/HR SURFACE TORQUE 13 @ 6504 0 @ 5955 10.1 12.38000 AMPS WEIGHT ON BIT 28 @ 5565. 0 @ 5876 15.6 19.63000 KLBS ROTARY RPM 136 @ 5684. 14 @ 6264 47.3 24.15000 RPM PUMP PRESSURE 2843 @ 6495. 2255 @ 5123 2675.4 2786.58008 PSI DRILLING FLUIDS REPORT DEPTH 6252' MW 9.5 VIS 67 PV 24 YP 24 FL 4.2 Gels 7/8/10 CL- 28000 FC 1/- SOL 6 SD 0.25 OIL 0 MBT 7 pH 9.7 Ca+ 40 Alk 2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 237 @ 5633 0 @ 5126 65.3 TRIP GAS CUTTING GAS 0 @ 6510 0 @ 6510 0.0 WIPER GAS 46u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 46920 @ 5633 62 @ 5126 12938.2 CONNECTION GAS HIGH ETHANE (C-2) 121 @ 5634. 0 @ 5328 9.7 AVG PROPANE (C-3) 105 @ 5842 0 @ 5328 8.1 CURRENT BUTANE (C-4) 0 @ 6510 0 @ 6510 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 6510 0 @ 6510 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 60% Tuffaceous Siltstone, 10% Sand, 30% Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Pull out of hole from 5122’-3545’MD. Circulate and wipe hole. Service block, carrier, and top-drive. Clean rig floor surface. Run in hole from 3545’-4970’MD. Pull up 48 singles 5” drill pipe. Wash down from 4970’-5122’MD. Drill ahead from 5122’-6568’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Monie Sainz, Rod Maniaci DATE Jan 14, 2015 DEPTH 7382' PRESENT OPERATION Drilling Ahead TIME 23:59:00 YESTERDAY 6554' 24 HOUR FOOTAGE 831' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6825.45 29.02 164.44 5978.52 6951.71 25.95 166.56 6090.58 7077.22 23.69 166.55 6204.42 7203.86 22.57 166.75 6320.97 7267.82 21.90 167.64 6380.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 488.5 @ 7049 2.1 @ 6692 139.8 127.54992 FT/HR SURFACE TORQUE 14 @ 7334 0 @ 6715 10.2 13.91000 AMPS WEIGHT ON BIT 31 @ 6902 1 @ 6675 17.9 18.89000 KLBS ROTARY RPM 43 @ 6805 0 @ 6911 28.3 31.00000 RPM PUMP PRESSURE 2862 @ 6719 1487 @ 6635 2676.1 2766.81006 PSI DRILLING FLUIDS REPORT DEPTH 6252 MW 9.5 VIS 67 PV 24 YP 23 FL 4.2 Gels 7/8/10 CL- 28000 FC 1/- SOL 6 SD 0.25 OIL 0/94 MBT 7 pH 9.7 Ca+ 40 Alk 2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 190 @ 7369 6 @ 6692 35.9 TRIP GAS CUTTING GAS 0 @ 7382 0 @ 7382 0.0 WIPER GAS 49u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 31973 @ 7366 1299 @ 6692 6516.5 CONNECTION GAS HIGH ETHANE (C-2) 51 @ 7366 0 @ 6571 1.9 AVG PROPANE (C-3) 25 @ 6893 0 @ 7129 0.7 CURRENT BUTANE (C-4) 0 @ 7382 0 @ 7382 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 7382 0 @ 7382 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 70% Coal, 20% Tuffaceous Siltstone. DAILY ACTIVITY SUMMARY Drill from 6568’-6630’MD. Circulate and condition at 500GPM with 2400PSI. Sweep showed at 1000STK past count. Monitor well static and fill trip tank. Pull out of hole from 6630’-5055’MD and monitor well again. Rig up to pick up 50 singles. Run in hole with singles from 5055’-6567’MD. Fill pipe with mud. Malfunction with #3 mud pump. Pump #3 fixed. Wash from 6567’-6630’MD. Drill ahead from 6690’- 7382’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 15, 2015 DEPTH 8586 PRESENT OPERATION POOH TIME 23:59:00 YESTERDAY 7382 24 HOUR FOOTAGE 1204 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8089.34 7.62 164.41 7169.98 8151.73 6.30 159.97 7231.91 8215.74 5.18 152.66 7295.60 8340.69 3.39 150.98 7420.17 8467.11 1.40 211.47 7546.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 534.1 @ 7924 2.0 @ 7827 133.9 117.95544 FT/HR SURFACE TORQUE 20 @ 7922 0 @ 8225 12.2 16.97000 AMPS WEIGHT ON BIT 49 @ 7702 0 @ 7786 18.8 21.23000 KLBS ROTARY RPM 130 @ 8386 0 @ 7713 33.1 30.21000 RPM PUMP PRESSURE 2865 @ 8401 1358 @ 8323 2545.2 2824.69995 PSI DRILLING FLUIDS REPORT DEPTH 8523' MW 9.4 VIS 65 PV 23 YP 27 FL 4.3 Gels 7/9/11 CL- 27000 FC 1/- SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 9.7 Ca+ 27000 Alk 1.3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 392 @ 8171.00000 4 @ 7775.00000 48.9 TRIP GAS CUTTING GAS 0 @ 8586.00000 0 @ 8586.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 71630 @ 8171 838 @ 7775 9574.1 CONNECTION GAS HIGH ETHANE (C-2) 158 @ 8171 0 @ 7431 15.6 AVG PROPANE (C-3) 121 @ 8457 0 @ 7431 19.5 CURRENT BUTANE (C-4) 0 @ 8586 0 @ 8586 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 8586 0 @ 8586 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 20% Coal, 40% Tuffaceous Siltstone, 10% Sand, 30% Tuffaceous Sandstone. DAILY ACTIVITY SUMMARY Trouble shoot issue with #2 shaker. Continue to drill and reduce drilling rate due to sliding per Baker rep. During drilling, pull up and move up stands in mouse hole. Continue to drill until 8586’MD. Start to pull out of hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 16, 2015 DEPTH 9492 PRESENT OPERATION POOH TIME 23:59;00 YESTERDAY 8586 24 HOUR FOOTAGE 906 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8903.90 1.51 7.44 7983.18 9029.49 1.86 12.03 8108.72 9155.82 1.47 8.69 8235.00 9281.33 2.07 4.20 8360.45 9408.89 3.54 357.39 8487.85 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 488.8 @ 8853 2.2 @ 9088 112.4 0.00000 FT/HR SURFACE TORQUE 21 @ 9431 0 @ 8604 16.5 0.90000 AMPS WEIGHT ON BIT 32 @ 9288 0 @ 9471 18.5 16.30000 KLBS ROTARY RPM 38 @ 8624 0 @ 9089 26.4 0.00000 RPM PUMP PRESSURE 3081 @ 9304 2336 @ 8587 2821.5 2355.57007 PSI DRILLING FLUIDS REPORT DEPTH 9368' MW 9.4 VIS 60 PV 20 YP 26 FL 4.1 Gels 5/7/10 CL- 27500 FC 1/- SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 9.7 Ca+ 140 Alk 1.3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 362 @ 8953 3 @ 9483 34.2 TRIP GAS CUTTING GAS 0 @ 9492 0 @ 9492 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 71788 @ 8953 659 @ 9483 6591.6 CONNECTION GAS HIGH ETHANE (C-2) 198 @ 8953 0 @ 9487 16.2 AVG PROPANE (C-3) 58 @ 8856 0 @ 9487. 7.0 CURRENT BUTANE (C-4) 0 @ 9492 0 @ 9492 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 9492 0 @ 9492 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 30% Tuffaceous Siltstone, 30% Coal, 20% Sandstone, 20% Tuffaceous Sandstone. DAILY ACTIVITY SUMMARY Pull out of hole from 8398’-6500’MD. Perform a BOP drill and monitor well. Service top-drive, block, and carrier on top-drive. Run in hole with singles from 6567’-7657’MD. Fix O-ring on top drive. Continue to run in from 7657’- 8586’MD. Drill and slider per Baker representative. Drill to 9492’MD and notice pump pressure drop. Check surface and trouble shoot with MWD tool. Start to pull out of hole. Problem with top drive function. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 17, 2015 DEPTH 9968.00000 PRESENT OPERATION POOH TIME 23:59:00 YESTERDAY 9492.00000 24 HOUR FOOTAGE 476 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9787.44 3.35 0.97 8865.93 9850.78 3.65 359.98 8929.15 9912.97 4.11 356.44 8991.20 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 252.9 @ 9518 1.5 @ 9534 76.1 63.26889 FT/HR SURFACE TORQUE 28 @ 9674 0 @ 9520 19.2 20.51000 AMPS WEIGHT ON BIT 34 @ 9514 1 @ 9553 16.4 16.18000 KLBS ROTARY RPM 133 @ 9925 0 @ 9529 56.0 24.61000 RPM PUMP PRESSURE 2991 @ 9672 217 @ 9519 2727.5 2787.79000 PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.4 VIS 59 PV 20 YP 26 FL 4.1 Gels 6/8/10 CL- 28000 FC 1/- SOL 7 SD 0.25 OIL 0 MBT 7.75 pH 10 Ca+ 120 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 108 @ 9944. 1 @ 9501 19.5 TRIP GAS CUTTING GAS 0 @ 9968 0 @ 9968 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 19871 @ 9749 315 @ 9501 3771.8 CONNECTION GAS HIGH ETHANE (C-2) 82 @ 9663 0 @ 9622 9.8 AVG PROPANE (C-3) 71 @ 9663 0 @ 9772 4.7 CURRENT BUTANE (C-4) 0 @ 9968 0 @ 9968 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 9968 0 @ 9968 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pull out of from to find washout. At 7699’ MD, washout was on top of stand #110. Lay down joint and service rig. Run in hole to 9466’MD and wash/ream from 9466’-9522’MD. Continue to drill and slide per Baker. Drill to 9968’MD (TD). Circulate and clean hole with 2 bottom ups. Continue to pull from 9968’-7450’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 18, 2015 DEPTH 9968 PRESENT OPERATION RIH TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.4 VIS 60 PV 20 YP 26 FL 4.1 Gels 6/8/10 CL- 28000 FC 1/- SOL 7 SD 0.25 OIL 0/93 MBT 7.75 pH 10 Ca+ 120 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pull out the hole from 7450’-6410’MD. Monitor well (OK). Continue to pull out to 5798’MD. Blow down top-drive. Pull out to 3231’MD and monitor well (OK). Replace hydraulic valve on top-drive. Prepare test for BOPs. Run up test plug to drill string. Test BOPs annular, rams, and valves. Finish BOP test (good). Monitor well. Hang block and slip/cut drilling line. Run in hole from 2914’-5373’MD. CANRIG PERSONNEL ON BOARD 4 DAILY COST 2950.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 19, 2015 DEPTH 9968 PRESENT OPERATION POOH TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.4 VIS 65 PV 20 YP 26 FL 4.1 Gels 6/8/10 CL- 28000 FC 1/- SOL 7 SD 0 OIL 0/93 MBT 7.75 pH 10 Ca+ 120 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to run in hole from 5373’-9968’MD with washing and cleaning. Monitor well (OK). Pull out of hole from 9968’-2011’MD. Lay down agitator and shock sub. Continue to pull out from 2011’-752’MD. Pull up singles joint 5” drill pipe. Lay down jars and heavy weight. Safety meeting and remove radioactive source. Lay down sub and #1 DC. Download MWD data off tool. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2000.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 20, 2015 DEPTH 9968 PRESENT OPERATION RIH TIME 23:29:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.4 VIS 72 PV 20 YP 26 FL 4.1 Gels 6/8/10 CL- 28000 FC 1/- SOL 7 SD 0.25 OIL 0 MBT 7.75 pH 10 Ca+ 120 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish downloading data from MWD tool. Lay down BHA. Monitor well and clean rig floor. Strap new tally and BHA. Have safety meeting with Halliburton’s e-line crew. Halliburton ran two e-lines (TripleCombo and Side-Core-Gun). Halliburton log are good. Halliburton break rig down tool. Monitor well. Pick up BHA with 8 ¾” bit. Run in hole with 5”drill pipe. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Monie Sainz DATE Jan 21, 2015 DEPTH 9968 PRESENT OPERATION RIH TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.3 VIS 58 PV 17 YP 22 FL 4.1 Gels 5/8/9 CL- 26500 FC 1/- SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 10 Ca+ 160 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 63u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in hole from 1287’-9593’MD. Can’t rotate top-drive in hole. Attempt to work free and not freeing. Pull back stand to free pipe. Jars still not freeing. Pump 30BBLs of lube pills. Work pipe and it freed up. Continue to wash and clean to 9659’MD. Rig up head pin to safety valve on stump circulated. Replaced T.D. grabber die’s and tighten bolts. Install safety wire on top-drive grabber. Wash and rotate and tag bottom at 9973’MD. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci/Time Mckieran DATE Jan 22, 2015 DEPTH 9968 PRESENT OPERATION Break down BHA TIME 23:59:59 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.3 VIS 63 PV 17 YP 22 FL 4 Gels 5/8/9 CL- 27000 FC 1 SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 10 Ca+ 160 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 16u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Back ream from 9973’-9700’MD. Attempt to pull out the hole at 9700’MD on hooks (no good). Continue to back ream from 9700’-9280’MD. Attempt to pull out of hole with hooks (go good). Continue to ream to 8712’MD. Pull out of hole from 8712’-8460’MD with no pumps or rotation (good). Continue to pull out to 5592’MD. Rig up to lay down singles from 5592’-1160’MD. Lay down BHA. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci/Tim McKieran DATE Jan 23, 2015 DEPTH 9968 PRESENT OPERATION RIH casing TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.3 VIS 89 PV 17 YP 21 FL 4 Gels 5/8/9 CL- 27000 FC 1 SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 10 Ca+ 160 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to lay down BHA. Install casing tool and pick up 7” casing. Replace rams and pressure tests them. Have safety meeting with crew, and run 7” casing. Circulated bottom at 2930’MD and continue to run in hole. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci, Tim McKieran DATE Jan 24, 2015 DEPTH 9968 PRESENT OPERATION POOH 7" casing TIME 23:59:59 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.3 VIS 77 PV 19 YP 22 FL 4.1 Gels 5/7/9 CL- 27000 FC 1 SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 9.8 Ca+ 160 Alk 1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to run in the hole with 7” casing. At 8920” MD, casing stop running in hole. Driller work casing for several hour (no good). Pull 7” casing out of hole to 4796”Md and lay casing down. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci/Tim McKiernan DATE Jan 17, 2015 DEPTH 9968 PRESENT OPERATION BOP test TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.4 VIS 70 PV 16 YP 21 FL 4.3 Gels 5/7/9 CL- 25000 FC 1 SOL 7 SD 0.25 OIL 0 MBT 7.5 pH 9.6 Ca+ 160 Alk 0.9 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to pull out the hole with 7” casing. Fill pipe every 5 stands. Joint #106 is bad. Continue to pull out from 2446’-95’MD. Rig down Weatherford tools. Change out upper pipe ram. Rig up to test BOP. Move up test joint. Test BOP stack. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Rod Maniaci/Tim McKiernan DATE Jan 26, 2015 DEPTH 9968.00000 PRESENT OPERATION Clean Hole. TIME 23:59:00 YESTERDAY 9968.00000 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.4 VIS 65 PV 14 YP 18 FL 3.9 Gels 5/7/9 CL- 28500 FC 1 SOL 7 SD 0.25 OIL 0/93 MBT 6 pH 10 Ca+ 160 Alk 1.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to test BOP. Test gas alarms (good). Rig-down test equipment tools. Pull up BHA and prepare rig floor for running in hole. Run in hole with HWDP and rack drill pipe. RIH to 2942’MD. Slip and cut drill line and adjust torque tube. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda/Tim McKiernan DATE Jan 27, 2015 DEPTH 9968 PRESENT OPERATION Reaming Hole. TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.7 VIS 58 PV 18 YP 23 FL 4.1 Gels 6/8/9 CL- 24000 FC 1 SOL 9 SD 0.25 OIL 0/91 MBT 6.25 pH 9.3 Ca+ 160 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 468u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run in the hole to 9968’MD to clean and condition hole. Pull out of hole to 7152’MD and trip in hole to 8970’MD. Ream hole from 8970’- 9117’MD. Continue back in hole to 9497’-9968’MD and ream. Move mud weight up to 9.7LB/GAL. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda/Tim McKiernan DATE Jan 28, 2015 DEPTH 9968 PRESENT OPERATION Testing BOP TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968' MW 9.7 VIS 65 PV 17 YP 21 FL 4 Gels 6/8/9 CL- 24000 FC 1 SOL 9 SD 0.25 OIL 0 MBT 6.25 pH 9.3 Ca+ 160 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 9u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Circulate and condition mud. Wipe hole to 8500'MD. Run in hole to 9967'MD. Circulate bottoms up to clean hole. Pull out of hole to surface. Lay down BHA and change pipe rams. Testing BOP stack currently. DAILY ACTIVITY SUMMARY Circulate and condition mud. Wiped jole to 8500'MD. Run in hole to 9967'MD. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams Cook Inlet Energy DAILY WELLSITE REPORT North Fork Unit # 42-35 REPORT FOR Al Lunda/Tim Kiernan DATE Jan 29, 2015 DEPTH 9968 PRESENT OPERATION R/U Cementing TIME 23:59:00 YESTERDAY 9968 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 9968 MW 9.7 VIS 63 PV 17 YP 19 FL 4 Gels 4/7/7 CL- 24000 FC 1 SOL 9 SD 0.25 OIL 0 MBT 6.25 pH 8 Ca+ 160 Alk 0.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue BOPE test. Lay down test joint and rig up casing equipment. Run in casing to 8000’MD and circulate two bottoms up. Continue casing to 9955’MD. Rig up cementers. CANRIG PERSONNEL ON BOARD 2 DAILY COST 2050.00 REPORT BY Britten Adams