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Home My WebLink About214-1661. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Re-run cap string Development Exploratory 3. Address: 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 9,750 feet 8,482 feet true vertical 9,404 feet 9,092' (fish) feet Effective Depth measured 8,482 feet See Schematic feet true vertical 8,135 feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Cap String 3/8" 5,850' MD 5,519' TVD Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 8,483' MD 8,138' TVD Packers and SSSV (type, measured and true vertical depth) See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5,410psi 5,750psi 7,240psi 2,943' 2,818' Burst Collapse 3,090psi Production Liner 9,725' Casing Structural 9,380'9,725' 120'Conductor Surface Intermediate 20" 9-5/8" 120' 2,943' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-166 50-231-20045-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 391211 North Fork / Tyonek Gas North Fork Unit (NFU) 24-26 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 190 Size 120' 13 100472 0 5413 52 Scott Warner, Operations Engineer N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 572 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 p k ft t Fra O g s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov DOA - Noel Nocas Out of Office By Grace Christianson at 2:04 pm, Aug 21, 2025 Digitally signed by Scott Warner (4620) DN: cn=Scott Warner (4620) Date: 2025.08.21 11:25:10 - 08'00' Scott Warner (4620) BJM 10/3/25 Page 1/1 Well Name: North Fork Unit 24-26 Report Printed: 8/21/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50231200450000 Field Name:North Fork State/Province:ALASKA Permit to Drill (PTD) #:214166 Sundry #: Rig Name/No: Capillary tubing unit Jobs Actual Start Date:6/2/2025 End Date: Report Number 1 Report Start Date 6/4/2025 Report End Date 6/4/2025 Last 24hr Summary PTW, JSA. MIRU Capillary tubing unit. PU 300 lbs over string weight. Pull on cap string. POOH at 1900 lbs. Tagged up at surface. 6500' of 3/8" cap string and foot valve recovered. Rig back injector head. Bring well online. RDMO cap string truck. Report Number 2 Report Start Date 6/5/2025 Report End Date 6/5/2025 Last 24hr Summary PT 500 psi low/2500 psi high. Drift, tag and pt survey. RDMO Report Number 3 Report Start Date 6/6/2025 Report End Date 6/7/2025 Last 24hr Summary PTW, JSA. MIRU HAK capstring truck Make up pack off assembly and foot valve. Fluid pack and pressure test packoff assembly and wellhead bowen connection. 250/3500 psi. RIH to 5900'. Pick up in tension to 1650 lbs. Park string at 5850'. Install hanger assembly. Pressure up dynamic pack off assembly to 3000 psi and block in. Rig down capillary tubing unit. Report Number 4 Report Start Date 8/7/2025 Report End Date 8/8/2025 Last 24hr Summary We received clarity on documentation required for capstrings from email sent to AOGCC on 7/16. 404 documentation needed for capstring maintenance. Updated by JKO 7/17/25 SCHEMATIC North Fork Unit NFU 24-26 PTD: 214-166 API: 50-231-20045-00-00 PBTD = 9,640 / TVD = 9,295 TD = 9,750 / TVD = 9,404 JEWELRY DETAIL No. Depth ID OD Item 1 352 2.31HES Well StarTRSSSV @ 352 X nipple (SSSV mechanically locked out 5-4-17) 2 2,5242.441Chemical Injection Mandrel 3 5,0772.441RA Marker @ 5,077 4 5,1462.313Sliding Sleeve Annular (CLOSED 4/6/15) 5 5,1616.276Tripoint Hydraulic Set Packer 6 5,1882.313Sliding Sleeve Zone 1 (CLOSED 4/6/15) 7 5,8736.276Tripoint Hydraulic Set Packer 8 5,9042.313Sliding Sleeve Zone 2 (OPEN) 9 8,3342.441RA Marker @ 8,334 10 8,4046.276Tripoint Hydraulic Set Packer 11 8,4482.313X Nipple 12 8,4822.205XN Nipple Zone 3 (CLOSED, PXN set 3-16-15) 13 8,4832.441WLEG 14 8,9646.276Tripoint Packer Model D 15 XO 2 7/8 x 2 3/8 16 8,978 1.795 2 3/8 XN Nipple Zone 4 (CLOSED, XXN? plug in XN Nipple) 17 9,092 Fish 1: TCP guns 88 OAL Fish 2: Cut 2 7/8 tubing 6.5# 460 OAL OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Spacer 38 bbl 9.6 ppg. Lead - 281 bbl 12.5 ppg cement. Tail - 41 bbl 14.8 ppg cement. 125 bbls cement to surface. 8-3/4CBL TOC @ 4,050. 38.5 bbl spacer followed by 161 bbl 12.7 ppg lead cement and 99.5 bbl 13.5 ppg tail cement. CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor 93 K-55 Weld 14.88Surf 120 9-5/8"Surf Csg 40 L-80 BTC 8.835Surf 2,943 7"Intermediate Csg 26 L-80 GeoCon 6.276Surf 9,725 2-7/8Production Tubing 6.5 L-80 EUEM BTC 2.441Surf 8,483 16 Conductor 7 Csg 12-1/4 hole 1 9-5/8 Csg 8-3/4 hole 3 4 5 6 7 8 9 10 11 12 & 13 14 15 16 RKB TO GL: 21 17 3/8 Capillary String Set @ 5,850 Max Deviation 24 deg @ 2,190 MD All sleeves open DOWN. T-47 T-42 T-46 T-47 T-7 T-11 T-13 T-14 T-18 T-22 T-23 T-2 T-3 T-4 T-5 T-6 PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,196 5,204 4,898 4,906 8' 2/15/2015 Inactive - Zone 1 T-2 5,262 5,280 4,960 4,977 18' 2/15/2015 Inactive - Zone 1 T-6 5,765 5,800 5,438 5,471 35' 2/15/2015 Inactive - Zone 1 T-7 5,908 5,921 5,575 5,587 13' 12/5/2021 Open (reperf) - Zone 2 T-7 5,911 5,934 5,578 5,600 23' 2/15/2015 Open - Zone 2 T-7 5,921 5,941 5,587 5,607 20' 12/5/2021 Open (reperf) - Zone 2 T-7 5,934 5,940 5,600 5,606 6' 4/1/2020 Open - Zone 2 T-7 5,990 6,004 5,654 5,667 14' 2/15/2015 Open - Zone 2 T-11 6,310 6,326 5,967 5,982 16' 12/5/2021 Open (reperf) - Zone 2 T-11 6,310 6,340 5,967 5,996 30' 4/1/2020 Open - Zone 2 T-11 6,329 6,334 5,985 5,990 5' 12/4/2021 Open (reperf) - Zone 2 T-11 6,330 6,342 5,986 5,998 12' 12/1/2021 Open (reperf) - Zone 2 T-13 6,400 6,415 6,056 6,071 15' 4/1/2020 Open - Zone 2 T-14 6,435 6,450 6,091 6,106 15' 4/1/2020 Open - Zone 2 T-18 6,766 6,778 6,421 6,433 12' 12/5/2021 Open - Zone 2 T-22 7,027 (7,012) 7,034 (7,019) 6,682 6,689 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-22 7,034 (7,019) 7,041 (7,026) 6,689 6,696 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-23 7,177 (7,162) 7,185 ( 7,170) 6,832 6,840 8' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-42 8,497 8,523 8,147 8,179 26' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-46 8,804 8,812 8,459 8,467 8' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,917 8,932 8,589 8,600 15' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,970 9,016 8,625 8,671 46' Plugged - Zone 4 (Plug in XN) Notes: There was an error in the depth tie in of original logging of the 24-26 LWD between Run 2 & Run 3. The result is that the original LWD log is 15' deeper that subsequent cased hole logs. 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: Shift Sleeve, N2 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): 9,750'9,092' (fish) 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 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: Tubing Size: Cap String 3/8" PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: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 ADL 391211 214-166 50-231-20045-00-00 Hilcorp Alaska, LLC Proposed Pools: 6.5# / L-80 TVD Burst 8,483' 7,240psi 2,818' Size 120' 2,943' MD See Attached Schematic 5,750psi 120'120' 2,943' September 4, 2025 2-7/8" 9,725' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 North Fork Unit (NFU) 24-26CO 705, CO 720 Same 9,380'7" 1,830 9,725' 8,482' Length See Schematuic See Schematic 9,404'8,482'8,135' North Fork Tyonek Gas 20" 9-5/8" See Attached Schematic m n P s 66 tc N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov DOA - Noel Nocas Out of Office By Grace Christianson at 2:23 pm, Aug 21, 2025 Digitally signed by Ryan Lemay (14113) DN: cn=Ryan Lemay (14113) Date: 2025.08.21 11:26:57 - 08'00' Ryan Lemay (14113) 325-500 10-404 BJM 8/22/25 DSR-9/26/25A.Dewhurst 27AUG25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.28 08:17:58 -08'00'08/28/25 RBDMS JSB 082825 Well Prognosis Well Name: NFU 24-26 API Number: 50-231-20045-00-00 Current Status: Producing Gas Well Permit to Drill Number: 214-166 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: 2368 psi @ 5381’ TVD Based on 0.44 psi/ft and proposed T-6 perfs Max. Potential Surface Pressure: 1830 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.71 psi/ft using 13.62 ppg EMW FIT at the 9-5/8” sur. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.71-0.1) = 1830 psi / 0.61 = 3000‘ TVD Top of Applicable Gas Pool: 5060’ MD/ 4772’ TVD Well Status: Online Gas Producer flowing at 475 mcfd, 2 bwpd, 51 psi FTP Well Summary North Fork 24-26 is a vertical well that was drilled in 2014. Over the years various zones were tested from the T- 47 through T-2 with varying results. T-2 through T-6 perforations were isolated in 2015 by closing a sliding sleeve and have not produced since. The purpose of this sundry is to access the T-2 & T-6 perforations by opening the zone 1 sliding sleeve and conducting a flow test. If successful, additional perforations and re-perforations will be performed to increase production. Notes Regarding Wellbore x Deviation o Max deviation: 24.9° @ 2440’ MD o Max DLS: 5.13°/100ft @ 430’ MD x Min ID o 2.313” at: 352’ MD (TRSSSV) 5146’, 5188’, 5904, MD (sliding sleeves) x Recent Tags o 6/5/25: SL RIH w/ 2.27 LIB to 8462’ SLM Pre-Sundry Steps: 1. MIRU Cap string truck 2. Pull 3/8” cap string from 5850’ MD 3. RD cap string truck Slickline Procedure 1. MIRU Slickline and pressure control equipment 2. PT lubricator to 250 psi low / 2,500 psi high 3. RIH and shift sliding sleeve – zone 1 at 5188’ MD open to allow access to T-2 and T-6 perforations a. Shut in well ahead of time to allow pressure build prior to shifting sleeve b. Hand well over to production to flow test c. Contact OE with results prior to rigging down d. If results are negative, shift sliding sleeve closed 4. RDMO Well Prognosis Eline Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,500 psi high 3. RIH and perforate Beluga T2 – T7 sands from bottom up: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Footage T2 (reperf/add) ±5,195' ±5,229' ±4,897' ±4,929' ±34' T2 (reperf) ±5,262' ±5,280' ±4,960' ±4,977' ±18' T3 ±5,407' ±5,421' ±5,097' ±5,110' ±14' T3 ±5,425' ±5,452' ±5,114' ±5,140' ±27' T5 ±5,605' ±5,625' ±5,285' ±5,304' ±20' T5 ±5,681' ±5,695' ±5,358' ±5,371' ±14' T6 ±5,705' ±5,725' ±5,381' ±5,400' ±20' T6 (reperf) ±5,765' ±5,800' ±5,438' ±5,471' ±35' T7 (reperf) ±5,908' ±5,941' ±5,575' ±5,607' ±33' T7 (reperf) ±5,990' ±6,004' ±5,654' ±5,667' ±14' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. 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) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. i. Patch will most likely be used to avoid shutting off current production. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Cap String Procedure: 1. RU Cap String Truck 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 2000 psi 3. RIH with 3/8” capillary string to ±5150’ MD 4. Install slips and connect tubing to chemical injection pump 5. Set spool of remaining line near well 6. RD cap string unit, and turn well over to production Well Prognosis Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Updated by JKO 7/17/25 SCHEMATIC North Fork Unit NFU 24-26 PTD: 214-166 API: 50-231-20045-00-00 PBTD = 9,640’ / TVD = 9,295’ TD = 9,750’ / TVD = 9,404’ JEWELRY DETAIL No.Depth ID OD Item 1 352’ 2.31”HES Well StarTRSSSV @ 352’ X nipple (SSSV mechanically locked out 5-4-17) 2 2,524’2.441”Chemical Injection Mandrel 3 5,077’2.441”RA Marker @ 5,077’ 4 5,146’2.313”Sliding Sleeve – Annular (CLOSED 4/6/15) 5 5,161’6.276”Tripoint Hydraulic Set Packer 6 5,188’2.313”Sliding Sleeve – Zone 1 (CLOSED 4/6/15) 7 5,873’6.276”Tripoint Hydraulic Set Packer 8 5,904’2.313”Sliding Sleeve – Zone 2 (OPEN) 9 8,334’2.441”RA Marker @ 8,334’ 10 8,404’6.276”Tripoint Hydraulic Set Packer 11 8,448’2.313”X Nipple 12 8,482’2.205”XN Nipple – Zone 3 (CLOSED, PXN set 3-16-15) 13 8,483’2.441”WLEG 14 8,964’6.276”Tripoint Packer Model ‘D’ 15 XO – 2 7/8” x 2 3/8” 16 8,978’1.795”2 3/8” XN Nipple – Zone 4 (CLOSED, XXN? plug in XN Nipple) 17 9,092’ Fish 1: TCP guns 88’ OAL Fish 2: Cut 2 7/8” tubing 6.5# 460’ OAL OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Spacer – 38 bbl 9.6 ppg. Lead - 281 bbl 12.5 ppg cement. Tail - 41 bbl 14.8 ppg cement. 125 bbls cement to surface. 8-3/4”CBL TOC @ 4,050’. 38.5 bbl spacer followed by 161 bbl 12.7 ppg lead cement and 99.5 bbl 13.5 ppg tail cement. CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor 93 K-55 Weld 14.88”Surf 120’ 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,943’ 7"Intermediate Csg 26 L-80 GeoCon 6.276”Surf 9,725’ 2-7/8”Production Tubing 6.5 L-80 EUEM BTC 2.441”Surf 8,483’ 16” Conductor 7” Csg 12-1/4” hole 1 9-5/8” Csg 8-3/4” hole 3 4 5 6 7 8 9 10 11 12 & 13 14 15 16 RKB TO GL: 21’ 17 3/8” Capillary String Set @ 5,850’ Max Deviation – 24 deg @ 2,190’ MD All sleeves open DOWN. T-47 T-42 T-46 T-47 T-7 T-11 T-13 T-14 T-18 T-22 T-23 T-2 T-3 T-4 T-5 T-6 PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,196 5,204 4,898 4,906 8' 2/15/2015 Inactive - Zone 1 T-2 5,262 5,280 4,960 4,977 18' 2/15/2015 Inactive - Zone 1 T-6 5,765 5,800 5,438 5,471 35' 2/15/2015 Inactive - Zone 1 T-7 5,908 5,921 5,575 5,587 13' 12/5/2021 Open (reperf) - Zone 2 T-7 5,911 5,934 5,578 5,600 23' 2/15/2015 Open - Zone 2 T-7 5,921 5,941 5,587 5,607 20' 12/5/2021 Open (reperf) - Zone 2 T-7 5,934 5,940 5,600 5,606 6' 4/1/2020 Open - Zone 2 T-7 5,990 6,004 5,654 5,667 14' 2/15/2015 Open - Zone 2 T-11 6,310 6,326 5,967 5,982 16' 12/5/2021 Open (reperf) - Zone 2 T-11 6,310 6,340 5,967 5,996 30' 4/1/2020 Open - Zone 2 T-11 6,329 6,334 5,985 5,990 5' 12/4/2021 Open (reperf) - Zone 2 T-11 6,330 6,342 5,986 5,998 12' 12/1/2021 Open (reperf) - Zone 2 T-13 6,400 6,415 6,056 6,071 15' 4/1/2020 Open - Zone 2 T-14 6,435 6,450 6,091 6,106 15' 4/1/2020 Open - Zone 2 T-18 6,766 6,778 6,421 6,433 12' 12/5/2021 Open - Zone 2 T-22 7,027 (7,012) 7,034 (7,019) 6,682 6,689 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-22 7,034 (7,019) 7,041 (7,026) 6,689 6,696 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-23 7,177 (7,162) 7,185 ( 7,170) 6,832 6,840 8' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-42 8,497 8,523 8,147 8,179 26' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-46 8,804 8,812 8,459 8,467 8' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,917 8,932 8,589 8,600 15' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,970 9,016 8,625 8,671 46' Plugged - Zone 4 (Plug in XN) Notes: There was an error in the depth tie in of original logging of the 24-26 LWD between Run 2 & Run 3. The result is that the original LWD log is 15' deeper that subsequent cased hole logs. Updated by SRW 8/21/25 PROPOSED - SCHEMATIC North Fork Unit NFU 24-26 PTD: 214-166 API: 50-231-20045-00-00 PBTD = 9,640’ / TVD = 9,295’ TD = 9,750’ / TVD = 9,404’ JEWELRY DETAIL No.Depth ID OD Item 1 352’ 2.31”HES Well StarTRSSSV @ 352’ X nipple (SSSV mechanically locked out 5-4-17) 2 2,524’2.441”Chemical Injection Mandrel 3 5,077’2.441”RA Marker @ 5,077’ 4 5,146’2.313”Sliding Sleeve – Annular (CLOSED 4/6/15) 5 5,161’6.276”Tripoint Hydraulic Set Packer 6 5,188’2.313”Sliding Sleeve – Zone 1 (OPEN -TBD) 7 5,873’6.276”Tripoint Hydraulic Set Packer 8 5,904’2.313”Sliding Sleeve – Zone 2 (OPEN) 9 8,334’2.441”RA Marker @ 8,334’ 10 8,404’6.276”Tripoint Hydraulic Set Packer 11 8,448’2.313”X Nipple 12 8,482’2.205”XN Nipple – Zone 3 (CLOSED, PXN set 3-16-15) 13 8,483’2.441”WLEG 14 8,964’6.276”Tripoint Packer Model ‘D’ 15 XO – 2 7/8” x 2 3/8” 16 8,978’1.795”2 3/8” XN Nipple – Zone 4 (CLOSED, XXN? plug in XN Nipple) 17 9,092’ Fish 1: TCP guns 88’ OAL Fish 2: Cut 2 7/8” tubing 6.5# 460’ OAL OPEN HOLE / CEMENT DETAIL 12-1/4"Est. TOC @ Surface. Spacer – 38 bbl 9.6 ppg. Lead - 281 bbl 12.5 ppg cement. Tail - 41 bbl 14.8 ppg cement. 125 bbls cement to surface. 8-3/4”CBL TOC @ 4,050’. 38.5 bbl spacer followed by 161 bbl 12.7 ppg lead cement and 99.5 bbl 13.5 ppg tail cement. CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor 93 K-55 Weld 14.88”Surf 120’ 9-5/8"Surf Csg 40 L-80 BTC 8.835”Surf 2,943’ 7"Intermediate Csg 26 L-80 GeoCon 6.276”Surf 9,725’ 2-7/8”Production Tubing 6.5 L-80 EUEM BTC 2.441”Surf 8,483’ 16” Conductor 7” Csg 12-1/4” hole 1 9-5/8” Csg 8-3/4” hole 3 4 5 6 7 8 9 10 11 12 & 13 14 15 16 RKB TO GL: 21’ 17 3/8” Capillary String Set @ 5,850’ MD Max Deviation – 24 deg @ 2,190’ MD All sleeves open DOWN. T-47 T-42 T-46 T-47 T-7 T-11 T-13 T-14 T-18 T-22 T-23 T-2 T-6 PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Status T-2 ±5,195' ±5,229' ±4,897' ±4,929' ±34' TBD Proposed T-2 5,196 5,204 4,898 4,906 8' Proposed Open- Zone 1 T-2 ±5,262 ±5,280 ±4,960 ±4,977 ±18' Proposed Open- Zone 1- Reperf T3 ±5,407' ±5,421' ±5,097' ±5,110' ±14' TBD Proposed T3 ±5,425' ±5,452' ±5,114' ±5,140' ±27' TBD Proposed T5 ±5,605' ±5,625' ±5,285' ±5,304' ±20' TBD Proposed T5 ±5,681' ±5,695' ±5,358' ±5,371' ±14' TBD Proposed T6 ±5,705' ±5,725' ±5,381' ±5,400' ±20' TBD Proposed T-6 5,765 5,800 5,438 5,471 35' Proposed Open- Zone 1- Reperf T-7 5,908 5,921 5,575 5,587 13' 12/5/2021 Open (reperf) - Zone 2- Reperf T-7 5,911 5,934 5,578 5,600 23' 2/15/2015 Open - Zone 2- Reperf T-7 5,921 5,941 5,587 5,607 20' 12/5/2021 Open (reperf) - Zone 2- Reperf T-7 5,934 5,940 5,600 5,606 6' 4/1/2020 Open - Zone 2 T-7 5,990 6,004 5,654 5,667 14' 2/15/2015 Open - Zone 2- Reperf T-11 6,310 6,326 5,967 5,982 16' 12/5/2021 Open (reperf) - Zone 2 T-11 6,310 6,340 5,967 5,996 30' 4/1/2020 Open - Zone 2 T-11 6,329 6,334 5,985 5,990 5' 12/4/2021 Open (reperf) - Zone 2 T-11 6,330 6,342 5,986 5,998 12' 12/1/2021 Open (reperf) - Zone 2 T-13 6,400 6,415 6,056 6,071 15' 4/1/2020 Open - Zone 2 T-14 6,435 6,450 6,091 6,106 15' 4/1/2020 Open - Zone 2 T-18 6,766 6,778 6,421 6,433 12' 12/5/2021 Open - Zone 2 T-22 7,027 (7,012) 7,034 (7,019) 6,682 6,689 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-22 7,034 (7,019) 7,041 (7,026) 6,689 6,696 7' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-23 7,177 (7,162) 7,185 ( 7,170) 6,832 6,840 8' 12/5/2021 Open - Zone 2 (Adjust perf depths up 15') T-42 8,497 8,523 8,147 8,179 26' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-46 8,804 8,812 8,459 8,467 8' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,917 8,932 8,589 8,600 15' 2/14/2015 Plugged - Zone 3 (Plug in XN) T-47 8,970 9,016 8,625 8,671 46' 2/14/2015 Plugged - Zone 4 (Plug in XN) Notes: There was an error in the depth tie in of original logging of the 24-26 LWD between Run 2 & Run 3. The result is that the original LWD log is 15' deeper that subsequent cased hole logs. STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. P. 0. Box 92593 Lafayette, Louisiana 70509 February 15, 2022 Transmittal Letter Ms. Meredith Guhl AOGCC 333 W. 7th Ave., Ste 100 Anchorage, Alaska 99501 Ref: Document Filing – AOGCC 214-166 – Vision Operating 24-26 NFU Dear Ms. Guhl, Per our conversation accompanying this Transmittal Letter are the following files for the referenced well: 1. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GPT 5in.pdf 2. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GPT 5in.tif 3. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GPT.las 4. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GR 5in.pdf 5. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GR 5in.tif 6. 502312004500 Vision Oper #24-26 NFU 26-4S-14W GR.las 7. 502312004500 Vision Oper #24-26 NFU 26-4S-14W Perf Rec 2021.las 8. 502312004500 Vision Oper #24-26 NFU 26-4S-14W Perf Rec 2021.pdf 9. 502312004500 Vision Oper #24-26 NFU 26-4S-14W Perf Rec 2021.tif Please indicate receipt of the listed files by signing in the space provided below and returning one copy to Vision Operating at the address shown above. If you have any questions regarding this transmittal, please contact me at my e-mail address scott@sevendog.net or by phone at (713) 299-4665. Sincerely, Scott M. Daniel Consulting Geologist Received by: ___________________________________ Date: _____________ ______________________________________ Date: ________________ By Meredith Guhl at 2:32 pm, Feb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y Samantha Carlisle at 12:51 pm, Jan 04, 2022 Claude Joseph Digitally signed by Claude Joseph Date: 2022.01.04 08:32:56 -06'00' SFD 1/6/2022 1RUWK)RUN7\RQHN*DV 3HUIUURUDWH DSR-1/4/22 3HUPLW WR 'ULOO 1XPEHU RBDMS HEW 1/4/2021 1RUWK)RUN8QLW WCB 10-20-2023 188 W. 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Northern Lights Blvd - Suite 515 Anchorage, AK 99503 ʹȁʹ 1RUWK)RUN2SHUDWLRQV6XPPDU\ 6XQGU\ 3HUIRUDWLRQ6XPPDU\ 3ODQQHGYV$FWXDO ±5HSHUI 5XQ 5XQ ±5HSHUI 'LGQRWVKRRW ±5HSHUI 5XQ ±5HSHUI 5XQ 5XQ ±1HZ 5XQ 5XQ ±1HZ 5XQ ±1HZ 'LGQRWVKRRW ±1HZ 5XQ &RQWLQXHSUHVVXUHEXLOGXS«SVLDQGFRQWLQXLQJWRULVH &RQFOXGHSUHVVXUHEXLOGXS)LQDO:+3SVL5XQWHPSSUHVVXUHORJ ZLWKZHOOIORZLQJ7DJIOXLG#¶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roposed Completion Schematic Version: Final 16" 93# K-55 120' MD ID 14.88" Welded 120' TVD TRSSSV @ +/-352 MD - ID 2.441" *TRSSSV is not operational due to cap string 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/8" 40# L-80 2943' MD ID 8.835" BTC 2818' TVD CBL EST TOC @ 4050' MD MD TVD 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 5765-5800 5438-5472 Zone 1 5911-5934 5578-5600 Zone 2 RA Tag @ 5077' MD 5908-5941 Zone 2 Reperf 5934-5940 5565-5571 Zone 2 Sliding Sleeve @ 5146' MD - ID 2.313" 5990-6004 5653-5668 Zone 2 Annular Sleeve - Closed - 4/6/2015 5990-6006 Zone 2 Reperf 6310-6340 5938-5968 Zone 2 Tripoint Hydraulic Set Packer @ 5161' MD 6310-6326 Zone 2 Reperf Sliding Sleeve @ 5188' MD - ID 2.313" 6329-6334 Zone 2 Reperf Zone 1 - Closed - 4/6/2015 **6330-6342 Zone 2 Reperf 6400-6415 6028-6043 Zone 2 Tripoint Hydraulic Set Packer @ 5873' MD 6435-6450 6063-6078 Zone 2 Sliding Sleeve @ 5904' MD - ID 2.313" 6766-6778 Zone 2 new Zone 2 - Open - Sliding Sleeve Open 7012-7026 Zone 2 new 7040-7047 Zone 2 new 7162-7170 Zone 2 new 8497-8523 8147-8179 Zone 3 3/8" Capillary Tube @ 6,450' MD 8804-8812 8459-8467 Zone 3 8917-8932 8589-8600 Zone 3 RA tag @ 8334' MD 8970-9016 8625-8671 Zone 4 * Red done in 2020, Blue-proposed Oct '21 Tripoint Hydraulic Set Packer @ 8404' X Nipple @ 8,448' Tripoint - ID 2.313" 2 7/8"6.5# L80 EUEM 8483' MD XN Nipple @ 8,482' MD - ID 2.205" ID - 2.441" BTC 8138' TVD Wire Line re-entry guide @ 8483' MD Zone 3 - Closed - Plug in XN Nipple Tripoint Packer Model D Set @ 8964' MD 2-7/8" X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" intervals perforated 321-555 Zone 4 - Closed - Plug in XN Nipple Est. TOF @ 9092' MD Fish 1 TCP guns 88' long Fish 2 Cut 2 7/8 tubing 6.5# 460' long PBTD @ 9640' MD 9295' TVD TD at 9,750' MD / 9,404' TVD 7"26# L80 EUE 9,725' MD ID - 6.276" GeoCon 9,379' TVD 8 3/4" Hole December 2021 16" Conductor 12 1/4" Hole PERFORATIONS All Sliding Sleeves Open Down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his WBS has been superseded by a replacement WBS sent by Vision. -WCB 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: 188 W. Northern Lights Blvd Suite 515 Stratigraphic Service 6.API Number: Anchorage, AK 99503 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?CO 705 CO 720 26 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): Tyonek Gas 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9750 9404 9750 9404 2269 286 / 8483 NA Casing Collapse Structural Conductor N/A Surface 3090 Intermediate Production 5410 Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See WBD See WBD 12. Attachments: Proposal Summary Wellbore schematic 13. W ell 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:Tom Maunder, P.E. Claude Joseph Contact Email: stmaunder@aol.com Contact Phone: 907-529-1645 Authorized Title: VP Reserves, Vision Operating, LLC Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See WBD 9750 See WBD 2-7/8" 2496 9750 Perforation Depth MD (ft): 20" 9-5/8" 120 120 2496 94047" Length Size 6.5# L-80 EUE TVD Burst 8483 7240 MD N/A 5750 120 2821 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391211 North Fork 214-166 50-231-20045-00-00 Vision Operating, LLC North Fork Unit 24-2 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 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: AOGCC USE ONLY P 2 6 5 6 t _ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:49 pm, Oct 22, 2021 321-555 Claude Joseph Digitally signed by Claude Joseph Date: 2021.10.22 16:30:36 -05'00' Pressure test wireline lubricator and pressure control equipment to 2500 psi minimum Nov. 15, 2021 10-404 BJM 10/25/21 SFD SFD 10/22/2021 DSR-10/25/21 dts 10/27/2021 JLC 10/27/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.27 10:58:26 -08'00' RBDMS HEW 10/28/2021 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 Well Name – NFU 24-26 (214-166) Well Summary Current Status: Well shut-in due to no flow. Well History: North Fork Unit (NFU) was drilled in 2014 to increase rate and further develop reserves in this small tertiary gas field. The well was placed in production in January 2015 produced essentially continuously until April 2019 producing some 1.23 BCF and ~700 bw. Due to increasing water production, a small diameter capillary string was installed in 2Q 2017 to improve produced water removal. Since shut-in, despite adding new perforations production has not been reestablished although it appears that all planned work was not completed. This work will include wellbore diagnostics designed to determine inflow to the wellbore as well as perforating/reperforating selected zones and reinstalling the capillary string. Scope of Work Pull tubing plug Conduct SI production logs Conduct Flowing production logs Add Perforations / Reperf Run capillary string Rig down General Well Information Reservoir Pressure / TVD 2954 psi @ 7185’ MD / 6813’ TVD MASP 2269 psi Wellhead Type / Pressure Rating Vetco Gray – 5M Wellhead Assembly BOP Configuration Slickline / Eline WLV Well Type Gas Producer Estimated Start Date November 15, 2021 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 Operation Procedure 1. Pull tubing plug at 257’. 2. Drift tubing to PBTD at 8482’. 3. RU and conduct SI production logs. 4. RU and conduct flowing production logs. 5. Evaluate production logs. 6. Perforate / reperforate intervals as follows… 5910 – 5943 Reperf 5990 – 6006 Reperf 6320 – 6325 Reperf 6328 – 6340 Reperf 6768 – 6780 New 7025 – 7032 New 7040 – 7047 New 7178 – 7186 New 7. Rig up Spooler 8. Install capillary string to 6450’. 9. Turn well over to Production. Pressure test wireline pressure control equipment to minimum 2500 psi. bjm NFU 24-26 Proposed Completion Schematic Version: Oct '21 16" 93# K-55 120' MD ID 14.88" Welded 120' TVD TRSSSV @ +/-352 MD - ID 2.441" *TRSSSV is not operational due to cap string 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/8" 40# L-80 2943' MD ID 8.835" BTC 2818' TVD CBL EST TOC @ 4050' MD MD TVD 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 5765-5800 5438-5472 Zone 1 5911-5934 5578-5600 Zone 2 RA Tag @ 5077' MD 5934-5940 5565-5571 Zone 2 5910-5943 Zone 2 Reperf Sliding Sleeve @ 5146' MD - ID 2.313" 5990-6004 5653-5668 Zone 2 Annular Sleeve - Closed - 4/6/2015 5990-6006 Zone 2 Reperf 6310-6340 5938-5968 Zone 2 Tripoint Hydraulic Set Packer @ 5161' MD 6320-6325 Zone 2 Reperf Sliding Sleeve @ 5188' MD - ID 2.313" 6328-6340 Zone 2 Reperf Zone 1 - Closed - 4/6/2015 6400-6415 6028-6043 Zone 2 6435-6450 6063-6078 Zone 2 Tripoint Hydraulic Set Packer @ 5873' MD 6768-6780 Zone 2 new Sliding Sleeve @ 5904' MD - ID 2.313" 7025-7032 Zone 2 new Zone 2 - Open - Sliding Sleeve Open 7040-7047 Zone 2 new 7178-7186 Zone 2 new 8497-8523 8147-8179 Zone 3 8804-8812 8459-8467 Zone 3 3/8" Capillary Tube @ 6,450' MD 8917-8932 8589-8600 Zone 3 8970-9016 8625-8671 Zone 4 RA tag @ 8334' MD * Red done in 2020, Blue-proposed Oct '21 Tripoint Hydraulic Set Packer @ 8404' X Nipple @ 8,448' Tripoint - ID 2.313" 2 7/8"6.5# L80 EUEM 8483' MD XN Nipple @ 8,482' MD - ID 2.205" ID - 2.441" BTC 8138' TVD Wire Line re-entry guide @ 8483' MD Zone 3 - Closed - Plug in XN Nipple Tripoint Packer Model D Set @ 8964' MD 2-7/8" X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" Zone 4 - Closed - Plug in XN Nipple Est. TOF @ 9092' MD Fish 1 TCP guns 88' long Fish 2 Cut 2 7/8 tubing 6.5# 460' long PBTD @ 9640' MD 9295' TVD TD at 9,750' MD / 9,404' TVD 7"26# L80 EUE 9,725' MD ID - 6.276" GeoCon 9,379' TVD 8 3/4" Hole May 4, 2020 16" Conductor 12 1/4" Hole PERFORATIONS All Sliding Sleeves Open Down 2 M S A 3 R NFU 24-26 Final Completion Schematic Version: V1 AD2 stop, packoff, & A stop set at 287' WLM 16" 93# K-55 120' MD ID 14.88" Welded 120' TVD TRSSSV @ +/-352 MD - ID 2.441" *TRSSSV is not operational due to cap string 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/8" 40# L-80 2943' MD ID 8.835" BTC 2818' TVD CBL EST TOC @ 4050' MD MD TVD 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 5765-5800 5438-5472 Zone 1 5911-5934 5578-5600 Zone 2 RA Tag @ 5077' MD 5934-5940 5565-5571 Zone 2 new 5990-6004 5653-5668 Zone 2 Sliding Sleeve @ 5146' MD - ID 2.313" 6310-6340 5938-5968 Zone 2 new Annular Sleeve - Closed - 4/6/2015 6400-6415 6028-6043 Zone 2 new 6435-6450 6063-6078 Zone 2 new Tripoint Hydraulic Set Packer @ 5161' MD 8497-8523 8147-8179 Zone 3 Sliding Sleeve @ 5188' MD - ID 2.313" 8804-8812 8459-8467 Zone 3 Zone 1 - Closed - 4/6/2015 8917-8932 8589-8600 Zone 3 8970-9016 8625-8671 Zone 4 Tripoint Hydraulic Set Packer @ 5873' MD Sliding Sleeve @ 5904' MD - ID 2.313" Zone 2 - Open - Sliding Sleeve Open RA tag @ 8334' MD Tripoint Hydraulic Set Packer @ 8404' X Nipple @ 8,448' Tripoint - ID 2.313" 2 7/8"6.5# L80 EUEM 8483' MD XN Nipple @ 8,482' MD - ID 2.205" ID - 2.441" BTC 8138' TVD Wire Line re-entry guide @ 8483' MD Zone 3 - Closed - Plug in XN Nipple Tripoint Packer Model D Set @ 8964' MD 2-7/8" X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" Zone 4 - Closed - Plug in XN Nipple Est. TOF @ 9092' MD Fish 1 TCP guns 88' long Fish 2 Cut 2 7/8 tubing 6.5# 460' long PBTD @ 9640' MD 9295' TVD TD at 9,750' MD / 9,404' TVD 7"26# L80 EUE 9,725' MD ID - 6.276" GeoCon 9,379' TVD May 4, 2020 16" Conductor 12 1/4" Hole All Sliding Sleeves Open Down 8 3/4" Hole PERFORATIONS 2 M S A 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: __Pull Cap String/Set plug___ 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 9750 feet None feet true vertical 9404 feet None feet Effective Depth measured 9640 feet see schematic feet true vertical 9404 feet see schematic feet Perforation depth Measured depth 5196 - 9016 feet True Vertical depth 4898 - 8671 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# L80 EUE 8483' MD 8138' TVD Packers and SSSV (type, measured and true vertical depth)SSSV- 352' 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 Contact Phone:907-433-3808 9750 WINJ WAG 0 Water-Bbl MD 120 2946 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 24-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-166 50-231-20045-00-00 4. Well Class Before Work: ADL 391211 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-027 232 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 100 Authorized Signature with date: Authorized Name: 100 Casing Pressure Liner 5. Permit to Drill Number: 0 North Fork Tyonek GasNone measured 9750 Conductor Surface Intermediate Production Casing Structural 20" 9 5/8" Length 120 2946 120 2821 9404 5410 Burst N/A 5750 7240 COOK INLET ENERGY LLC 2. Operator Name Senior Engineer:Senior Res. Engineer: Collapse N/A 3090 Plug Perforat PerforaPf Perforate New PoPerforateNewPo fter w Fr 4 W Other: _ 5 Permit to Dr Other: Explora ServSer SPLUG t G k: Ga SUS Stratigraphic WD o Status afte W Re-en e W ork: Re en 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 10:31:24 -08'00' By Samantha Carlisle at 3:35 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 24-26 Permit to Drill NO: 214-166 API No: 50-231-20045-00-00 Dear Mr. Price, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for NFU 24-26. The work performed was covered under Approved Sundry 320-027 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 10:31:05 -08'00' 2 | Page NFU 24-26 Daily Operations Summary API: 50-231-20045-00-00 PTD#: 214-166 Date Activity 31 March 2020 RU Dyna-coil unit and POH with 3/8” capillary string. RD unit. 01 April 2020 RU Eline. RIH w/2.25” GR to 6773’ – no issues), POH. RIH with gun run #1: 15ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6435’-6460’– all shots fired. RIH with gun run #2: 15ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6400’-6415’– all shots fired. RIH with gun run #3: 30ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 6310’-6340’ – all shots fired. RIH with gun run #4: 6ft of 2” (4 spf, 60 deg phase). Correlate on depth and shoot 5934’-5940’ – all shots fired. RIH and check fluid level – 969’. RD Eline. Secure well. 02 April 2020 RU Slickline. RIH w/2.44” swab cups and make multiple runs. Drop fluid level from 969’ to 3910’. RD for night and secure well. 03 April 2020 RU Slickline. RIH w/2.44” swab cups and make multiple runs. Drop fluid level from 3910’ to 4800’. Swab cups damaged and unable to recover any additional fluid. RD Slickline. Turn well over to Production for monitoring. 10 April 2020 RU Slickline. RIH w/brush to 400’. RIH w/plug and set in top profile of SSSV at 357’. RIH and set prong at same depth. RD Slickline. Secure well. 14 April 2020 RU Slickline. RIH and pull prong and plug from SSSV at 357’. Plug was not holding pressure. RIH w/brush to 5200’ and clean sliding sleeve profile at 5132’ WL. POH. Bleed WHP down for negative test – plug not holding. RIH and pull plug at 5132’ WL. RIH w/AD2 stop and set at 287’ WL (just above SSSV). RIH w/packoff and set at 286’ WL. RIH and set “A” stop on packoff. RD Slickline. Monitor well. Confirm plug is holding. Release Slickline. Secure well. NFU 24-26 Actual Wellbore Schematic Version: Current AD2 stop, packoff, & A stop set at 287' WL. 16" 93# K-55 120' MD ID 14.88" Welded 120' TVD TRSSSV @ +/-352 MD - ID 2.441" *TRSSSV is not operational due to cap string 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/8" 40# L-80 2943' MD ID 8.835" BTC 2818' TVD CBL TOC @ 4050' MD RA Tag @ 5077' MD Sliding Sleeve @ 5146' MD - ID 2.313" Annular Sleeve - Closed - 4/6/2015 Tripoint Hydraulic Set Packer @ 5161' MD Sliding Sleeve @ 5188' MD - ID 2.313" MD TVD Zone 1 - Closed - 4/6/2015 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 Tripoint Hydraulic Set Packer @ 5873' MD 5765-5800 5438-5472 Zone 1 Sliding Sleeve @ 5904' MD - ID 2.313" 5911-5934 5578-5600 Zone 2 Zone 2 - Open - Sliding Sleeve Open 5934-5940 5565-5571 Zone 2 new 5990-6004 5653-5668 Zone 2 6310-6340 5938-5968 Zone 2 new 6400-6415 6028-6043 Zone 2 new 6435-6450 6063-6078 Zone 2 new 8497-8523 8147-8179 Zone 3 RA tag @ 8334' MD 8804-8812 8459-8467 Zone 3 8917-8932 8589-8600 Zone 3 Tripoint Hydraulic Set Packer @ 8404' 8970-9016 8625-8671 Zone 4 X Nipple @ 8,448' Tripoint - ID 2.313" XN Nipple @ 8,482' MD - ID 2.205" Wire Line re-entry guide @ 8483' MD 2 7/8"6.5# L80 EUEM 8483' MD Zone 3 - Closed - Plug in XN Nipple ID - 2.441" BTC 8138' TVD Tripoint Packer Model D Set @ 8964' MD 2-7/8" X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" Zone 4 - Closed - Plug in XN Nipple Est. TOF @ 9092' MD Fish 1 TCP guns 88' long Fish 2 Cut 2 7/8 tubing 6.5# 460' long PBTD @ 9640' MD 9295' TVD TD at 9,750' MD / 9,404' TVD 7"26# L80 EUE 9,725' MD ID - 6.276" GeoCon 9,379' TVD 8 3/4" Hole May 4, 2020 16" Conductor 12 1/4" Hole PERFORATIONS All Sliding Sleeves Open Down T * 2 A THE STATE °fALASKA 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, Tyonek Gas Pool, NFU 24-26 Permit to Drill Number: 214-166 Sundry Number: 320-027 Dear Mr. Ratcliff: Alaska Cil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.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 [i!/day of January, 2020. RBDMS I JAN 2 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on nnr 25 ovn JAN 17 P7 -S 11 Zz_ (2-0 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull/Run capillary strinE- 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development El 1 Slraligraphic ❑ Service ❑ 214-166 ' 3. Address: 6. API Number: 188 W. Northern Lights Blvd, Suite 510, Anchorage, AK, 99503 50-231-20045-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 705 & CO 720 Will planned perforations require a spacing exception? Yes No North Fork Unit 24-26 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 391211 l Zt North Fork Tyonek 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): 9750' MD 9404' TVD 9750' MD 9404' TVD 2269 psi None None Casing Length Size MD TVD Burst Collapse Structural 120' 20" 120' 120' N/A N/A Conductor -- __ -- _ Surface 2946 9 5/8" 2946 2821 5750 3090 Intermediate -- -- __ Production 9725 7" 9725 19379 7240 1 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# L80 EUE 9026 Packers and SSSV Type: 2 x HES Hyd. Rett. PHIL Packer Packers and SSSV MD (ft) and TVD (ft):5194' MD/4896' TVD; 5851' MD /5497' TVD 1 x olgoonik DHL Packer 8415' MD / 8069' TVD 12. Attachments: Proposal Summary R Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Stiatigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations2/1/2020 : ❑ WINJ ❑ WDSPL ❑ OIL 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 `^l Contact Phone: 907-433-3808 Authorized Signature: Lam- Date: 1111120 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS!Lf�JJAN 2 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Ex ion Required? Yes No d Subsequent Form Required: lo_y�,y APPROVED VSI Approved by: COMMISSIONER THE COMMISSION Date: /' F 1 Y 1ozZ-Zo ,�spr IGINAi. bmil Form and [7 Form 10-403 sed 4/201 Approve application is valid for 12 months from the date of ap r tt nts in Duplicate 4 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 24-26 API: 50-231-20045-00-00 Dear Commissioner, Cook Inlet Energy (CIE) hereby submits a Sundry Application for NFU 24-26, PTD: 214-166 to move the placement of the capillary string and 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 GLACIER WELL NAME — NFU 24-26 Requirements of 20 AAC 25.005(f) Well Summary Current Status: Currently shut-in due to no flow. Scope of Work: • Rig up Spooler. • Pull capillary string. • Rig Up Eline. • Add Perforations. • Run capillary string. • Rig down. General Well Information: Reservoir Pressure / TVD: MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 2954 psi @ 7185' MD / 6813' TVD 2269 psi Vetco Gray -5M - Wellhead Assembly Eline WLV Gas Producer February 1, 2020 2 GLACIER 1. Operational Procedure Requirements of 20 AAC25.005 (c)(13) 1. Rig up Spooler. 2. Pull out of hole with capillary string. 3. Rig up Eline. 4. RIH with 2", 4 spf, 60 deg phase perforating guns and perforate the following intervals from bottom to top: NFU 24-26 — Perf Intervals Top MD Base MD Footage Top TVD Base TVD Notes 5934 5940 6 5565 5571 New Interval 6310 6340 30 5938 5968 New Interval 6400 6415 15 6028 6043 New Interval 6435 6450 15 6063 6078 New Interval 6512 6520 8 6140 6148 New Interval 6767 6780 13 6395 6408 New Interval 7024 7030 6 6652 6658 New Interval 7038 7045 7 6666 6673 New Interval 7178 7185 7 6806 6813 New Interval Total = 107 ft 5. Rig down Eline. 6. Rig up Spooler. 7. RIH with capillary string and place at 5900 ft. 8. Turn well over to Production. 3 Zen f 2-1 NFU 24-26 Final Completion Schematic Version: Current Cook Inlet Energy_ June 21, zon 16" Conductor 12 1/4" Hole CBL TOC @4059 MD PJI Sliding Sleeves Open Dwn J 2718" 6.8N LBO EUEM 8483'MD ID -2.441" BTC 8138'TVD 8 3/4" Hole PBTD 9840' MD 9295' TVD TD .19,75' MD / 9,404' TVD 7 PERFORATIONS MD TVD 51965204 4898-4906 Zone 1 5262-5280 49664977 zone 57665800 5438-5472 Zone 1 5911-5934 557&5000 Zone 5990-6004 5653-5668 Zone 2 8497-8523 8147-8179 Zone 88048812 8459-8467 Zone 3 8917-8932 8588-8FA0 Zone 3 8970.9016 66258671 Zone4 2718" 6.8N LBO EUEM 8483'MD ID -2.441" BTC 8138'TVD 8 3/4" Hole PBTD 9840' MD 9295' TVD TD .19,75' MD / 9,404' TVD 7 _ Cook Inlet Energy_ 76" Conductor 12 1/4" Hole CBL TOC @ 4050' MD 2718" .6# L80 EUE 8483' MD ID- 2.441" BTC I 8138'TVD 8 3/4" Hole NFU 24-26 Proposed Completion Schematic Version: V1 January 8, 2020 16" 1 93# K-55120' MD ID 14.88" Welded 120' ND TRSSSV @ +/-352 MD - ID 2,441" 'TRSSSV is not operational due to cap slnng 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/B" 40# L-80 2943' MD ID 8.835" BTC 2818' ND All Sliding Sleeves Open Down RA Tag @ 5077' MD Sleeve @ 5146' MD - Tripoint Hydraulic Set Packer @ 5161' MD Sliding Sleeve @ 5188' MD - ID 2.313" PERFORATIONS MD ND 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 5765-5800 5438-5472 Zone 1 5911-5934 5578-5600 Zone 2 5934-5940 5565-5571 Zone 2 new 5990-6004 5653-5668 Zone 6310-6340 5938-5968 Zone 2 new 6400-6415 6028-6043 Zone 2 new 6435-6450 6063-6078 Zone 2 new 6512-6520 6140-6148 Zone 2 new 6767-6780 6395-6408 Zone 2 new 7024-7030 6652-6658 Zone 2 new 7038-7045 6666-6673 Zone 2 new 7178-7185 6806-6813 Zone 2 new 8497-8523 8147-8179 Zone 3 8804-8812 8459-8467 Zone 3 8917-8932 8589-8600 Zone 3 8970-9016 8625-8671 Zone4 2718" .6# L80 EUE 8483' MD ID- 2.441" BTC I 8138'TVD 8 3/4" Hole NFU 24-26 Proposed Completion Schematic Version: V1 January 8, 2020 16" 1 93# K-55120' MD ID 14.88" Welded 120' ND TRSSSV @ +/-352 MD - ID 2,441" 'TRSSSV is not operational due to cap slnng 2 7/8" Chemical Injection Mandrel @ +/- 2524' MD - ID 2.441" 9 5/B" 40# L-80 2943' MD ID 8.835" BTC 2818' ND All Sliding Sleeves Open Down RA Tag @ 5077' MD Sleeve @ 5146' MD - Tripoint Hydraulic Set Packer @ 5161' MD Sliding Sleeve @ 5188' MD - ID 2.313" -21,1111111111, —FNipple raulic Set Packer @ 8404' �- 8,446' Tnpaint- ID 2.313" @ 8,482' MD -ID 2.205" -entry guide @ 8483' MD Zone 3 - Closed - Plug in XN Nipple Tripoint Packer Model D Set @ 8964' MD 2-7/8"X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" Zone4- Closed -Plug in XN Nipple Es" TOF @ 9092' MD _ Fish 1 TCP guns 88' long iI IFish2 Cult 7/8 tubing 6.5#460' long PBTD @ 9640' MD 9295' ND TD at 9,750' MD / 9,404' ND Tripoint Hydraulic Set Packer @ 5873' MD (2-) Sliding Sleeve @ 5904' MD - ID 2.313" Zone 2 - Open - Sliding Sleeve Open :1111a 318 " Capillary Tube @5,900'MD -21,1111111111, —FNipple raulic Set Packer @ 8404' �- 8,446' Tnpaint- ID 2.313" @ 8,482' MD -ID 2.205" -entry guide @ 8483' MD Zone 3 - Closed - Plug in XN Nipple Tripoint Packer Model D Set @ 8964' MD 2-7/8"X/O 2-3/8" 2 3/8" XN Nipple @ 8978' MD - ID 1.795" Zone4- Closed -Plug in XN Nipple Es" TOF @ 9092' MD _ Fish 1 TCP guns 88' long iI IFish2 Cult 7/8 tubing 6.5#460' long PBTD @ 9640' MD 9295' ND TD at 9,750' MD / 9,404' ND STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Install Cap.String&Move SSvn 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Cook Inlet Energy,LLC Development ❑✓ Exploratory ❑ 214-166 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic ❑ Service ❑ 6.API Number: 99501 50-231-20045-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL 391211 North Fork Unit 24-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 1 North Fork Tyonek Gas JUL 1 3 2017 11.Present Well Condition Summary: AOGCC Total Depth measured 9750 feet Plugs measured N/A feet true vertical 9404 feet Junk measured 9092 feet Effective Depth measured 9640 feet Packer measured 5161,5873,8404,8964 feet true vertical 9295 feet true vertical 4896,5497,8069,8058 feet Casing Length Size MD TVD Burst Collapse Structural 120 20" 120' 120' Conductor Surface 2946 9 5/8" 2943' 2818' 5750 3090 Intermediate Production 9725 7" 9725' 9379' 7240 5410 Liner JUL3 1r�}i Perforation depth Measured depth 5196-9016 feet �('e��E® J 2 L j7 True Vertical depth 4898-8671 feet w� Tubing(size,grade,measured and true vertical depth) 2 7/8" 6.5#L80 EUE 8483'MD 8137'TVD Packers and SSSV(type,measured and true vertical depth) 3 Hyd Retr Packers 5161',5873',8404'MD 4896',5497',8069'TVD 1 Model D Packer 8964'MD 8058'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 826 0.3 200 65 Subsequent to operation: 0 737 0 195 80 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-225 Authorized Name: David Kumar Contact Name: David Kumar Authorized Title: Production Manager Contact Email: dkumar@glacieroil.com Authorized Signature: U4:; ---'------\ ' Date:X)11-.---\- /1 ----, Contact Phone: 907-433-3822 Form 10-404 Revised 4 2017 ' 7f0,7 RBDMS U JUL 1 4 2017 Submit Original Only • GLACIER RECEIVED July 12th, 2017 Mr. Hollis S. French, Chair JUL 13 201? Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Ac Anchorage,Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: NFU 24-26 Permit to Drill NO:214-166 API No: 50-231-20045-00-00 Dear Mr. French, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for NFU 24-26. The work performed was covered under Approved Sundry 317-225 for installing a 3/8" capillary string in the production tubing. If you have any questions, please contact me at (907)433-3808. Sincerely, Davi Kumar Production Manager Cook Inlet Energy, LLC (a Glacier Oil &Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage,AK 99501 10-404 i GLACIER NFU 24-26 Daily Operations Summary API: 50-231-20045-00-00 Permit #: 214-166 Date Activity 14 June 2017 Set TWC. ND flowline and swapped out upper master actuated valve with wing valve. NU Flowline.Tested tree to 5000 psi—good. Pulled TWC. RU Slickline. RIH with 2.25" GR to 8100' MD, POH. RD Slickline. 18 June 2017 RU to run Capillary String. Test FCV Opens at 4000 psi—good. RIH with Capillary string to 8000' MD. Hang off capillary string. Pump through string, 2200 psi. RD. *FU 24-26 Final Completion Schematic • Version: Current Cook Inlet Energy_ June 21,2017 L.16"Conductor .` Y -r 16" 93#K-55 120'MD Al ID 14.88" Welded 120'TVD ' _ � TRSSSV @+/-352 MD-ID 2.441" , "TRSSSV is not operational due to cap string 4' 2 7/8"Chemical Injection f ,r Mandrel @+/-2524'MD-ID 2.441" f. ,, 12 1/4"Hole 9 5/8" 40#L-80 2943'MD ID 8.835" BTC 2818'TVD CBL TOC @ 4050'MD � ' MI 4K' , —.._.._,,.... RA Tag @ 5077'MD All Sliding Sleeves Open Down , —.•ISliding Sleeve @ 5146'MD-ID 2.313" + 4_.; Annular Sleeve-Closed-4/6/2015 - < Tripoint Hydraulic Set Packer @ 5161'MD PERFORATIONS } r- Sliding Sleeve @ 5188'MD-ID 2.313" MD TVD Zone 1-Closed-4/6/2015 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 111 .=- Tripoint Hydraulic Set Packer @ 5873'MD 5765-5800 5438-5472 Zone 1 Sliding Sleeve @ 5904'MD-ID 2.313" 5911-5934 5578-5600 Zone 2 " Zone 2-Open-Sliding Sleeve Open 5990-6004 5653-5668 Zone 2 8497-8523 8147-8179 Zone 3 Q 8804-8812 8459-8467 Zone 3 TT 8917-8932 8589-8600 Zone 3 - 3/8"Capillary Tube @ 8,000'MD -8970-9016 8625-8671 Zone 4 •1 NM , .-[RA tag @8334'MD - Tripoint Hydraulic Set Packer @ 8404' i X Nipple @ 8,448'Tripoint-ID 2.313" 2 718" 6.5#L80 EUEN 8483'MD ``.1- it '(.1�I XN Nipple @ 8,482'MD-ID 2.205" ID-2.441" BTC 8138'TVD g'-tit-.;.fes Wire Line re-entry guide @ 8483'MD a 3= Zone 3-Closed-Plug in XN Nipple a a t Tripoint Packer Model D Set @ 8964'MD 3,- 1 —� 2-7/8"X/O 2-3/8" tI et 2 3/8"XN Nipple @ 8978'MD-ID 1.795" �r1= Zone 4-Closed-Plug in XN Nipple liEst. 'MD ng Fish 1TOF TCP@ guns909288'lo "1 ' Fish 2 Cut 2 7/8 tubing 6.5#460'long PBTD @ 9640'MD 9295'TVD TD at 9,750'MD/9,404'TVD 8 3/4"Hole 7" 26#L80 EUE 9,725'MD ID-6.276" GeoCon 9,379'TVD • • S • •106 GE Oil & Gas I 47.7 0 11.1M III.t_u1 i rn r--. —a i- 30.2- ON�co 55 2-9l,8"5M .0 = � a .::r 218'5M 1 - / ( 7 I ] 1 \ 11,4 .. ;,AY j at r.r_r•t 2-9/18 5M 2-9,18"5M '14' o. 4uAupulwi 45.8' , 2-9116"SM i O :` 1272' ''a'" i 11'5M -T+��''"j IN �F='+ -1 c.-1.-3�.__i�"1_^1 5 ' - — - , • �I S-I{I 2&5'to I. 19.0' -- f A/` N! • -;YE 11*5M rf J 2-1118'SM I■ { RA l 283"Oo4 it I '.i 1. L i � . _ S. Irl 9i�, ( Ill: '. -:'11-.A r �� 31 7" :r ' - • 4 r♦ .._ 2-1118'5M iii I i �I zc OD.Base Piste I 1}] 'i, r:-29-5/8'Casing qi._I I. 7"Casing 2-718'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 ENERGY 24-26 neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE OA&Gas Pressure Control LP. 9-5/8" x 7" x 2-7/8" 5M SH2 Wellhead Assembly, DRAWN CR 20NOV14 APPRV KN 20NOV14 With T-M40-CCL Tubing Hanger and M40-CCLAdapter Flange FOR REFERENCE ONLY • DRAWING NO. 1001107-1B SOF T� • • S ge\\\Vyy�, THE STATE Alaska Oil and Gas ofLASKA Conservation Commission kIf Sir#=__ 333 West Seventh Avenue -7 i Anchorage, Alaska 99501-3572 h GOVERNOR BILL WALKER g °P Main: 907.279.1433 AL • s' Fax: 907.276.7542 www.aogcc.alaska.gov David Kumar scoria r 1`g Production Manager � ` Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: North Fork Field, Tyonek Gas Pool,NFU 24-26 Permit to Drill Number: 214-166 Sundry Number: 317-225 Dear Mr. Kumar: 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, 031",47Pa.4.i/hL, Cathy P. Foerster Chair DATED this IZ a of June, 2017. RBDMS L - JUN 1 3 2017 0 • RECEIVED STATE OF ALASKA JUN 01 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 111.Type of Request: Abandon Plug Perforations❑ Fracture Stimulate u Repair Well uOperations shutdownu Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool 8 Re-enter Susp Well Alter Casing a Other: Install Capillary Str • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: E 1,401,(c: �✓ Cook Inlet Energy,LLC Exploratory Development 214-166 ' 3.Address: Stratigraphic 8 I Service ® 6.API Number: 74 - 601 W.5th Avenue,Suite 310,Anchorage,AK,99501 50-231-20045-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO705 J 7ZU North Fork Unit 24-26 ' Will planned perforations require a spacing exception? Yes No u CC,'S= r 7 9.Property Designation(Lease Number): 10.Field/Pool(s): -T',r,,1.2-4, .6 4. > (7 ADL 391211 ' North Fork CIeftfed 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): 9750 9404 9750 9404 None None Casing Length Size MD TVD Burst Collapse Structural 120 20" 120' 120' Conductor Surface 2946 9 5/8" 2946 2821 5750 3090 Intermediate Production 9725 7" 9725 9379 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#L80 EUE 9026 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 2 x Halliburton Hydraulic Retr.PHL Packer,1 Olgoonik DHL Packer 5194',5,851',8415'MD/4896',5497',8069'TVD 12.Attachments: Proposal Summary IXI Wellbore schematic IDI 13.Well Class after proposed work: Detailed Operations Program I I BOP Sketch I I Exploratory I Stratigraphic I I Development DCI Service I I 14.Estimated Date for 7-Jun-17 15.Well Status after proposed work: Commencing Operations: OIL El WINJ WDSPL Suspended p 16.Verbal Approval: Date: GAS ® WAG u GSTOR 8 SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 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: David Kumar David Kumar Contact Name: Authorized Title: Production Myger 1 ' Contact Email: dkumarglaCieroil.Com Contact Phone: 907 433 3822 Authorized Signature: ( Date: COMMISSION USE ONLY Conditions of approval: Notify Commfls on so that a representative may witness Sundry Number: !// 3 \-7- 22� Plug Integrity ❑ i,JBOP Test EIMechanicalIntegrity Test ❑i Location Clearance ❑ F— Z f"�i � 'I1l Other: V) p(k.c_ �j an h a r..g L c:.:� "- ` -'C fed...`.,, r'°1 Z i A4c- -5-6 a-6 /1.. ) 0 C Post Initial Injection MIT Req'd? Yes ❑ No 1:14 Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /0 '18 ai / APPROVED BY Approved by: i7 '/ __ COMMISSIONER THE COMMISSION Date: ‘.�/Z 7 7 -� .- l 7 Submit Form and Form 10-403 Revised 4/2017 Appr ed application is valid for 12 months from the date of approval. Attachments in Duplicate % ,Ari 0RIGINpk RBDMS L�JUN 1 3 2017 / -' - - (7 • • Cook Inlet Energy_ RECEIVED J U N 01 2017 June 1, 2017 AO GCC 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 24-26 API: 50-231-20045-00-00 Permit to Drill: 214-1660 Dear Mr. Schwartz, Cook Inlet Energy (CIE) proposes to install a 3/8" capillary string in the production ' tubing of North Fork Unit 24-26 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 8,000' 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 theLubsur`face safety valvelpe locked out and remain inactive due to the capillary string. 5.--;"11 (,� 1,Srt r' Please contact me at (907) 433-3822 if you have any questions ' ) Sincerely, � ` tv3 (34j-I \?( e, Dav Umar Pro uction Manager Cook Inlet Energy Attachments: Sundry Application • _ ` Cook Inlet Energy_ June 7, 2017 RECEIVED JUN 08 2017 Mr. Guy Schwartz, AOGCC 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 24-26 API: 50-231-20045-00-00 Permit to Drill: 214-1660 Additional Information Supporting Sundry Application Dear Mr. Schwartz, Cook Inlet Energy (CIE) previously submitted a Sundry application on June 1, 2017 to install a 3/8" capillary string in the production tubing of North Fork Unit 24-26 well. The installed capillary string will impact operations of the surface safety valve in additional to the subsurface safety valve. CIE requests a variance for regulation 20 AAC 25.265 (c) (1) that requires the surface safety valve to be located in the vertical ` run of the tree. CIE will move the surface safety valve to the horizontal run of the V tree to ensure its operability. This tree modification will be conducted before the actual installation of the capillary string. A procedure is included for the Commission to review Please contact me at (907) 433-3822 if you have any questions Sincerely, 0,1J-eXA\ r Dav'd Kuma • Pro uction Manager Cook Inlet Energy Attachments: Surface Safety Valve Location Work Procedure S . NFU 24-26 Surface Safety Valve Location Work Wellhead Work 1. Rig up lubricator � v.7 Tp"` ��r.�� 2. Set 2 way check valve frx.e_" • 6 t?...-- 1-7 L17 3. Close lower master 4. Rig down lubricator 5. Nipple down tree (Actuated upper master,tee, swab valve and wing valves) 6. Nipple up tree swapping actuated valve with 2nd wing valve 7. Shell test tree 8. Rig up lubricator 9. Pull 2 way check valve 10. Rig down lubricator 11. Perform a function test on the surface safety valve 1 • NFU 24-26 Ca I illa Strin. 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 Capillary String Work 1. Perform onsite Safety/Job site review meeting and review/update HRA 2. Capillary crew to set up ground protection for truck location 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 containing a downhole fluid control valve to the desired bottom hole depth of 8,000�'�N II, 21.Once capillary 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 • 0 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 ••NFU 24-26 Current Schematic Version: Current - Cook Inlet Energy_ March 15,2017 j --7 — 7. 4,4 16"Conductor 16" 93#K-55 120'MD ID 14.88" Welded 120'TVD '„ .# <. - TRSSSV @+/-352 MD-ID 2.441" 0 ,,.- ,,,,,A ,,-2 7/8"Chemical Injection Mandrel @+/-2524'MD-ID 2.441" 12 1/4"Hole • J1111 9 5/8" 404 L-80 2943'MD ID 8.835" BTC 2818'TVD CBL TOC @ 4050'MD RA Tag @ 5077'MD All Sliding Sleeves Open Down � --� � 'i ------•'-'Sliding Sleeve @ 5146'MD-ID 2.313" II Annular Sleeve-Closed-4/6/2015 1 ,, Tripoint Hydraulic Set Packer @ 5161'MD PERFORATIONS i' 'I -- Sliding Sleeve @ 5188'MD-ID 2313" MD TVD — Ii Zone 1-Closed-4/6/2015 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 I -- -E 4 ....---- _.n_. . Tripoint Hydraulic Set Packer @ 5873'MD 5765-5800 5438-5472 Zone 1 ' 1 I Sliding Sleeve @ 5904'MD-ID 2.313" 5911-5934 5578-5600 Zone 2 % t Zone 2-Open-Sliding Sleeve Open 5990-6004 5653-5668 Zone 2 3=iI: ]C'S 8497-8523 8147-8179 Zone 3 T_'7t al= 8804-8812 8459-8467 Zone 3 8917-8932 8589-8600 Zone 3 8970-9016 8625-8671 Zone 4 , k .-: RA tag @ 8334'MD • I. w 4- „..,.,.- _.- Tripoint Hydraulic Set Packer @ 8404' X Nipple @ 8,448'Tripoint-ID 2.313" 2 7/8" 6.5#L80 EUEN 8483'MD tf It c„ _. . XN Nipple @ 8,482'MD-ID 2.205" ID-2.441' BTC 8138'TVD • tt. kil. , „ Wire Line re-entry guide @ 8483'MD — WC Zone 3-Closed-Plug in XN Nipple =it lle ta 4 - Tripoint Packer Model D Set @ 8964'MD 0, --- 2-7/8"X/O 2-3/8" a? 4 1 2 3/8"XN Nipple @ 8978'MD-ID 1.795" __ rZZ Zone 4-Closed-Plug in XN Nipple I =E X Est.TOF @ 9092'MD Fish 1 TCP guns 88'long Fish 2 Cut 2 7/8 tubing 6.54 460'long PBTD @ 9640'MD 9295'TVD TD at 9,750'MD/9,404'TVD 8 3/4"Hole 7" 26#L80 EUE 9,725'MD ID-6.276" GeoCon 9,379'TVD + NFU 24-26 Proposed Schematic Cook Inlet Energy --a 16"Conductor -' 7. 16" 93#K-55 120'MD v,',4 ID 14.88" Welded 120'TVD i''''fs ,.. TRSSSV©+/-352 MD-ID 2.441" 1, g Lac((C0 c--- - rt-. ,, `r ( 4 Tel 1'4 2 7/8"Chemical Injection Mandrel @+/_2524'MD-ID 2.441" 12 1/4"Hole -' *.; 9 5/8" 40#L-80 2943'MD ID 8.835" BTC 2818'TVD CBL TOC @4050'MD a i Y 0 1^. k;; •U RA Tag @ 5077'MD All Sliding Sleeves Open Down J, ` _..... -... Sliding Sleeve @ 5146'MD-102 2 313" .1, Annular Sleeve-Closed-4/6/2015 } Tnpoint Hydraulic Set Packer @ 5161'MD PERFORATIONS It Sliding Sleeve @ 5188'MD-ID 2 313" MD TVD 1-Closed-4/6/2015 5196-5204 4898-4906 Zone 1 5262-5280 4960-4977 Zone 1 -- Tnpoint Hydraulic Set Packer @ 5873'MD 5765-5800 5438-5472 Zone 1 Sliding Sleeve @ 5904'MD-ID 2.313" 5911-5934 5578-5600 Zone 2 11. Zone 2-Open-Sliding Sleeve Open 5990-6004 5653-5668 Zone 2 / 8497-8523 8147-8179 Zone 3 ✓ 8804-8812 8459-8467 Zone 3 8917-8932 8589-8600 Zone 3 3/8"Capillary Tube to 8,000'MDQ 8970-9016 8625-8671 Zone 4 4.--•,----- C _._........ .. RA tag @8334'MD It M Tnpoint Hydraulic Set Packer @ 8404' I X Nipple @ 8.448'Tnpoint-ID 2.313" 2 7/8" 6.5#L80 EUEM 8483'MD Tt i' XN Nipple @ 8,482'MD-ID 2.205" ID-2.441" BTC 8138'TVD I1. W re Line re-entry guide @ 8483'MD =$t ant Zone 3-Closed-Plug in XN Nipple SE Tnpoint Packer Model D Set©8964'MD All. 2-7/8"X/0 2-3/8" 2 3/8"XN Nipple @ 8978'MD-ID 1 795" 7:'8C m Zone 4-Closed-Plug in XN Nipple SIC 3= IS _ Est.TOF @ 9092'MD IFish 1 TCP guns 88'long , Fish 2 Cut 2 7/8 tubing 6.5#460'long PBTD @ 9640'MD 9295'TVD TD at 9.750'MD/9,404'TVD 8 3/4"Hole 7" 26#L80 EUE 9,725'MD ID-6.276" GeoCon 9,379'TVD • • • ® G E Oil & Gas I 38.6" (1;\ i ',Li___,.)._' I• `—IO I.1 / 302' 1#111 �L 2-9116'5M $1.O ... 2-9116.5M2-9/16'5M,__ I1 I -r [1._.., , ' i11_ rr p ri ) (1 i - z:. 11.4" • • ■H—lei ion ... 5-V 2-9/16"5M S 2-9/16"5M • sis IiI:yN sl 45.8" G 0J 1,6 ,,' /"` ' MSIJ 1 o,i a 2-9/16"5M O (I 011 127.2" O' 1. ' . _ X11 • 4 • 111 11.5m • . ow I ■■ iii_ �- ' • I��1 1 28.5'toc lit i 19.0" ft ■ �. ti ■ w NI 1.1 II - e 11"5M .1 41 2-1/16'5M t t i -all' MI 28.5"to E '` 0 t el 11 6_ '__1111 I ,9 to I •I i-.i' 31.7" i ari MEM, - i A_ - 2-1/16"5M di i —a 1— 26"O.D.Base Plate J 9-5/8"Casing 7'Casing 2-78"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 ENERGY neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. NFU 24-26 9-5/811 x 711 x 2-7/811 5M SH2 Wellhead Assembly, DRAWN VJK 19DEC14 APPRV KN 19DEC14 With T-M40-CCL Tubing Hanger and M40-CCLAdapter Flange FOR REFERENCE ONLY DRAWING NO. 1001107-1C • • 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 Guy, 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. 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 P1 4- (420 Regg, James B (DOA) From: David Kumar <dkumar@glacieroil.com> Sent: Wednesday, May 10, 2017 2:58 PM c I1-k ( l To: Regg, James B (DOA) t I Cc: Quick, Michael J (DOA) Subject: Re: SSSV NFU 24 26 Dear Mr.Regg, As an update to NFU 24-26 we were able to lock out the previous SSSV and install an insert.Unfortunately due to problems with the top polished bore on the insert,we were unable to get it operational.Pursuant to these findings we shut-in the well on 5/4/2017 1030 and the well has been shut in ever since.We are currently looking at various other options and will keep the Commission in loop when we have an solution Please call me if you have any questions Thanks and Regards David Kumar Production Manager 1 Glacier Oil and Gas Corporation Email: dkumar@glacieroil.com From: "Regg, James B (DOA)" <jim.regg@alaska.gov> Date: Thursday, April 27, 2017 at 8:44 AM To: David Kumar <dkumar@glacieroil.com> SCANNED E'� �� Vit'' Cc: "Quick, Michael J (DOA)" <michael.quick@alaska.gov> Subject: RE: SSSV NFU 24 26 Approval granted by phone yesterday. For your and our records, AOGCC has granted a 14-day extension to complete repairs and test the SSSV in NFU 24-26 (PTD 2141660). A passing test is to be completed by May 10, 2017 or the well must be shut it. 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 From: David Kumar [mailto:dkumar@glacieroil.com] Sent:Tuesday, April 25, 2017 2:23 PM To: Regg,James B (DOA) <jim.regg@alaska.gov>; Quick, Michael J (DOA) <michael.quick@alaska.gov> Subject:SSSV NFU 24 26 Mr. Regg, During our 6-month SVS testing at North Fork Unit the SSSV on NFU 24-26 failed to hold differential pressure after closure. We tried to clean and repair the valve via wireline work and remain unsuccessful. The delivery time for an insert was initially stated to be 16 weeks. After numerous efforts we were able to locate tools, services and hardware which will help us complete the job in approximately a week from now. The 14 day period required to fix the SSSV ends on the 27th and we are requesting the Commission to give us an additional 14 day period to install and test the insert. This well flows about 800 MCFD and is detrimental to our contacts obligations. Please let us know if we have permission to continue operating this well for the additional 14 days. We are willing to perform periodic SSV testings during this extension as the commission desires Sincerely, David Kumar Production Manager I Glacier Oil and Gas Corporation A(43, Email:dkumar@glacieroil.com 2 40 PPG( Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, April 27, 2017 8:45 AM (Ret -7/1 7 To: 'David Kumar' (7 Cc: Quick, Michael J (DOA) Subject: RE: SSSV NFU 24 26 Approval granted by phone yesterday. For your and our records,AOGCC has granted a 14-day extension to complete repairs and test the SSSV in NFU 24-26 (PTD 2141660). A passing test is to be completed by May 10, 2017 or the well must be shut it. 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: David Kumar [mailto:dkumar@glacieroil.com] Sent:Tuesday, April 25, 2017 2:23 PM To: Regg,James B (DOA) <jim.regg@alaska.gov>; Quick, Michael J (DOA)<michael.quick@alaska.gov> Subject:SSSV NFU 24 26 Mr. Regg, During our 6-month SVS testing at North Fork Unit the SSSV on NFU 24-26 failed to hold differential pressure after closure. We tried to clean and repair the valve via wireline work and remain unsuccessful. The delivery time for an insert was initially stated to be 16 weeks. After numerous efforts we were able to locate tools, services and hardware which will help us complete the job in approximately a week from now. The 14 day period required to fix the SSSV ends on the 27th and we are requesting the Commission to give us an additional 14 day period to install and test the insert. This well flows about 800 MCFD and is detrimental to our contacts obligations. Please let us know if we have permission to continue operating this well for the additional 14 days. We are willing to perform periodic SSV testings during this extension as the commission desires Sincerely, David Kumar Production Manager I Glacier Oil and Gas Corporation 1 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. z.4. - 1 co (0, Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Ma s: rayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date:T117/`/ 5 /s/ oil' Project Proofing BY: Maria Date: q17/".....c. /s/ vVf Scanning Preparation 5 x 30 = ._ 0 + /0 = TOTAL PAGES aso (Count does not include cover sheet) g BY: 620 Date: g7 `tc /s/ Production Scanning cc�� Stage 1 Page Count from Scanned File: 2 3-1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 41, Date: S17[45- 1 7 I 45— /s/ yjij Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 110 NO TOTAL PAGES: loEl Digital version appended by: Meredith1/1S_ Michal Date: 6/ i pZ I I 6' /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3 L4- 9 Scanning is complete at this point unless rescanning is required. 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APR 2 7 2015 Phone: (907) 334-6745 Fax: (907) 334-6735 M.K.BENDER AOGCC` DATA TRANSMITTAL Date: April 27, 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) 24-26, API#50-231-20045-00-00 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); Dipole Sonic in las and pdf; CBL Logs in las and pdf; Quad Combo Logs in las, pdf, and cgm; total 28 files 1 Printout of above listed CD -3 pages 7 1 CD (Disc 2)- Digital data for LAC 200 Log in DLIS, LAS, & PDF; total 4 files 8 1 Paper Copy- Directional Survey NFU 24-26 - 3 pages 9 1 Paper Copy- NFU 24-26 CBL Logs 10 1 Paper Copy- NFU 24-26 Quad Combo Logs 1", 2", 5", MD &TVD 11 1 Paper Copy- NFU 24-26 Dipole Sonic Log 5" MD Runs 2 & 3 12 1 Paper Copy- CanRig Well Report binder including mudlogs with data CD To submit emailed signed transmittals send to: barb.kruk@cookinlet.net Please sign below to acknowledge receipt. Received By: fi).....4„,./,) Date: Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC NFU 24-26/NFU 24-26 Date Modified:4/27/2015 bk S - :.':.�_ -.WJE q..� �wi^.., :a.:•'y.. _-. =456 - - -. RECEIVED � ., 1 > APR 272015 214166 AO GCC er 1 , -' 1� ,11 Coo,. INLET GY, LLC- / J 611v)115" 1 `N� AA L 11 5itau201 ' 700 � MsD Mo �1r: M.K.BENDER ` ' r speed $ ..1.). ` i N.. 52 x vitesse OM 1 7*4771F117 80 min 1 2 5 7 2 k ' _ . NFU Lgt-24 Af o 71II -24040 _____ D 1SC �- ; G+4 L°G DLA s,i.�1S D Tik4 i 4 tcs �O l a t nfu24-26_shear.txt volume in drive E is NFU 24-26 CD 2 Volume Serial Number is A7FD-96F0 Directory of E:\ 03/26/2015 01:29 PM 144,861,714 COOK_NFU_24_26_LAC200.dlis 03/26/2015 01:24 PM 1,252,901 COOK_NFU_24_26_LAC200.1as 03/26/2015 12: 51 PM 40,648,061 COOK_NFU_24_26_LAC200.meta 03/26/2015 03:29 PM 9,160,028 COOK_NFU_24_26_LAC200.meta.PDF 4 File(s) 195,922,704 bytes Total Files Listed: 4 File(s) 195,922,704 bytes 0 Dir(s) 0 bytes free Page 1 L 1 4 1 b 6 7 1 4 4_ V I Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 ri L E I V E D Anchorage, Alaska 99501 ATAGGED APR 2 7 2015 Phone: (907) 334-6745 Fax: (907) 334-6735 D .L1,O20 E M.K.BENDER AOGCC AOGCC DATA TRANSMITTAL Date: April 27, 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) 24-26, API#50-231-20045-00-00 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); Dipole Sonic in las and pdf; CBL Logs in las and pdf; Quad Combo Logs in las, pdf, and cgm; total 28 files 1 Printout of above listed CD - 3 pages 7 1 CD (Disc 2)- Digital data for LAC 200 Log in DLIS, LAS, & PDF; total 4 files 8 1 Paper Copy- Directional Survey NFU 24-26 - 3 pages 9 1 Paper Copy- NFU 24-26 CBL Logs 10 1 Paper Copy- NFU 24-26 Quad Combo Logs 1", 2", 5", MD & TVD 11 1 Paper Copy- NFU 24-26 Dipole Sonic Log 5" MD Runs 2 & 3 12 1 Paper Copy- CanRig Well Report binder including mudlogs with data CD 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 24-26/NFU 24-26 Date Modified:4/27/2015 bk - 5724 214166 RECEIVED APR 272015 NFU #24-26, API#50-231-20045-00 AOGCC Location Depth MD Depth ND Type of Coordinate Coordinate Surface 0' 0' Latitude,decimal minutes seconds 59 47' 46.960"N Longitude,decimal minutes seconds 151 3T 46.655"W Coordinate System Datum: NAD27(NADCON); Ellipsoid: Clarke 1866 TD 9,750' 9,405' Latitude,decimal minutes seconds 59 47' 40.785"N Longitude,decimal minutes seconds 151 38' 19.980"W Coordinate System Datum: NAD27(NADCON); Ellipsoid: Clarke 1866 214166 25724 4/20/2015 NFU 24-26, API# 50-231-20045-00 RECEIVED Geologic Markers APR 2 7 2015 AOGCC Name Measured Depth TVD Beluga 1,400' 1,390' Tyonek- Upper 5,000' 4,714' Tyonek- Middle 7,905' 7,560' 21 4166 25724 4/20/2015 NFU#24-26,API#50-231-20045-00 RECEIVED Oil and Gas Shows APR 2 7 2015 AOGCC Name Measured Depth TVD Fluid Show#1 5,908'-5,922' 5,575'-5,588' Gas Show#2 6,990'-7,005' 6,645'-6,660' Gas Show#3 7,040'-7,080' 6,695'-6,735' Gas Show#4 7,115'-7,125' 6,770'-6,780' Gas Show#5 7,135'-7,160' 6,790'-6,815' Gas Show#6 7,175'-7,185' 6,830'-6,840' Gas Show#7 7,379'-7,427' 7,034'-7,082' Gas Show#8 8,493'-8,528' 8,148'-8,183' Gas 21 4166 4/20/2015 25 72 4 NFU#24-26,API#50-231-20045-00 RECEIVED Abnormal Pressure Zones APR 2 7 2015 AOGCC Name Measured Depth TVD Fluid NONE NONE NONE CO LO e— tV a— LC) N pNoi-- 0000 ?n000inoin V O lD M V) V) lD in N in Vl Vl N V1 N V N m 00 N N lD N N N N Cr N Ct m Ol Ol l0 Ol O l Ol Ol Ol Ol Ol Ol Ol Ol Ol ILI lfl in1-- O O O in in O In O inN a O - M O [F Vl N Ill N Vl N Vl N ' LU v r •Zr •Cr 01 00 Ol I Ol 00 Ol CO al 00 Ol 00 N lD N a--1N N N N N N N N f0 H Q V1 LI'f ` : }0 N N in to to 1n N N N N N N N N w C ce N N N m a1 <-1 a1 a-1 a1 a l a1 a1 a1 a1 2 O 0_ CL O O E E O CO CU N (D 0 - 1 > ? m Y !r N •I'' in in 00 L11 J • Q QQ JO It 04 0- Y Y 00 1 p p D • H Q. 0 y m m � cms p ; g Q , 2 N o E 0hD ,n ,En 0 'n n , , A uua O O . 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NN. . 2%& 20 M&12g 0 0 0 0 0 M 0%W 0 M W M 0 0 2 W M W O CD 0 0 0 tM+f�pYNOq��pM�tG t'�CDMq�t7 tD��(Ny{eMp (y IV�p(�pG OO�4..s?4180Tt�INO�'NtiN�d:2gm;:0170 COGCGO GGpG6tV,6 666677 QO9d CCGCGOO 66 O O • m A0amVAOD0ypOOA2Y-.8OQA. tAh •O . pp O.MN.01. .-0 NN m.tO V ID.n.v.e,li�NCG 0V0000V0000000NNCD 0000�1000V0000000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3V3y33p3m�op3opVt3333333�3133�133333<33p3 V V V VpMQt0+lM tph tpA+I tp7 Cpl MM01 N N tV,N pM N 01�tppOOtdV OO pOpOOM NNNNN Fl N N N N N N N N N N N N N N N N N N N N N N N N a N N N l0 N N N N N N N N N N N N N N N lO N 10 N N N l0 N N N N N ZZZZZZZZZZZZZZZZZZ yZZZZ�Z�QQZZZZZc�ZZZ 00000'00 V m.MOOIoococc .6 6O6o O6 vedvddddvv vv ededee deddddddddd.a eee'"'aeeedde geqdpe�pe10e1ee NMl0nl0D10010A10A10A100100i(0)l0!)1n Y10000000O0Y00 dN(tNyV NQCOpp 0100 • NO.,SMMmONMNs-Om CODNBOO W AMNNOcomsim dNOf l00A app.��pyp.app.app. ��pyD. app. .app. .app. �Op. .. NNNlinigNggig88888888888NN1§ON NN N N N N N N N N NN ININN NNN;NNNNN NNNNNNN(NN • N A N e v W A 0 e 0 r W,m m,N A�mG'O;<CD.N',m,,D OmD m m M A W N d M C D G N r N t v omD o p CC DD N NNNNNNNMNMMMM�i�MMMt+I MthM V eIV O<O<v0 NNNNN�Np CNp Q1Cp.-Q1 m 0 r Cp%2 M6 CpM CD oD 6m Amm W 1m�0SSO101S X0{101.01 I!t0111'.011,0101:0101,.01.0100i p0p1�(C0yy1'.0 TIRE TO • mNN W lrOO�ANt000100RttDIlNO I1: M mN",?NI0If0 V n N M NNNNNNNOANNN010.0nnmm'N eC7 fV Om0 n.m',N A A A A A A A A A A A r np n N OAiA • m-o O m pN m Gm O co A m tiIrf.N m N A m N O.m m m 1�o1 A m m COD t00 fD fD t0�t0 fD tD f�f0(e W W m m o r r m o v. 1.N O m m e d M M M N N—m m�O e O N N N CCNppNNNNNN�NyNN'N.N.N,....A§MO �Ip��(�y(y�'O �(1 �(��pp tD CAprmm pMrNM�jA CASA pain le mn CADAiCD CDO V ggQ1�ECD�pQp1�Wpp CAD Ol�1ODmmOAmmmVNCDAAAA A AAAA-OVS3O21010 N tDf00ACDm W 80ZECDgggE O W CADCD(O CgD0101ss01 g W r r AA AAACD OCD CD 'OrON�e�PN�CDN�NOfN m'm.Nm NAMN�CD p aOv M��p A tV CO ffVV CD 117 N1�.�1�G CD M'N'IDN d O:A OC1 G�r(NV pA N(0y t0�1 N aD A fO fO N i0 N Y t7 Y t7 t'7 l7 M 0 V M N n-N N l7 t7 M t�1 t+1 C'1 f7 th MN V 2'.22. CAD W SVP84.S2�OtOl00n010NMN1V A(000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p 0 p p p p p p p p 8 8 g e e(�1 e e e e e e e e e e e e e e e e e 8 8 8 8 8 8 8 8�+1 8G DrDA '1 g�tOMm� w`AO'`$N$N a naOtrO Oi N^fV M ON .66-mg gl�mgrmMm81SSbg§ggil`§1g8or • . RECEIVED „_..._. APR 272015 ; ' , AOGOC .rtE O NV% 0 O �� o c% cL `-,-:. ;. 0 \ 1:', , ,,.„-;,,,,104 , K \ DJ \ \ . \ .s. ,,.,,.,,. .,...;,.:. , . 777 , ,. .., S . v ,..-,iii‘v, ‘s1 \ ...' 7.01 .3 4 . � C'� o s `fl �ozc 2 L' 0 2-'' C l'.' i4.1 o It. -,... 'f 1t i Volume in drive F is NFU 24-26 Volume Serial Number is B393-55B6 Directory of F:\ 04/27/2015 01:58 PM <DIR> Logs 04/27/2015 01:59 PM <DIR> Surveys 04/27/2015 02:18 PM 0 list.txt 1 File(s) 432 bytes Directory of F:\Logs 04/27/2015 01:58 PM <DIR> . 04/27/2015 02:18 PM <DIR> .. 04/27/2015 01:58 PM <DIR> Acoustic 04/27/2015 01:58 PM <DIR> CBL 04/27/2015 01:58 PM <DIR> QuadCombo 0 File(s) 1,276 bytes Directory of F:\Logs\Acoustic 04/27/2015 01:58 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 01/14/2015 04:56 PM 6,071,784 CIE_NFU_24-26_AC100.pdf 02/03/2015 11:12 AM 35,033,349 CIE_NFU_24_26_SOUNDTRAK_DTC_R2_R3.meta 02/03/2015 11:19 AM 10,438,172 CIE_NFU_24_26_SOUNDTRAK_DTC_R2_R3.pdf 02/02/2015 08:58 PM 394,871 COOK INLET ENERGY_NFU_24-26_SOUNDTRAK_R2.las 02/02/2015 08:59 PM 363,913 COOK INLET ENERGY_NFU_24-26_SOUNDTRAK_R3.las 01/09/2015 11:44 AM 20,700,812 COOK_NFU_24_26_AC100.meta 01/09/2015 11:46 AM 394,871 COOK_NFU_24_26_AC100_DTC.las 7 File(s) 73,398,512 bytes Directory of F:\Logs\CBL 04/27/2015 01:58 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 04/21/2015 03:56 PM 5,439,455 NFU#24-26 7IN CBL 23-DEC-14.pdf 04/21/2015 03:56 PM 6,348,182 NFU 24-2671N CBL 23-DEC-14.1as 2 File(s) 11,788,001 bytes Directory of F:\Logs\QuadCombo 04/27/2015 01:58 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 04/27/2015 01:58 PM <DIR> CGM 04/27/2015 01:58 PM <DIR> LAS 04/27/2015 01:59 PM <DIR> PDF 0 File(s) 1,864 bytes Directory of F:\Logs\QuadCombo\CGM 04/27/2015 01:58 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 12/25/2014 09:47 PM 5,007,208 2014-12-19_Rig37_NFU24-26_MD1MEM_QUAD_180-9750.cgm 12/25/2014 09:48 PM 6,017,188 2014-12-19_Rig37_NFU24-26_MD2MEM_QUAD_180-9750.cgm 12/25/2014 09:48 PM 10,366,040 2014-12-19_Rig37_NFU24-26_MD5M EM_QUAD_180-9750.cgm 12/24/2014 12:20 AM 4,033,976 2014-12-19_Rig37_NFU24- 26_TI M E M E M_AP_20141206_20141218.cg m 12/25/2014 09:49 PM 5,110,884 2014-12-19_Rig37_NFU24-26_TVD1MEM_QUAD_180-9750.cgm 12/25/2014 09:49 PM 5,893,988 2014-12-19_Rig37_NFU24-26_TVD2MEM_QUAD_180-9750.cgm 12/25/2014 09:50 PM 7,810,688 2014-12-19_Rig37_NFU24-26_TVD5MEM_QUAD_180-9750.cgm 7 File(s) 44,240,836 bytes Directory of F:\Logs\QuadCombo\LAS 04/27/2015 01:58 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 12/20/2014 11:55 PM 10,697,959 2014-12-19_Rig37_NFU24-26_MDM EM_QUAD_180-9750.Ias 1 File(s) 10,698,259 bytes Directory of F:\Logs\QuadCombo\PDF 04/27/2015 01:59 PM <DIR> . 04/27/2015 01:58 PM <DIR> .. 12/25/2014 09:52 PM 1,363,566 2014-12-19_Rig37_NFU24-26_MDIM EM_QUAD_180-9750.PDF 12/25/2014 09:52 PM 2,258,386 2014-12-19_Rig37_NFU24-26_MD2M EM_QUAD_180-9750.PDF 12/25/2014 09:52 PM 4,733,293 2014-12-19_Rig37_NFU24-26_MDSM EM_QUAD_180-9750.PDF 12/25/2014 09:53 PM 3,093,874 2014-12-19_Rig37_NFU24- 26_TIMEMEM_AP_20141206_20141218.PDF 12/25/2014 09:53 PM 1,571,286 2014-12-19_Rig37_NFU24-26_TVD1MEM_QUAD_180-9750.PDF 12/25/2014 09:53 PM 2,422,921 2014-12-19_Rig37_NFU24-26_TVD2MEM_QUAD_180-9750.PDF 12/25/2014 09:53 PM 4,623,091 2014-12-19_R1g37_NFU24-26_TVD5MEM_QUAD_180-9750.PDF 7 File(s) 20,067,281 bytes Directory of F:\Surveys 04/27/2015 01:59 PM <DIR> . 04/27/2015 02:18 PM <DIR> .. 04/27/2015 01:36 PM 30,433 NFU 24-26 Final Surveys.pdf 01/05/2015 01:13 PM 78,848 NFU 24-26 Final Surveys.xls 04/27/2015 01:42 PM 11,569 NFU 24-26 Final Surveys_loadfile.txt 3 File(s) 121,282 bytes Total Files Listed: 28 File(s) 160,317,743 bytes 24 Dir(s) 546,668,544 bytes free STATE OF ALASKA RECEIVED r AL, .A OIL AND GAS CONSERVATION COM. ,SION APR 15 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations L1 Perforate U Other 414 -C_c,i n,ti 0 Performed: Alter Casing ❑ Pull Tubing ❑✓ Stimulate-Frac ❑ Waiver ❑ Time Extension ❑ we,e.tf Change Approved Program ❑ Operat.Shutdown ❑ Stimulate-Other ❑ Re-enter Suspended Well ❑ 2.Operator COOK INLET ENERGY,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑., Exploratory ❑ 214-166 3.Address: 601 W.5TH AVE STE 310 ANCHORAGE,AK Stratigraphic ❑ Service ❑ 6.API Number: 99501 50-231-20045-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 391211 North Fork Unit#24 26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): North Fork 11.Present Well Condition Summary: Total Depth measured 9750' feet Plugs measured NONE feet true vertical 9404' feet Junk measured NONE feet Effective Depth measured 9750' feet Packer measured 1 5,161'MD/4,865'ND 2.5,873'MD/5,5417ND 3. true vertical 9404' feet true vertical 6'404 MD/8,059 TVD 4.8,964'MD/8,058 ND Casing Length Size MD TVD Burst Collapse Structural 120' 16" 120' 120' N/A N/A Conductor Surface 2943' 9 5/8"40# 2943' 2818' 5750 3090 Intermediate Production 9725' 7"26# 9725' 9379' 7240 5410 Liner Perforation depth Measured depth 5196'-5204',5262'-5280',5765-5800',5911'-5934',5990'-6004',8970"-9016',8497'-8523',8917'-8932',8804'-8812' True Vertical depth 4898'-4906',4960'-497T,5438'-5472',5578'-5600',5653'-5668',8625'-8671',814T-8179'.8589'-8600',8459'-8467' Tubing(size,grade,measured and true vertical depth) 2 7/8" L80/EUE 8,483'MD 8,138'TVD Packers and SSSV(type,measured and true vertical depth) Tnpoint DLH Hydra! Pkrs 1.5,161'MD/4,865'TVD 2.5,873'MD/5.541'TVD 3.8,404'MD/8,059'ND 4 8,964'MD/8,058'TVD TRSSSV:@ 352 MD/TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 1,944 1.6 0 383 Subsequent to operation: N/A 1884 0 0 374 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑., Service ❑ Stratigraphic ❑ Daily Report of Well Operations ATTACHED 16.Well Status after work: Oil U Gas U WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Tyler Wagner Email tyler.wagner(a�cookinlet.net Printed Name Conr er Title Drilling Manager Signature �� Phone 907-433-3831 Date 4/15/2015 Form 10-404 Revi((((sed 10/2012 - Zc' - RBDM - APR 1 8 2015ubmit Original Only . w _ Cook Inlet Energy_ RECEIVED APR 15 2015 April 15, 2015 AOGCC Ms. Cathy Foerster, 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# 24-26 Permit to drill NO: 214-166 API No: 50-231-20045-00-00 Dear Ms. Foerster, Cook Inlet Energy(CIE)hereby submits a Sundry Completion for pulling completion and setting a bridge plug above the lowest most perfs, re-perforating zone's 1, 2, and some of 3. Then recompleting. Attached is the 10-404 form, current wellbore schematic, tripoint completion, and daily reports. Work commenced on Febuary-10-2015. If you have any questions, please contact me at(907) 727-7404. Sincerely, .nrad Pe Drilling Manager Cook Inlet Energy 10-404 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • IFU 24-26 Final Completion Schematic Version: Current Cook Inlet Energy April 14,2015 16"Conductor 16" 93#K-55 120'MD Al — ID 14.88" Welded 120'TVD TRSSSV @+/-352 MD-ID 2.441" 2 7/8"Chemical Injection Mandrel @+/-2524'MD-ID 2.441" • 12 1/4"Hole 9 518" 40#L-80 2943'MD ID 8.835" BTC 2818'TVD Note from 3/27/2015 Sliding sleeves 2 is open Both XN nipples have plugs .:. .. All Sleeves Open Down RA Tag @ 507T MD 1., Sliding Sleeve©5146'MD-ID 2.313" Perforations , MD TVD _ - Tripoint Hydraulic Set Packer @ 5161'MD 5196-5204 4898-4906 Zone 1 -- Sliding Sleeve @ 5188'MD-ID 2.313" 5262-5280 4960-4977 Zone 1 - Zone#1 5765-5800 5438-5472 Zone 1 5911-5934 5578-5600 Zone 2 -- - - Tripoint Hydraulic Set Packer©5873'MD 5990-6004 5653-5668 Zone 21 ;i Sliding Sleeve @ 5904'MD-ID 2.313" 8497-8523 8147-8179 Zone 3 { Zone#2 8804-8812 8459-8467 Zone 3 a a 8917-8932 8589-8600 Zone 3 37x a 8970-9016 8625-8671 Zone 4 [RA tag @ 8334'MD - ---: • 4--- Tripoint Hydraulic Set Packer©8404' 1 f• X Nipple©8,448'Tripoint-ID 2.313" ' Ir XN Nipple©8,482'MD-ID 2.205" Plug in XN Nipple - rl I' Wire Line re-entry guide©8483'MD o sx XEC Zone#3 a SC - 4.-- Tripoint Packer Model D Set @ 8964'MD 2 7/8's tubing cross over 2 3/8's Plug in XN Nipple w op 2 3/8's XN Nipple @ 8978'MD-ID 1.795" a IN= Zone#4 Est.TOF @ 9092'MD Fish 1 TCP guns 88'long Fish 2 Cut 2 7/8 tubing 6.5#460'long I i: ' PBTD @ 9640'MD 9295'TVD TD at 9,750'MD/9,404'TVD 8 3/4"Hole 7" 26#L80 EUE 9,725'MD ID-6.276" GeoCon 9,379'TVD LL 'TR/PG - ALAStti.. company G OS. Casing Size: seg WOt Lasing Glut: Gang Tweed: Depth Cook Inlet Entergy 14-Feb-15 7 26" N-80 I.eas.000 WO. Liner Sae: linr VAS Lew Gra. Liner Thread. Liar Depine NFU 24-26 0 0.0# 0 Oneliam13.cli. Leer Size: Leer1,0,000 Liner Gina 0 Liner Depths North Fork Field County/Pian State: 00,05a,ng Size'. Tubing W gt: Tubing Grad.: Tubing Thread: PBTD'. Kenai Peninsula Alaska 0° c 2.875 8.5 N-80 8 rd 0' Compiegne Interval 00P BHT'. Fluid'. Specialist: PSI 0°F 0.00# B .Turner III Item Description 0.D. I.D. Length Depth 1 Elevation 22.13 (0.00 59 Hanger 0.81 22.133 58 58 2 7/8"eue 8rd L-80 6.5#/ft Tbg Pup 3.868 2.441 3.90 22.94 57 57 2 7/8'eue 8rd L-8013.5#/ft Tbg Pup _ 3.888 2.441 32.52 26.84 56 58 2 7/8"eue Ord 1.80 6.5#/ft Tbg Pup 3.688 2.441 32.50 59.36 55 55 4 Stnds 2 7/8'eue 8rd 8.5#Tbg 3.888 2.441 251.01 91.86 54 54 2 7/8'ate 8rd 1-80 8.5#/ft Tbg Pup 3.688 2.441 8.19 342.87 53 53 2 7/8"eue Ord L-80 8.5#/fl Tbg Pup 3.888 2.441 1.88 351.06 I"+ 52 52 SSSV 4.850 2.441 6.71 352.72 I 51 51 2 7/8"eue Ord L-80 8.5#/8 Tbg Pup 3.888 2.441 1.20 359.43 50 50 2 7/8'eue 8rd L-80 8.5#/ft Tbg Pup 3.888 2.441 4.11 380.63 49 49 2 7/8"eue 8rd L-80 8.5#/ft Tbg Pup 3.888 2.441 8.20 384.74 48 48 2 7/8"eve 8rd 1-80 0.5#/8 Tbg Pup 3.688 2.441 8.28 372.9447 47 34 Sinds 2 7/8"eue 8rd 8.5#Tbg 3.888 2.441 2,138.39 381.22 ' 46 46 2 7/8"we 8rd L-80 8.5#/ft Tbg Pup 3.068 2.441 4.07 2,519.61 a, 45 45 Chemical Injection pump 3.888 2.441 7.15 2,523.68 Int 44 at 44 2 7/8' e Brd L-80 8.5#/ft Tbg Pup 3.068 2.441 1.60 2,530.83 I I 43 43 40 Soda 2 7/8"eue 8rd 6.5#Tbg 3.888 2.441 2,544.98 2,532.43 42 '.1 62.02 5,07. 1.1 42 41 2 7/8"eue 8rd L-80 6.5#/ft Tbg Pup 3.668 2.441 8.15 5,139.44 ■ 41 40 Sliding Sleeve#3 3.930 2.313 4.04 5,145.59 e 40 39 2 7/8"eue Brd L-80 8.5#/fl Tbg Pup 3.888 2.441 4.27 5,149.83 1.139 38 2 7/8"eue 8rd 1-8013.5#/ft Tbg Pup 3.688 2.441 8.06 5,153.90 38 37 Crossover 2 7/8"sue 8rd box X 3 1/2"elle 8rd pin _ 3.700 2.347 0.82 5,159.96 37 36 DLH Hydraulic Set Packer#3 5.870 3.000 6.35 5,160.78 $ 36 35 Crossover 3 1/2"eue 8rd box X 2 7/8"eue 8rd pin 4.510 2.347 0.84 5.167.13 =7. 35 34 2 7/8"eue 8rd 1-80 0.5#/f Tbg Pup 3.668 2.441 4.10 5,167.9734 33 2 7/8"eue 8rd L-80 8.5#/ft Tbg Pup 3.888 2.441 0.10 5,172.07 III 33 32 2 7/8"eue 8rd L-80 6.5#/ft Tbg Pup 3.668, 2.441 4.10 5,178.17 32 31 2 7/8"eue 8rd L-80 6.5#/ft Tbg Pup __ 3.888 2.441 8.15 5,182.27 I 31 30 Sliding Sleeve#2 3.930 2.313 4.04 5,188.42 O 30 29 27/8'sue 8rd 1-808.5#/ft Tbg Pup 3.688 2.441 4.27 5,192.46 ■I29 28 1-2 7/8'eue 8rd 1-80 6.5#/ft Tbg Joint 3.868 2.441 32.53 5,198.73 l28 27 10 Sind.2 7/8"eue 8rd 8.5#Tbg _ 3.888 2.441 637.27 5,229.26 IRI 27 28 2 7/8"sue Brd L-80 6.5#18 Tbg Pup 3.808 2.441 6.08 5,806.53 , 26 25 Crossover 2 7/8"eue 8rd box X 3 1/2'eue Brd pin 3.770 2.440 0.82 5,872.59 1 25 24 DLH Hydraulic Set Packer#2 5.870 3.000 8.35 5,873.41 ■ 24 23 Crossover 3 1/2"eue 8rd box X 2 7/8'eue Brd pin 4.500 2.348 0.84 5,879.76 23 22 2 7/8'sue Brd 1-80 0.5#/ft Tbg Pup 3.008 2.441 4.10 5,880.60 . 22 21 2 7/8"eue 8rd L-80 8.5#/ft Tbg Pup 3.888 2.441 4.22 5,884.70 I 21 20 2 7/8'eue Brd 1-80 8.5#/8 Tbg Pup 3.668 2.441 4.30 5,888.92 20 19 2 7/8"eue Brd L-80 6.5#/fl Tbg Pup 3.888 2.441 4.27 5,893.22 1 9 18 2 7/8'eue Brd L-80 6.5#/ft Tbg Pup 3.688 2.441 6.14 5,897.49 . 1 8 17 Halliburton Sliding Sleeve#1 3.930 2.313 4.04 5,903.63 e 17 16 2 7/8'we Brd 1.80 6.5/4ft Tbg Pup 3.668 2.441 4.27 5,907.87 ■. 16 15 2 7/8"eue Brd L-80 8.5#/8 Tbg Pup 3.888 2.441 10.40 5,911.94 MI 15 14 2 7/8"eue 8rd 1.80 8.5#/8 Tbg Pup 3.668 2.441 8.25 5.922.34 14 19 2 7/8"eue 8rd 1-80 8.5#/8 Tbg Pup 3.888 2.441 4.23 5,930.59 13 12 38 Sbda 2 7/8"award 0.5#Tbg 3.888 2.441 2,399.48 5,934.82 III 12 11 1 Sind 2 7/8'eue 8rd 6.5#Tbg with R.A.Ta J 3.668 2.441 62.60 8.334 79 . 11 10 2 7/8"eue 8rd L-80 8.5#M Tbg Pup _ 3.888 2.441 6.06 8,396.9 II10 9 Crossover 2 7/8'sue 8rd box X 3 1/2'eue 8rd pin 3.780 2.347 0.82 8,402.96 9 8 DLH Hydraulic Set Packer#1 5.870 3.000 8.35 8,403.78 ■ 8 7 Crossover 3 1/2"eue 814 box X 2 7/8'eue 8rd pin 4.513 2.347 0.85 8,410.13 7 6 2 7/8"eue 8rd L-80 8.5#/ft Tbg Pup 3.688 2.441 4.07 8,410.98 ■ 6 5 2 7/8"eue 8rd 1-80 8.5401 Tbg Joint 3.668 2.441 32.54 8,415.05 ' 5 4 2 7/8-We L-80"X'Landing Nipple w/2.131"ID 3.668 2.313 1.25 8,447.59 3 2 7/8"we Ord L-80 6.5#/ft Tbg Joint 3.668 2.441 32.49 8,448.84 ! I 4 2 2 7/8"eue L-80'XN"Landing Nipplew/2.205'No/Go 3.888 2.205 1.35 8,481.33 .I 3 ` 1 Wireline Reentry Guide 3.700 2.500 0.55 8,482.68 `RI 21 1 F 7"Mod"D"Wireline Set Permanent Packer 5.810 3.250 1.78 8,984.42 _ E Below Packer Tubing Adapter 5.810 2.810 0.55 8,966.20 F i D 2 7/8"eue 8rd 1-80 8.5#/ft Pup Joint 3.140 2.441 9.81 8,966.75 C Cross-over 2 7/8"eue 8rd box X 2 3/8"eue 814 pin 3.870 1.900 0.88 8,976.36 B 2 3/8""X-Landing Nipple with 1.795"No/Go 3.070 1.795 0.98 8,977.24 E A Wireline Reentry Guide 3.100 2.000 0.55 8,978.22 III 8,978.77 D ----- Service Contact: Kenai,AK(907)283-0202 .0 �� Plug in Place in Item B when packer was set on 02/14/2015 I`a'# AB • � Printed on 3/25/2015 @ 9:43 AM Page 1 of 1 NFU 24 26 Workover Summary 2/8/15-2/9/15 Rig Move 2/10/15 RU lubricator and test. RU and test Pollard.Attempt to RIH with blind box. RU and run Pollard slickline and shift sleeves. Reverse circulate well 2/11/15 Continue circulating well. RD Pollard Slickline. Monitor well. Set BPV and nipple down tree. Plug chemical and SSSV control lines, set plug in hanger. Tie onto BOP and set on wellhead. NU kill and choke valves. 2/12/15 Test BOPE. ND flow line, MU test joint. Recover BPV. Bleed down annulus. 2/13/15 Pull tubing hanger to rig floor. Pull and LD completion. 2/14/15 Test BOPE. RU SLB eline and prep completion. Run GR, CCL. LD tools. Set packer POH with tools. ND flow riser and NU shooting flange and pressure test. MU run#1 gun. Fire (8917'-8932'). MU #2 and fire (8804'-8812') MU #3 and fire (8497'-8523'). 2/15/15 MU gun #4 and fire (5990'-6001'). MU gun#5 and fire (5911'-5934'). MU gun #6 and fire (5765'-5800'). MU gun #7 and fire (5262-5280). MU gun#8 and fire (5196'- 5204). RU and RIH w/ 6" gauge ring and junk basket. Tag Packer at 8960'. RD SLB eline. ND shooting flange. NU flow riser. Layout completion equipment. Run Completion. 2/16/15 Continue running completion. PU chemical injection mandrel, RU pollard equipment for injection and SSSV lines. Test. PU SSSV. Function valve open. Install tubing hanger. Land completion.WLRG @ 8483', #3 Packer @ 8403', #2 sleeve @ 5903', #2 Packer @ 5873', #1 sleeve @ 5188', #1 packer @5160'. CIrc sleeve @ 5145'. Chem Injection Mandrel @ 2,523', SSSV @ 352'. PU Pollard Slick line and run standing valve in XN at 8481'. RD Pollard 2/17/15 Set Packers with 3500 PSI on tubing. Packers set. Pressure test annulus. Set BPV. ND BOPE. Dress and Install tree and test. Cook Inlet Energy_ RECEIVED MAR 2 6 2015 3/26/2015 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7`I Ave., Suite 100 Anchorage, Alaska 99501 Re: NFU 24-26 Well Completion Cook Inlet Energy, LLC: NFU 24-26 Permit to Drill No: 214-166 Dear Ms. Foerster, Please find our enclosed 10-407 Well Completion for the NFU 24-26 well. Included is the 10- 407 form, drilling summary, wellbore schematic, final survey and a cementing report. If you have any questions, please contact me at (907)-727-7404. Sincerely, 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 JIL AND GAS CONSERVATION COMM ON • WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑✓ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development E- Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: _2 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: Cook Inlet Energy, LLC Aband.: 12/27/2014= 214-166 - 3.Address: 6. Date Spudded: 13.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 11/26/2014' 50-231-20045-00-00- 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 648'FSL, 1542'FEL-SEC 26-4S-14W 12/18/2014 • North Fork Unit 24-26 Top of Productive Horizon: 8. KB(ft above MSL): 678.6 15. Field/Pool(s): _ 239'FSL,2400'FWL-SEC 26-4S-14W GL(ft above MSL): 658 North Fork -,u E I V E D Total Depth: 9. Plug Back Depth(MD+TVD): 'A +' i� X�14. '' 49'FSL,2029'FWL-Sec 26-4S- 14W N/A Ar,-7,i Z•(OAR 2 6 2015 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. rP operty Designation: Surface: x- 199870 y- 2121192 - Zone- 4 ••9750'+9404' ADL 391211 4.®G CC TPI: x- 198520 y- 2120791 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 198150 y- 2120606 Zone- 4 352'+352' LOCI 10-004 18. Directional Survey: Yes H No H 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,sonic N/A 23. CASING, LINER AND CEMENTING RECORD 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 I 2943 0 2818 12 1/4" 284 bbls#12.5+41 bbls#14.8 125 bbls 7" 26 L-80 0 9725 0 9379 8 3/4" 161 bbls#12.7+100 bbls#13.5 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 193' 2 7/8"6.5#L-80 8483 1.5,161'MD/4,865'TVD TVD MD FT 2.5,873'MD/5,541'TVD 3.8,404'MD/8,059'TVD 4.8,964'MD/8,058'TVD (4898'-4906') 5196'-5204' 8' _ E .ECI • . (4960'-4977') 5262'-5280' 18' 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. (5438'-5472') 5765-5800' 35' Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ DATE . (5578'-5600' 5911'-5934' 23' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1,EA i;•1' (5653'-5668') 5990'-6004' 14' N (8147'-8179') 8497'-8523' 26' (8459'-8467') 8804'-8812' 8' (8589'-8600') 8917'-8932' 15' (8625'-8671') 8970'-9016' 46' 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 1/21/2015 • Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/27/2015 1/24/1900 Test Period -►N/A 1944 1.6 26/64 N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 383 0 24-Hour Rate -► N/A 1944 1.6 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No H ' Sidewall Cores Acquired? Yes ❑ No 0 • 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. Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original oily 7�97� 7 1c•(s- RBDMS,Alf APR 1 8 2015 , 'r ' ? 1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested?• R lYes Ho 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 1400 1390 Tyonek 5000 4714 Formation at total depth: 31. List of Attachments: 10-407,Wellbore Schematic, Daily Drilling Summaries, Direction Surveys,Casing and Cement Report, . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Conrad Perry Email: Conrad.Perry(c�CookInlet.net Printed Name: Conrad Per ' Title: Drilling Manager Signature: 'OrPhone: (907)727-7404 Date: 3/26/2015 INSTRUCTIONS General: This form is designed for submit'i 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 124-26 Final Completion Schematic Version: FINAL Cook Inlet Energy_ February 24,2015 20"Conductor 20" L-80 120'MD AllID 19" Welded 120'TVD TRSSSV @+/-352 MD-ID 2.441" 2 7/8"Chemical Injection Mandrel©+/-2524'MD-ID 2.441" 12 1/4"Hole i ip 9 518" 40#L-80 2943'MD : .y..4) ID 8.835" BTC 2818'TVD All Sleeves Open Down RA Tag@5077'MD , l Perforations Sliding Sleeve©5146'MD-ID 2.3131] MD TVD +C—- Tripoint Hydraulic Set Packer©5161'MD 5196-5204 4898-4906 Zone 1 • Sliding Sleeve @ 5188'MD-ID 2.313" 5262-5280 4960-4977 Zone 1 —IS 1 — Zone#1 5765-5800 5438-5472 Zone 1 — — 5911-5934 5578-5600 Zone 2 1--. 411( •••••••••••••"-- Tripoint Hydraulic Set Packer©5873'MD 5990-6004 5653-5668 Zone 2 I f ;i Sliding Sleeve©5904'MD-ID 2.313" 8497-8523 8147-8179 Zone 3 [] Zone#2 8804-8812 8459-8467 Zone 3 a 1 La= 8917-8932 8589-8600 Zone 3 xx sx 8970-9016 8625-8671 Zone 4 M - RA tag @ 8334'MD --! Tripoint Hydraulic Set Packer©8404' .1l I X Nipple @ 8,448'Tripoint-ID 2.313" ` 1 ‘ XN Nipple©8,482'MD-ID 2.205" I w'� Wire Line re-entry guide©8483'MD u a Zone#3 a sx Tripoint Packer Model D Set©8964'MD . '_ 2 7/8's tubing cross over 2 3/8's SII 'Tit a1 '�� 2 3/8's XN Nipple @ 8978'MD-ID 1.795" a s Zone#4 a rt Est.TOF @ 9092'MD Fish 1 TCP guns 88'long 1 Fish 2 Cut 2 7/8 tubing 6.5#460'long PBTD @ 9640'MD 9295'TVD TD at 9,750'MD/9,404'TVD 8 3/4"Hole 7" 26#L80 EUE 9,725'MD ID-6.276" GeoCon 9,379'TVD North Fork Unit 24 26 PTD: 214-166 Drilling Summaries 11-20-14 to 11-23-14 Rig Move, site prep 11-24-14 Diverter test. 11-25-14 Diverter Test 11-26-14 PU BHA and HWDP, Spud Well. Drill from 140'-156' 11-27-14 Drill from 156'-430'. 11-28-14 Drill ahead from 430'-1295'. 11-29-14 Drill ahead from 1295'-2157'. 11-30-14 Drill ahead from 2157'-2946'.TD hole section. Circ and condition for short trip. Pump dry job. 12-1-14 Short trip and RIH back to bottom. Circulate. POH RU for casing 12-2-14 RU to run casing. Run,9_5111140# Special Drift casing to 2943'. Circulate and reciprocate casing. 12-3-14 RU cementers. Pump spacer,test lines, bbls 9.6# Batch and pump lead 12.5# 281 bbl total lead. Pump 14.8#tail cement 1 bbW, kick out top plug and displace cem nt. Bump plug.WOC. ND Diverter IZ IV s 12-4-14 yr-7 fs-°r ND Annular Install 9 5/8"wellhead test void. NU BOPE. 12-5-14 NU and test BOPE. PU BHA. 12-6-14 PU Directional and MWD tools. Load LWD nuclear source. RIH to bottom. Test Casing to 3000psi. Drill cement to 2890'. Drill up float equipment from 2890 to 2938. Drill ahead from 2946 to 2970. CBU. Perform FIT, EMW of 13.62 ppg. Drill ahead to 3230. 12-7-14 Drill ahead from 3230-4300'. 12-8-14 Drill ahead from 4300'-5490' 12-9-14 CBU. Drill ahead from 5490'-6144'. 12-10-14 Drill ahead from 6144'-6837. POH. 12-11-14 POH.Test BOPE. 12-12-14 Continue testing BOPE. Run CBL. RD wireline. PU motor and BHA. RIH. Drill ahead to 6852'. 12-13-14 Drill ahead from 6852'-7596'. 12-14-14 Short trip. Drill ahead from 7596'-8522' 12-15-14 Drill ahead from 8522'-8970'. Short trip. 12-16-14 Continue POH. RIH to 5000'. 12-17-14 RIH to bottom. Drill ahead to 9524'. 12-18-14 Drill ahead to TD @ 9750'MD. Pump HI VIS Sweep. POH. LD drill pipe. 12-19-14 LD pipe, LWD tools, PU 5" test joint,test BOPE. 12-20-14 Continue testing BOPE. RU Weatherford CRT. PU 7" shoe track. RIH to 3970'. 12-21-14 RIH with 7" casing to 9740'. 12-22-14 1 I RU cementers. Drop bottom plug and chase with water. Pressure test lines. Pump 38.5 bbl spacer batch 12.7 ppg class G cement,pump 161 bbl, pump 99.5 tail cement at 13.5 ppg. Drop top plug and displace with 371 bbl 8.5 ppg 3%KCL brine. Bump lug. RD cementers, LD 5" 12-23-14 Change rams and test BOPE. PU Pollards for CBL. RD Pollards. Change rams to VBR and test. -� 12-24-14 Test BOPE.Test ca 0 4D0 nsi. PU and RIH with taper mill and scraper. 12-25-14 Continue clean out. Run guage ring. LD tools. RU to run completion. PU guns. 12-26-14 Continue running completion. PU chemical injection pump, PU SSSV, RU and test control line to 5000 PSI. Run correlation log. 12-27-14 Correlate. Space out tubing 3'. Test ports. Land completion on hanger. Run plug and set in XN nipple. RU to set packers. Set packers. Shear pins. LD landing joint. Install BPV. RD Weatherford. 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RRRRRRiRiRivtSit` thtg"g"nia RtttA�t°�it°RtSSg;4Q4Vt&`&4Si sssssssSSSSSSSSSSSsssssssssssSSS ttvttpyttsttpyttattpytttrsttpyt'tsttpytttttpy tCrtCpiytrgsmau�tyRsutStegt8)$giassttS CnpCpDD tptppp,ry A I A I A A I A r A r n A 0 R A A A A A A A A A A A A A n t A i i te t�y ttyy C" ^� i i t ipp ttyy i t i i tt t�� i pp i i t t ib qq� 6.Z 0)N$ZOt'D V SCD0O�S S(ON)O.Cr 0000O)t+)— A O(GOD pqIQ+IM NN app ACD CpD to Gr tV Y N tN tC iGA A CG CD Oi)Q�5y cc�V t5+y�lNy�Ny t'„p� �Ov�p7�"Y44`AYtOH11$ rQ 0'4'4'4 tY�� ;:gc tY"f`YtY' 1 R N RRRNtAV RRn m0000 eo----O$tB$OCDse+f O di N �ri m m of ui m ai ni Yf q ms Asp �� .tp OOv o(�y p�� e�essa stt pp{a♦ssmtp ems tpOy 1tDpt532gO�1(C��DCDCADt032 CO CDCODCD I�n A tP AAtAp AICD eSas I�O Yf 11')t0 t�lntOfD1� Ak8(pAOm�tYy)�e7$j ti j$p^tC'vp Q8A1�t+)��ty0j��{tVA� A A�Ap 1A�A C0 t0;; Cg 2CD Oty mCmD tOy CD�y 00)tO�f RTmS O)00) O.qq�eyy p�tp SAO toy t4N�%.5 C4Cp.A4e:=V 2t?tRpqtpO tA[)<OT GO pf2,7.1 IOC to tfV tOV gNtOR'tOt 2 4 V 4 f�t+)t7F)00"�NRt+)t+)CDtOt�Mt7t�) 0000.0,. 0 0ADM44S00000NFdbiB OOO0000666 0O0GOOOOO 8p8 8 ppS OOpppppppppppppppp$pp0pppppp pp • �C1A�t7NO �YRpQ with O $ AMi CAggV0§oo §1WWWg�igy§Cl • •- Surface Cook Inlet Energy_ �c' i- Casing and Cementing Report -- Tel2: 907 272-5003 Operator:Cook Inlet Energy C� Consultant: Rodney Maniaci Tell: (907)342-2551 UWI: 50-231-20045-00-00 WELL: NFU-24-26 DATE: 29-Nov-2014 ' AFE No.: 146003 KB Elevation: 678.58 ft KB to Ground: 20.58 ft KB to CBF: 24.00 ft CBF Elevation: ft CASING SUMMARY NO.of JTS. Size O.D Weight CASING GRADE THREAD STRING DESCRIPTION Length Tops ftKB (in) (Ib/ft) S/P Y/S ft ftKB ftKB 1 9.6 40.00 N 80 BUTT Float Shoe Single 1.72 2941.60 2943.32 1 9.6 40.00 N 80 BUTT Surface Casing 43.87 2897.73 2941.60 1 9.6 40.00 N 80 BUTT Float Collar Single 2.15 2895.58 2897.73 67 9.6 40.00 N 80 BUTT Surface Casing 2898.58 -3.00 2895.58 Total Number of items in Use: 74 Total length In Use: 3121.74 ft Rig Ld Joint: ft Liner Top: ftKB Number of full length joints on site: 72 Total full length Joints: 3117.87 ft Shoe Joint Length: ft Top Marker Set At: 0.00 ftKB Number of full length joints left Out: 4 Total full length left Out: 175.42 ft Stick Up: 3.00 ft Plug Back TD: 2895.00 ftKB Number of full length joints left In: 68 Total Length left In: 2942.45 ft Left In Hole: 2946.32 ft Csg Landed @ 2943.32 ftKB Csg Bowl Model: 11"5k Csg Bowl Serial#: Make Up Torque: ft•Ib TVD Depth: 2813.00 ft Csg Bowl MFG: Size: x Pressure: psi OutletType: Hole Depth: 2945.00 ftKB Transferred: 4 Joints Moved from: 50-231-20045-00-00 To: North Yard via: Truck Hole Size: 12.25 in Markers Make: Number:0 Positions:0 r Centralizers Make: Number: Positions: Scratchers Make: Number: Positions: Pup Joints Make: Number: Positions: Couplings Make: Number: Positions: Turbolizers Make: Number: Positions: Casing on Circulating Pressure Prior Circulation Rate Mud Properties Circulated for Mud Checked Bottom @ to Cementing(psi) - (BPM) YP PV Gels 11:00 12 Hrs 200 10 7 6 3/19/30 Yes Landed in: QQ Tension 0 Compression Q Unspecified Weight: 85000.00 lbf CEMENTING SUMMARY _ Pressure Test: 2500 psi Safety Meeting: Yes Circulation While Mixing: Full Rate: 3 BPM Cemented By: BJ Services TIME STAGE TOP (ftKB)INTERVALCEMENT (ftK8) AMOUNT UNIT TYPE/ADDITIVE CCODET SLURRY VOLUME(bbl) Density(Ib/gal) FILL 0 2606 1509 Cubic Feet 01 284 12.5 NO.1 TAIL NO.2 FILL • TAIL 2606 2946 86.6 Cubic Feet 01 41 14.8 NO.3 FILL - TAIL Lines Pumped Out? ©Yes 0 No On the Fly? ©Yes 0 No Circulation: Full %Excess: 95 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 219 219 MUD 3 300 500 1300 v 03/Dec/2014 06:30 Yes 1 STAGE COLLAR Cement Retums to Surface © Yes El No 1 Volume: 125 bbl Type of Returns Cement REMARKS 51cks Type I Cement+0.005 lbs/sack Static e+0.4%bwoc CD-32+ 1 gals/100 sack FP-6L +2%bwoc Sodium Metasilicate+2%bwoc Calcium Chloride+0.3%bwoc FL-52+ 106.7% h Water 17 sacks Type I Cement+0.005 lbs/sack Static Version 1136 Wellman 9-Resource Energy Solutions Inc.(403)245-0220 www.resourceenergysolutions.com January 22 2015 Page 1 of 1 •- Production Cook Inlet Energy Casing and Cementing Report Te12: 907 272-5003 Operator:Cook Inlet Energy Consultant Danile Sa)n/Rodney Mani Tell: 907 433-3549 UWI: 50-231-20045-00-00 WELL: NFU-24-26 DATE: 17-Dec-2014 AFE No.: 146003 KB Elevation: 678.58 ft KB to Ground: 20.58 ft KB to CBF: 24.00 ft CBF Elevation: 654.58 ft CASING SUMMARY NO.of JTS. Size OD Weight CASING GRADE THREAD STRING DESCRIPTION Length Tops ftKB (in) (Ib/ft) S/P Y/S ft ftKB ftKB 1 7.0 26.00 L 80 Geoconn Guide Shoe 1.50 9723.77 9725.27 2 7.0 26.00 L 80 Geoconn Production Casing 82.67 9641.10 9723.77 1 7.0 26.00 L 80 Geoconn Float Collar Single 1.45 9639.65 9641.10 222 7.0 26.00 L 80 Geoconn Production Casing 9611.83 27.82 9639.65 1 7.0 26.00 L 80 Geoconn Pup Joint 3.15 24.67 27.82 1 7.0 26.00 L 80 Geoconn Other(Casing Accessory) 0.50 24.17 24.67 1 7.0 26.00 L 80 Geoconn Landing Joint 34.32 -10.15 24.17 Total Number of items in Use: 236 Total length In Use: 10039.75 ft Rig Ld Joint: 34.32 ft Liner Top: ftKB Number of full length joints on site: 231 Total full length Joints: 9998.83 ft Shoe Joint Length: ft Top Marker Set At: 0.00 ftKB Number of full length joints left Out: 7 Total full length left Out: 304.33 ft Stick Up: 10.15 ft Plug Back TD: 9639.00 ftKB Number of full length joints left In: 224 Total Length left In: 9694.50 ft Left In Hole: 9701.10 ft Csg Landed @ 9725.27 ftKB Csg Bowl Model: 11"5k Csg Bowl Serial#: Make Up Torque: 18000 ft•lb TVD Depth: 9379.00 ft Csg Bowl MFG: Size: x Pressure: psi OutletType: Hole Depth: 9750.00 ftKB Transferred: 7 Joints Moved from: 50-231-20045-00-00 To: via: Hole Size: 8.75 in Markers Make: Turbolator Number:0 Positions:0 Centralizers Make: Number: Positions: Scratchers Make: Number: Positions: Pup Joints Make: Number:1 Positions:24.67 Couplings Make: Number: Positions: Turbolizers Make: Number: Positions: Casing on Circulating Pressure Prior Circulation Rate Mud Properties Bottom Circulated for to Cementing(psi) (BPM) YP PV Gels Mud Checked 22:30 3 Hrs 780 8 16 15 416/6 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: 5 BPM Cemented By: Baker TIME STAGEINTTOP (RIB) BOTTOM RVAL BOTTOM (RIB) RY AMOUNT UNIT TYPE/ADDITIVE CEMENT VOLUME(bbi)Density(Ib/gal) FILL 5750 5750 1123 'Cubit-Feel - -- 04 161 12.7 NO.1 TAIL 4026 57`0 1123 Cubic Feet 04 .-112-.-7 FILL N0.2 TAIL 5750 9725 449 Cubic Feet 04 99.5 13.5 FILL N0.3 TAIL Lines Pumped Out? ©Yes 0 No On the Fly? ®Yes ❑ No Circulation: Full %Excess: 38 1_T_- 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 369 371 WATER 5 273 1680 2670 22/Dec/2014 09:00 Yes STAGE COLLAR Cement Returns to Surface I]Yes ❑ No Volume: 680 bbl Type of Returns Mud REMARKS Lead:522 sacks Class G Cement+10%bwoc BA-90+ 0.005 IBs/sack Static Free+2.5%bwoc BA-56+ , �p I , 01 0 0.5%bwoc EC-1 +0.1%bwoc ASA-301 + 1 l v - gals/100 sack FP-6L+0.2%bwoc Sodium C--6 Metasilicate+ 104.1% Fresh Water vt'L Tail:2sacks Class G Cement+ 10%bwoc BA-90+ e.../.5-1..c.- Version /St�Version 1136 Wellman 9-Resource Energy Solutions Inc.(403)245-0220 www.resourceenergysolutions.com January 22 2015 Page 1 of 1 Cook Inlet Energy, LLC X522 601 W. 5th Avenue, Suite 310 EC E I V E D Anchorage, Alaska 99501 MAR 0 6 2015 Phone: (907) 334-6745 Fax: (907) 334-6735 AOGCC DATA TRANSMITTAL Date: March 6, 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 - 24-26, API#50-231-20045-00-00 Item No. Qty Description 1 Washed & Dried Samples for North Fork Unit-24-26 1 Box 1 of 5 - Dry Samples Interval depths (2,950' -4,450') @ 30' 1 Box 2 of 5 - Dry Samples Interval depths (4,450'-5,950') @ 30' 1 Box 3 of 5- Dry Samples Interval depths(5,950' - 7,450') @ 30' 1 Box 4 of 5- Dry Samples Interval depths (7,450' -8,950') @ 30' 1 Box 5 of 5- Dry Samples Interval depths (8,950' -9,750') @ 30' Email completed transmittals to: barb.kruk@cookinlet.net Please sign below to acknowledge receipt. Received — ( / j r? Date: 3// /l5 Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals_CIE_AOGCC.xlsx/AOGCC_3-6-15_NF24-26 kikk z141a .o Regg, James B (DOA) From: Evan Harness <Evan.Harness@cookinlet.net> � 8� Sent: Saturday, February 14, 2015 9:20 AM I� f To: DOA AOGCC Prudhoe Bay Subject: Miller Rig #37 Ann Preventer Use Attachments: 02-13-14 Miller Rig #37 Ann Preventer Use.pdf; ATT00001.htm Saturday, February 14, 2015 Cook Inlets Miller Rig #37 Use of Annular Preventer 02-13-15 12:00hrs to 03:00hrs NFU 24-26 PTD #214166 Miller Rig #37 Drill Site Manager 907-433-3549 Work over operations - 3ea Packers in the Hole -As we sheared the Packers the Trapped Gas below the packers would release - Circulating down the flow line caused gas accumulation in the Shaker area - Closed Annular Preventer and Diverted Flow through Gas Buster to assist with Venting Gas 11" 5M Hydril GK Annular Preventer Gas cut Mud Diversion Sent E-Mail (Not Correct Form) 02-13-15 PM - Received Instructions to Complete a Annular Preventer Test Prior to Next Trip in Hole Annular Preventer Pressure Tested to 250psi low and 2,500psi High 02-14-14 +/- 02:00hrs ' when out of Hole with Completion doa.aogcc.prudhoe.bay@alaska.gov j 7of ry THE STATE Alaska Oil and Gas �►;,,, „ALASKA =- �, Conservation Commission _ " t#i__ 333 West Seventh Avenue yjcz GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ' Fax: 907.276 7542 www.aogcc.alaska gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 0114 - / 6 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU 24-26 Sundry Number: 315-045 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, Danie . Seamount, Jr. Commissioner v DATED this day of February, 2015 Encl. RECEIVED STATE OF ALASKA JAN 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A 1GCC 20 AAC 25.280 1.Type of Request: Abandon' Plug for Redrill❑ Perforate New Pool n' Repair Well❑ Change Approved Program❑ Suspen[] Plug Perforations❑✓ Perforate 2. Pull Tubing • Time Extension❑ Operations Shutdown' Re-enter Susp.Well n' Stimulate 0 Alter Casing 0 Other: 4+-w Co%hel< 4• . M. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q • 214-166 3.Address: Stratigraphic ❑ Service 0 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20045-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.705 • 1/ Will planned perforations require a spacing exception? Yes O • No 0 North Fork Unit 24 26 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211 • Development North Fork Undefinded Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9750' 9404' 9750' 9404' None None Casing Length Size MD ND Burst I Collapse Structural 120' 20" 120' 120' N/A Conductor Surface 2946' 9 5/8" 2946' 2821' 5750 3090 Intermediate Production 9725' 7" 9725' 9379' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Wellbore See Wellbore 2 7/8"6.5# L80 EUE 9,026' Packers and SSSV Type: SSSV:Halliburton Packers and SSSV MD(ft)and TVD(ft): SSSV:349'MDfTVD 2 x Halliburton Hydraulic Retr PHL Packer,1 Olgoonik DHL Packer Packers:5194',5,851',8415'MD/4896',5497',8069'TVD 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑] Service 0 14.Estimated Date for 2/10/2015 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG n' 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tyler Wagner Email Tvler.Waciner(@.cookinlet.net Printed Name Conrad Perry,Drilling Man-,- •7-7404 Title 1/27/2015 Signature / IllrI Phone Date / COMMISSION USE ONLY Conditions of approval: Notify'om ssion so that a r resentative may witness Sundry Number: V 3) -c Plug Integrity ❑ BOP Test n'/ Mechanical Integrity Test 0 Location Clearance ❑ Other: 3JCC' S, 7$ if S � � ., d..,4`..), '7 ; ,as i. z t isS ..` �_ f�=..` �z ';� Spacing Exception Required? Yes No J� Subsequent Form Required: / yC y 0/.1_.-7/ 1 ' APPROVED BY -.., Approved by: / COMMISSIONER THE COMMISSION Date:t `- lli-C- �❑ wv Submit Form and Form 10-403(Revised 10/2012) �,ii�"��\\ i t I f r 12 m the from the date of approval. Attachments in Duplicate RRF M 1 GGP - R ?(115 ''4` K?4,----;-`'�/- Z'1. " Cook Inlet Energy RECEIVED JAN 2 7 2015 January 27, 2015 ®GCC 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 24 26 API: 50-231-20045-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a reperf sundry for North Fork Unit 24-26, PTD: 214- 166.We request to kill 24-26, pull the completion, and set a bridge plug above the lowest most perfs, re-perforate zone 1, 2 and some of 3. Then recomplete. If you have any questions, please contact me at(907) 727-7404. Sincerely, I Conrad Perry Drilling Manager- Cook Inlet Energy 1 Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 24 26 Requirements of 20 AAC 25.005(f) Well Summary Current Status: Well has been drilled to TD,completed,and we have perforated zones 1, 2 and 3,however with less than expected production. Scope of Work: • Move rig 37 on NFU 24-26 • Circulate kill weight fluid 8.6 ppg • Pull and lay down tubing from 9026' MD • Rig up wireline set bridge plug above perfs 8970' - 9016' • Re-Perforate all zones besides 8970 - 9016 ✓ • Re-run completion • Flow Well General Well Information: Reservoir Pressure /TVD: 3728 psi @ 8,670' TVD MASP: 3,300 psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Gas Well Estimated Start Date: February 10th, 2015 Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Tyler Wagner (907) 433-3831 Tyler.Wagner@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 2 Cook Inlet Energy_ Abandonment- Phase I 1. Move rig 37 on NFU 24-26 2. Notify AOGCC of start of operations and upcoming BOP test `/ } 3. Rig up wireline and close zone 2 sliding sleeve @ 5,897' MD t( r 4. Bleed off pressure in tubing and annulus 5. Rig up circulating lines to tree /l be-'-'- RR"" 6. Rig up pollard open sliding sleeve @ 5147' MD (shift down to open) 7. Make up 8.6 ppg kill weight mud and Circulate well dead 8. Ensure Well is dead 9. Set BPV and N/D Tree a. Have tree inspected by Vetco hand 10. Nipple up and test 11" 5 M BOPE with 2-7/8"pipe rams with blinds in middle a. Test Rams to 4500 psi .`\ r b. Test Annular Bag to 2500 psi 11. Remove/Pull BPV 12. P/U Landing Joint and make up to 2-7/8" Tubing Hanger 13. Pull & L/D 2-7/8" Landing Joint and Tubing Hanger a. Max yield for 2 7/8" 6.5 # L-80 EUE tubing is 144,000 lb b. Halliburton packers straight pull release at 54,000 lb c. Olgoonik packer straight pull release at 58,000 lb d. Around 115,000 lbs to straight pull and release hydraulic set packer with tubing weight. e. Max pull @ 80% of tubing yield is 115000, if exceeded call town 14. Circulate 2 bottoms up 15. Check for flow 16. Pull and LID tubing 17.Send packers in for redress 3S j 18. Rig up Eline to set bridge plug @ 8960' MD +G`i F �`" "``' c'L 19. RIH with SLB 4 1/2" casing guns to reperf the follow zones a. 5262'to 5280' �"" b. 5765'to 5800' P`,.is c. 5911'to 5934' \ .,L` t-- d. 5990'tO 6004' � 5/7 ,_ ' 2-011 C 2-3-1C -J e. 8497' to 8523' f. 8804'to 8812' g. 8917'to 8932' 3 Cook Inlet Energy_ 20. RIH with 6" OD junk basket to bridge plug @ 8960' MD 21. Set Completion _ A> a. 2 7/8" XN nipple at 8460' b. Tripoint 7" Hydraulic Packer at 8415' c. Sliding sleeve (closed) at 5880' d. Tripoint 7" Hydraulic Packer at 5850' e. 2 7/8" tubing to Sliding sleeve at 5250' f. Tripoint 7" Hydraulic Packer at 5190' g. Sliding sleeve (closed) at 5160' h. 2 7/8" tubing to chemical injection mandrel at 2500' i. 2 7/8" tubing to Tubing Retrievable SSSV at 350' j. Vetco 11" x 2 7/8" tubing hanger 22. Rig up Pollard wireline 23. Run plug to XN nipple at 8480. Pressure up and set all three hydraulic packers according to Tripoint recommendations 24.Test annulus to 2500 psi for 30 minutes on chart yt l T- IA- 25.Set BPV 26. Nipple Down BOPs 27. Nipple up Tree and test to 5000 psi 28. Rig up and test flowlines 29. Recover BPV lubricator i 30. Ri slick line and testto 4000 s Rig upP 31. Recover Plug from XN nipple 32. RIH and open sliding sleeve 5880' MD (down to open) 33.Start swabbing operation to turn on well 4 • . ' NFU 24 2t. _ roposed Completion 1/27/2015 TRSSSV @+/-349' • J' '2 7/8"Chemical Injection mandrel @+/-2517' ! 20" L80 120'TVD �: 120# BTC 120'MD 'r . • i • r kt q. •% a l . All sleeves shift down to 12 1/4"Hole open and up to close. • I 9 5/8" L80 2,818'TVD — T_ 40#SD BTC 2,943'MD Sliding Sleeve @ 5,147' Zone#1 I : 4 Current Perforations(TVD) MD Tripoint Hydraulic Set Packer @ 5,190' (4960'-4977') 5262'-5280' Sliding Sleeve @5,250'MD (5438'-5472') 5765-5800' (5578'-5600') 5911'-5934' (5653'-5668') 5990'-6004' (8625-8671') 8970"-9016' - 17 Zone#2 tI �' (8589'-8600') 8917'-8932' Tripoint Hydraulic Set Packer©5,850' (8459'-8467') 8804'-8812' Sliding Sleeve @5,880'MD Zone#3 Tripoint Hydraulic Set Packer @ 8,415' XN Nipple @ 8,460' an IQ 2 7/8"6.5#L80 EUE-M m Q 11 1 ev,G Bridge plug Set @ 8960'MD —, _ TOF©9658'MD — 8 3/4"hole TD �' 7" L80 9,379'TVD 9,404'TVD r . 26# GEOCON 9,725'MD 9,750'MD NFU 24 26 _ .oposed Completion 1/27/2015 — TRSSSV @+/-349' 2 7/8"Chemical Injection 16. mandrel @+/-2517' 20" L80 120'TVD 120# BTC 120'MD 1t , All sleeves shift down to 12 1/4"Hole open and up to close. _ . 9 5/8" L80 2,818'TVD Ti...- 40#SD BTC 2,943'MD Sliding Sleeve @ 5,147' I i Zone#1 "' I Current Perforations(TVD) MD €. -4977' 5262'-5280' Tripoint Hydraulic Set Packer @ 5,156' (4960' ) Sliding Sleeve @5,186'MD (5438'-5472') 5765-5800' (5578'-5600') 5911'-5934' ac (5653'-5668') 5990'-6004' (8625'-8671') 8970"-9016' I (8147'-8179') 8497'-8523' Zone#2 ' I (8589' 85866400601'.))) 600') 8917--- 8932' Tripoint Hydraulic Set Packer @ 5,850' (8459'-8467') 8804'-8812' Sliding Sleeve @5,880'MD Additional Perforations GM Calif (4898'-4906') 5196-5204' II lF. . Zone#3 I 161 Tripoint Hydraulic Set Packer @ 8,415' XN Nipple @ 8,460' MX 2 7/8"6.5#L80 EUE-M m Q II Bridge plug Set @ 8960'MD = TOF @ 9658'MD — = 8 3/4"hole TD ..' 7" L80 9,379'TVD 9,404'TVD . 1 26# GEOCON 9,725'MD 9,750'MD Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 03, 2015 11:13 AM To: 'Courtney Rust' Subject: RE: 214-- (NFU 24-26) add perfs 164 Courtney, Will add these to your sundry request. BTW..top perf is only 6 ft from your top packer depth. 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.aov). From: Courtney Rust [mailto:Courtney.RustCa cookinlet.net] Sent: Tuesday, February 03, 2015 10:24 AM To: Schwartz, Guy L (DOA) Subject: PTD: ,R1 y _ e(„6. Guy, We would like to add an additional pert interval to the 4900' Sand. 5196'-5204' Courtney Rust Cook Inlet Energy Drilling Engineer Cell: 907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED.If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 Schwartz, Guy L (DOA) From: David Kumar <David.Kumar@cookinlet.net> Sent: Monday,January 19, 2015 9:19 AM To: Regg,James B (DOA) Cc: Schwartz, Guy L(DOA); Roby, David S (DOA) Subject: Re: Updated Status on NFU 24-26:Questions on SVS Testing and Multipoint Back Pressure Test rreD Dear Mr Regg, We completed a multi-point back pressure test on Friday on Zone 2 and rolled into the Super A Sol treatment for 24 hrs on Zone 1 after isolating Zone 2. We tried back flowing the well late last night and early this morning with no considerable success. Current plan of operations is to isolate Zone 1, retrieve the pressure recorder from Zone 3 and bring the well online using Zone 2.This means that we should be able to do the SVS testing sometime this week. I will fill out a test notification form in advance. FYI,there are also plans on moving the rig back to this well, pending economics for a quick work-over operation. Thank you for your patience Regards David Kumar From:<Regg>, "James B (DOA)" <jim.regg@alaska.gov> Date:Wednesday,January 14, 2015 at 4:46 PM To: David Kumar<david.kumar@cookinlet.net> Cc: "Schwartz,Guy L(DOA)" <guy.schwartz@alaska.gov>, "Roby, David S(DOA)"<dave.roby@alaska.gov> Subject: RE: Updated Status on NFU 24-26: Questions on SVS Testing and Multipoint Back Pressure Test Thanks for your call this afternoon and the explanation about ongoing evaluation of NFU 24-26 (PTD 2141700)as it impacts AOGCC's initial witness of the SVS performance test. You confirmed that the well has a functional SVS— including SSSV. We agree that the AOGCC witness of the SVS performance test is appropriately deferred until after completing the current eval of Zone 2 (continuing to show improvement in flow potential) and Friday's planned Super A Sol treatment(and evaluation of its effectiveness)of Zone 1. Contact me about the timing of SVS testing after evaluating the effectiveness of the Super A Sol treatment of Zone 1 early next week(1/13/15?). 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 iim.regg@alaska.gov. 1 • ti From: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Wednesday,January 14, 2015 12:22 PM To: Regg, James B(DOA); Roby, David S (DOA) Cc: Schwartz, Guy L(DOA) Subject: Updated Status on NFU 24-26: Questions on SVS Testing and Multipoint Back Pressure Test Dear all, From the previous email chain, I thought that I would update the commission of the status of the well. After working on Zone 3 by using coil and unloading the zone of water, we were unable to establish production and had very little wellhead pressure from the zone. The zone is currently isolated from the other zones with a downhole pressure gauge monitoring buildup data which we will later retrieve for analysis. We then went back into Zone 2 and brought it into test in the wee hours of the morning on the 13th. We found that the pressure had built up to 1,550 psi from the previous 1,317 psi previously when we shifted sleeve. The well has been cleaning up from the previous test production rate of—500 MCFD to currently about—1,050 MCFD at—300 psi flowing wellhead pressure and is slightly increasing with passage of time. We believe there might be some sort near well bore flow restriction in Zone 2. As the commission is aware,we are in the process of getting ready to treat Zone 1 with Super A Sol sometime around Friday afternoon if everything lines up. This would be followed by possible testing of Zone 1, and depending upon what we find we might propose a similar plan for Zone 3 Mr. Regg With all the above said, activities would take considerable amount of time and I was hoping to clean up zone 2 this well for the rest of today and perform a initial pressure build up test in preparation for a four point test and roll into one on Friday. I was hoping to provide the Commission with an SVS testing on Friday which would be take place before the start of the back pressure test .Please let me know if this arrangement works for you and I will fill in a test witness notification form unless you decide to push it to a later date after the above mentioned tests on other zones. Drilling also has a BOP test in the near future. Mr. Roby The current PI of the well using surface pressures is about 0.84 MCF/day.psi as we have a huge drawdown going on for little flow. The Commission recommends as referenced in the back pressure testing of gas wells manual to perform the test between 95%to 75%of the wellhead shut in pressure as the flowing pressure steps for this test. This approximately equates to rates between 65MCFD to 325MCFD during the range of these four points. We might not be able to get good resolution flow data and control on the lower side of these rates . Is there a different method considering these circumstances that the Commission would like us to follow? I am more than happy to work with the Commission too provide them with all data they need. Please advise. Thanks and Regards David Kumar Production Manager K7,:,t Mitt Eine gy enuc.Suite 310_Anchoraee,AK 90", 907-433-3822(Directll 907-9034164(Mohile) 907-334-6745(Main) 1907-334-6735(Fux) David.Kumar@cookinlet.net From:<Regg>, "James B(DOA)"<jim.regg@alaska.gov> Date: Friday,January 9, 2015 at 9:04 AM To: David Kumar<david.kumar@cookinlet.net> 2 Cc: "Schwartz, Guy L(DOA)" <guy.schwartz@alaska.gov> Subject: RE: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing AOGCC will witness the SVS performance test once the well is online with stable production. Notification procedures are outlined in the attached guidance document;test witness notification form can be found at the following link: Test Witness Notification. If stabilized flowing conditions do not occur within 5 days of commencing production, contact me for further instructions about testing the SVS. 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: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Thursday, January 08, 2015 7:20 PM To: Regg, James B (DOA) Subject: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing Dear Mr Regg, As per the regulation 20 AAC 25.265, Cook Inlet Energy(CIE) is supposed to offer the Commission a witnessed SVS performance test after placing the well in service . CIE as usual function tested and ensured the closure of both the SSV and SSSV before perforating.As the Commission is well aware NFU 24-26 has three zones for potential production,which are isolated with a combination of packers and sliding sleeves. CIE perforated Zone 3 on 1/2/2015 and encountered water and was unsuccessful in unloading it.CIE perforated Zone 2 on 1/6/2014 and ran it briefly through test and was unsatisfied with the flow rates.CIE then proceeded to perforate Zone 1 on 1/7/2014 and was not able to detect any significant amount of gas.CIE is in the process of re-evaluating all these zones Currently,we have a coil tubing unit on site getting ready to rig up and unload water from Zone 3.We are hoping to bring this zone to production. CIE will also be conducting the multipoint back pressure test on this zone as per 20 AAC 25.255 before placing the well into production. I am hoping that we should be able to offer the commission at the earliest, an opportunity to witness an official SVS performance test once this zone cleans up followed by conducting the multipoint back pressure test before placing in production due to ongoing well operations. If you wish to perform this test before or between the above mentioned events, please let me know at the earliest so that I can arrange for it. Please feel free to call me if you have any questions regarding this email Thanks and Regards David Kumar Production Manager Cook inlet Energy 601 W_5th Avenue,Suite 310,Anchorage,AK 99501 007-433-3822(Direct)!907-903-4I64(Mobile) 907-334-6745(Main) 1907-334-6735(Fax) David.Kumar@cookinlet.net 3 Pm 2tti- 1LG 2,4rutq . 21' rv .. ,, ,, ._ .. , ., ...,....... t, ,,, ., . _ ' , . . : _•i •,,-,it- --, -, „ , _ -:1 I:1 i i:„.-t r �, .: r* z n re r L. • i -11 -7--- - tr-- , ,..:4c .All, --- ti - ....._.,1 i__ _ l,rs�rlsfisr�asrr11111 1/1111fi11/1rl " -'' ' , l '. fill)/ilii,,, 1, z lIlilI11r rsr ,tL/' +17111111I/l1 * a © `-.- 6. Ate' yx ""!','y --*- a lipY, \a . . . , • .. , '4 f . . it I/ kl , , A it ) .,,,. .. - - - - . L_____ 1, . - r- \ . ........, . . . ., ,,. 1 . . . - 11 . .... , . • . .. , , t... ., .... . ....,., . , . __ _ ,,,_....------‘ . .,,.t. ,_,,, r- :•• 'r'- H,,1 -.i:--1".116,,„ ' .. , ' ' -, --Agfa' , .- all'114**it,'''',:..; '''.... ---- . ' ' ,'" . it".''''''.'..,,,,L, ..: ' !,.'„ ,', I. ', \. • '. . .-.• ,. 1 „ ' . •,..-- ., . ........„ ,?,•• • .,• ,,,-....i ; _.„ 7._•,• -,-. 1.1.: to...Am, .4, . . . . . .. . . . . .. ,..... , - '... . .. i ...„ ,...... ._ •I :i i -.401Pr) ' • ‘ik . ,. •,:-, ......-.....„. II ..7 ..W. .. --.1. \ --1.-...111..n.1110. V.-.-,-..., , .. .. .. ' ..... , , , . — -.. \ . ,,....,.. . . . , . • . i:'`--, . , . , tp; ' ' -r 4' : • , (I''74•AMA—li. 1! -7)'.". .''P'' ' ';..'-'." .---,'• ,'. -• ..1.1! rfrlw '' ....,,•._, I I , . ...; gr4 .., • _ _... . . .._ , , . - ,, , f• t Nt- Elitt •• iiii.j....0,... . 4. .. . • _ i , .••,• ..a..• ` •.; • \ \ \ .. r'..,•; ' ',,1 . •••.i Yor .: ':„.,..‘ ,.-.• ' ' ...ee_„, _,,,,-4';:t.4': '''Vflif ...NW* 2, .., , , . ,,...„. ,...._., , .........., . . )01`- v L-U..t z4 Ritu4! C) Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, January 14, 2015 4:47 PM To: 'David Kumar' l Cc: Schwartz, Guy L (DOA); Roby, David S (DOA) Subject: RE: Updated Status on NFU 24-26: Questions on SVS Testing and Multipoint Back Pressure Test Thanks for your call this afternoon and the explanation about ongoing evaluation of NFU 24-26 (PTD 2141700) as it impacts AOGCC's initial witness of the SVS performance test. You confirmed that the well has a functional SVS— including SSSV. We agree that the AOGCC witness of the SVS performance test is appropriately deferred until after completing the current eval of Zone 2 (continuing to show improvement in flow potential) and Friday's planned Super A Sol treatment (and evaluation of its effectiveness) of Zone 1. Contact me about the timing of SVS testing after evaluating the effectiveness of the Super A Sol treatment of Zone 1 early next week (1/13/15?). 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: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Wednesday, January 14, 2015 12:22 PM To: Regg, James B (DOA); Roby, David S (DOA) Cc: Schwartz, Guy L (DOA) Subject: Updated Status on NFU 24-26: Questions on SVS Testing and Multipoint Back Pressure Test Dear all, From the previous email chain, I thought that I would update the commission of the status of the well. After working on Zone 3 by using coil and unloading the zone of water, we were unable to establish production and had very little wellhead pressure from the zone. The zone is currently isolated from the other zones with a downhole pressure gauge monitoring buildup data which we will later retrieve for analysis. We then went back into Zone 2 and brought it into test in the wee hours of the morning on the 13th. We found that the pressure had built up to 1,550 psi from the previous 1,317 psi previously when we shifted sleeve. The well has been cleaning up from the previous test production rate of—500 MCFD to currently about 1,050 MCFD at—300 psi flowing wellhead pressure and is slightly increasing with passage of time. We believe there might be some sort near well bore flow restriction in Zone 2. 1 As the commission is aware, we are in the process of getting ready to treat Zone 1 with Super A Sol sometime around Friday afternoon if everything lines up. This would be followed by possible testing of Zone 1, and depending upon what we find we might propose a similar plan for Zone 3 Mr. Regg With all the above said, activities would take considerable amount of time and I was hoping to clean up zone 2 this well for the rest of today and perform a initial pressure build up test in preparation for a four point test and roll into one on Friday. I was hoping to provide the Commission with an SVS testing on Friday which would be take place before the start of the back pressure test .Please let me know if this arrangement works for you and I will fill in a test witness notification form unless you decide to push it to a later date after the above mentioned tests on other zones. Drilling also has a BOP test in the near future. Mr. Roby The current PI of the well using surface pressures is about 0.84 MCF/day.psi as we have a huge drawdown going on for little flow. The Commission recommends as referenced in the back pressure testing of gas wells manual to perform the test between 95%to 75% of the wellhead shut in pressure as the flowing pressure steps for this test. This approximately equates to rates between 65MCFD to 325MCFD during the range of these four points. We might not be able to get good resolution flow data and control on the lower side of these rates . Is there a different method considering these circumstances that the Commission would like us to follow? I am more than happy to work with the Commission too provide them with all data they need. Please advise. Thanks and Regards DAVID KUMAR Production Manager Coo 1111t,t Easeril 30 i 00.5th Avenue,Suite 310,Anchorage.AK 99501 907-433-3822(Direct)!907-903-4164(Mobile) 907-334-6745(Main) 907-334-6735(1 ax) David.Kumar@cookinlet.net From: <Regg>, "James B (DOA)" <jim.regg@alaska.gov> Date: Friday,January 9, 2015 at 9:04 AM To: David Kumar<david.kumar@cookinlet.net> Cc: "Schwartz, Guy L(DOA)" <guy.schwartz@alaska.gov> Subject: RE: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing AOGCC will witness the SVS performance test once the well is online with stable production. Notification procedures are outlined in the attached guidance document; test witness notification form can be found at the following link: Test Witness Notification. If stabilized flowing conditions do not occur within 5 days of commencing production, contact me for further instructions about testing the SVS. 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, 2 please delete it, without first saving or forwaraing 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: David Kumar [mailto:David.Kumar©cookinlet.net] Sent: Thursday, January 08, 2015 7:20 PM To: Regg, James B (DOA) Subject: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing Dear Mr Regg, As per the regulation 20 AAC 25.265, Cook Inlet Energy (CIE) is supposed to offer the Commission a witnessed SVS performance test after placing the well in service . CIE as usual function tested and ensured the closure of both the SSV and SSSV before perforating. As the Commission is well aware NFU 24-26 has three zones for potential production, which are isolated with a combination of packers and sliding sleeves. CIE perforated Zone 3 on 1/2/2015 and encountered water and was unsuccessful in unloading it. CIE perforated Zone 2 on 1/6/2014 and ran it briefly through test and was unsatisfied with the flow rates . CIE then proceeded to perforate Zone 1 on 1/7/2014 and was not able to detect any significant amount of gas. CIE is in the process of re-evaluating all these zones Currently,we have a coil tubing unit on site getting ready to rig up and unload water from Zone 3. We are hoping to bring this zone to production. CIE will also be conducting the multipoint back pressure test on this zone as per 20 AAC 25.255 before placing the well into production. I am hoping that we should be able to offer the commission at the earliest, an opportunity to witness an official SVS performance test once this zone cleans up followed by conducting the multipoint back pressure test before placing in production due to ongoing well operations. If you wish to perform this test before or between the above mentioned events, please let me know at the earliest so that I can arrange for it . Please feel free to call me if you have any questions regarding this email Thanks and Regards David Kumar Production Manager Ccrok inlet Energy tw: tY'_9th Accnae, tiui;<t 3 li_;\ncl'or,irr. 007=133-322(x)zocl',m1-0n3-,116,4(Mobile) 007- 34-6745,' 4-6735(Fax) David.Kumar(a cool,inlet.nei 3 of � 7 ofALASI�:A THE STATE Alaska Oil and Gas Conservation Commission __ : s it;tz 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage,e, Alaska 99501-3572 Main: 907.279.1433 ALAS "' Fax 907.276 7542 www.aogcc alaska.gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU 24-26 Sundry Number: 315-020 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, Cathy P Foerster Chair DATED this 11- day of January, 2015 Encl. ' RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AN 1 2 2015 / DSM APPLICATION FOR SUNDRY APPROVALS 073 I/i %113 tiliiI)S 20AAC25.280 .hLOGCC 1.Type of Request: Abando❑ Plug for Redd!!El Perforate New Pool❑ Repair Well 1=1hange Approved Program❑ Suspenl] Plug Perforations❑ Perforate❑ Pull Tubing❑ Time ExtensionMM__ ,❑/ ❑ El ShutdowRe-enter Susp.Well Stimulate Alter Casing D Other: 111 //601-- I' 2.Operator Name: 4.Current Well Class: ,i.5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory /X rbevelopment Elf' 172 214-166 3.Address: Strati ra hic I ❑ 6.API Number: g p ❑ i Service 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20045-00-00 • 7.If perforating: l"•U -70.5� 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?,(pe 13•f; 20 .055 Will planned perforations require a spacing exception? ///''�iYes Q No 0 i..1. �,ei_Unit 24 26 • 9.Property Designation(Lease Number): I 10.Field/Pool(s): ADL 391211 _ Development North Fork Undefinded Gas ' 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): 9750' 9404' 9750' 9404' None None Casing Length Size _ _ MD ND Burst I Collapse Structural 120' 20" 120' 120' N/A Conductor Surface 2946' 9 5/8" 2946' 2821' 5750 3090 Intermediate Production 9725' 7" 9725' 9379' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached See Attached 2 7/8"6.5# L80 EUE 9,026' Packers and SSSV Type: SSSV:Halliburton Packers and SSSV MD(ft)and ND(ft): SSSV:349'MD/TVD 2 x Halliburton Hydraulic Retr.PHL Packer,1 Olgoonik DHL Packer Packers:5194',5,851',8415'MD/4896',5497',8069'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory LIStratigraphic LI Development❑� " Service ❑ 14.Estimated Date for / 1/13/2015 15.Well Status after proposed work: Commencing Operations: Oil 0 Gas ❑r • WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 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_ Pnnted Name Conrad Perry,Drilling Manager 7204 Title 1/12/2015 iiiiN Signature "hone Date /L f MMI /' COMMISSION USE ONLY Conditions of approval: Notify Common so that a repres#ative may witness Sundry Number: 3 \5 - 020 Plug Integrity 0 BOP Test 0 Mechanical Integnty Test ❑ Location Clearance 0 Other: r•e'3 /Cc. ( 4:,j wtozar....,,,t) Spacing Exception Required? Yes 12( No ❑ Subsequent Form Required: / 6 - 1 IN, 1 APPROVED BY Approved by:ewe,,,,/,.....,,,,,,.._ COMMISSIONER THE COMMISSION Date: /_ /q__is (_/c-1-(s 1,111 • intro A I Submit Form and Cook Inlet Energy_ RECEIVED JAN 122015 January 12, 2015 AOGGO 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 24 26 API: 50-231-20045-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 24-26, PTD: 214-166 requesting the use chemical treatments to stimulate the well. If you have any questions, please contact me at (907) 727-7404. Sincerely, Conrad Per Drilling Manager- Cook Inlet Energy 1 Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 24 26 Requirements of 20 AAC 25.005(f) Well Summary Current Status: Well has been drilled to TD, completed, and we have begun perforating zones. We have used coil tubing to clean the water off the well and nitrogen to lift the well, but feel a chemical treatment is necessary. Scope of Work: • Begin Super Asol treatment General Well Information: Reservoir Pressure/TVD: 3728 psi @ 8,670' TVD MASP: 3,300 psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Gas Well Estimated Start Date: January 7, 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 24-26 Forward Plan 1-12-2105 REV 0 1) Bleed and keep pressure bled off well. 2) Rig up slickline. 3) Set PX Plug Body in XN plug at 8460. Body to have Pressure Temperature bomb set below for 1 second readings. 4) Set PX prong in plug body. Ensure wellhead pressure is bled off at that time. 5) Monitor well while pulling out of hole to ensure prong is set. Tag prong with blind box if any question. 6) Pressure up on wellhead with N2 to equalize pressure across Zone 2 sliding sleeve at 5897'. Expect bottom hole pressure to be 1825 psi,surface pressure with N2 of about 1575 psi. 7) Open Zone 2 sliding sleeve. 8) Flow well to diffuser tank until gas returns at surface,then switch to production. 9) Flow well until prepared and ready for Zone 1 Super Asol treatment. a. Set up surface pressure recorder b. Record flow rates every hour 10) Shut well in and let pressure build on tubing to equalize pressure against Zone 1 Sliding sleeve at 5213'. a. Take manual surface pressures during any shut in at 10 minute intervals for first lhour then every 15 minutes for next 6 hours. 11) Rig up slick line. 12) Close Zone 2 sliding sleeve at 5897'. 13) Tag fluid level. If below 5213',fill tubing with produced water to 5213'. 14) Open Zone 1 sliding sleeve at 5213'. ivtA ( (2,,fre 15) Flow well to diffuser tank. 16) Rig up Baker pumping and Baker N2 to well. Test Lines to 5000 psi. 5✓`'"` 17) Bullhead 5500 gallons of Super ASOL well treatment into Zone 1. Chase with N2 to the bottom set of perforations at 5800'. 13o 64(-5 18) Let treatment soak according to recommendations(may chase treatment back into formation) 19) Open well to diffuser tank and flow back N2 and treatment. Turn well to production once gas to surface. _ 20) Repeat steps for Zone 2 and 3 if treatment is successful. (tel s S 3 NFU 24 26 Proposed Completion 12/18/2014 TRSSSV @+/-349' J --- ..... 2 7/8"Chemical Injection mandrel @+/-2517' 20" L80 120'TVD (i 120# BTC 120'MD ti, ,.Y ,w t i All sleeves shift down to i,. 12 1/4"Hole open and up to close. ' , 9 5/8" L80 2,750'TVD 40#SD BTC 2,870'MD Sliding Sleeve @ 5,147' Ti....._ Perforations Zone#1l Current Perforations(TVD) MD HB PHL Hydraulic Set Packer @ 5,194' `, (4960'-4977') 5262'-5280' Sliding Sleeve @5,213'MD /��j° (5438'-5472') 5765-5800' Y Block 2"guns 0 degree phase ff'�� (5578'-5600') 5911'-5934' IF I a, (5654'-5668') 5991'-6005' . — (8625'-8671') 8970"-9016' (8149'-8183') 8494'-8528' Zone#2 *I (8589'-8600') 8917'-8932' HB PHL Hydraulic Set Packer @ 5,851' Additional Perforations(TVD) MD: Sliding Sleeve @5,897'MD (8,149'-8,183') 8,494'-8,528' Y Block 2"guns 0 degree phase 2..... (8,458'-8,467') 8,803'-8,812' Q _ (8,598'-8,620') 8,943'-8,965' Zone#3 OLG DHL Hydraulic Set Packer @ 8,415' XN Nipple @ 8,460' v Q 2 7/8"6.5#L80 EUE-M Tubing 4 5/8"TCP or 2"Wireline Guns �v c 1J z 8 3/4"hole TDa = 7" L80 9,379'TVD 9,404'TVD lill 26# GEOCON 9,725'MD 9,750'MD Note:It is as tied into WLM which is 4'Shallower than tubing measurements 0' WLM=4'Tubing measurements.Packer Details on next tab Schwartz, Guy L (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Tuesday,January 13, 2015 4:20 PM To: Schwartz, Guy L(DOA) Cc: Conrad Perry Subject: Re: NFU 24-26 (PTD 214-166) Guy, Our max rate will be 2 bbl/min. We expect to stay under the frac gradient estimated at .79psi/ft with our lowest perf at 8,620' TVD or 6809 PSI Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. On Jan 13, 2015, at 3:22 PM, Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>wrote: Courtney, What is your max rate and pressure for injecting the fluid (ASOL)? I assume you are trying to stay below frac gradient and get matrix injection. 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(d,,alaska.gov). 1 y 774' -04THE STATE Alaska Oil and Gas ofALASI�:A Conservation Commission '. ti•#.t2 ^_ �_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS1P Fax 907.276.7542 www.aogcc.alaska gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU 24-26 Sundry Number: 315-018 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, Cathy P. oerster Chair L�- DATED this f 3 day of January, 2015 Encl. RECEIVED STATE OF ALASKA JAk 0 9 2015 ✓,. ALASKA OIL AND GAS CONSERVATION COMMISSION Q9S it 13J Is 0 JI`-'1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspen❑ Plug Perforations❑ Perforate RI "',fiS Pull Tubing 0 Time Extension❑ Operations Shutdown Re-enter Susp.Well 0 Stimulated,i`� Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class:{ 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory „i, f�% /y Development [1 iv 6 214-166 - 3.Address: Stratigraphic S 1 Service ❑ I`t' 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20045-00-00 • 7.If perforating: 1,0, .7 c.-- 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ' 2(� t ft.7y Will planned perforations require a spacing exception? Yes 12 No ❑ / s,eG„Unit 24 26 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211 • Development North Fork Undefinjed Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9750' 9404' 9750' 9404' None None Casing Length Size MD TVD Burst Collapse Structural 120' 20" 120' 120' N/A Conductor - Surface 2946' 9 5/8" 2946' 2821' 5750 3090 Intermediate Production 9725' 7" 9725' 9379' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached See Attached 2 7/8"6.5# L80 EUE 9,026' Packers and SSSV Type: SSSV:Halliburton Packers and SSSV MD(ft)and TVD(ft): SSSV:349'MD/TVD 2 x Halliburton Hydraulic Retr.PHL Packer,1 Olgoonik DHL Packer Packers:5194',5,851',8415'MD/4896',5497',8069'TVD 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑r Service ❑ 14.Estimated Date for / 1/7/2015 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑✓ . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: I- 9-IS" WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: SC-kwc.,-ft GSTOR ❑ SPLUG Cl 17.I hereby certify that the foregoing is tru and correct to the best of my knowledge. Contact Courtney Rust 907-433-3809 Email courtney.rust@cookinlet.net Printed Name Conrad Perry,Drilling=..404 itle 1/9/2015 Signature /'Phon: Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a sentative may witness Sundry Number: L� I 6 J1 Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 10-4-er 41.'") Spacing Exception Required? Yes No ❑ Subsequent Form Required: /6-460 7 / (,l�ts/ V APPROVED BY Approved by: Oefi COMMISSIONER T HE[MMISSION Date: /3 ORIGINA Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 mihs from the date of approval. i , Attachments in Duplicate Cook Inlet Energy_ January 9, 2015 RECEIV Ms. Cathy Foerster, Chair 9 2015 Alaska Oil and Gas Conservation Commission JAN 333 West 7th Ave., Suite 100 OGGC Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 24 26 API: 50-231-20045-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 24-26, PTD: 214-166 requesting these additional wireline perforations: 8,494' - 8,528'MD (8,149' - 8,183'TVD) 8,803' - 8,812'MD (8,458' - 8,467'TVD) 8,943' - 8,965'MD (8,598' - 8,620'TVD) If you have any questions, please contact me at(907) 727-7404. Sincerely, Conrad Perry Drilling Manager-Cook Inlet Energy 1 NFU 24 26 Perforations Current Perforations(TVD) MD (4960'-4977') 5262'-5280' (5438'-5472') 5765-5800' (5578'-5600') 5911'-5934' (5654'-5668') 5991'-6005' (8625'-8671') 8970"-9016' (8149'-8183') 8494'-8528' (8589'-8600') 8917'-8932' Additional Perforations(TVD) MD: (8,149'-8,183') 8,494'-8,528' (8,458'-8,467') 8,803'-8,812' (8,598'-8,620') 8,943'-8,965' NFU 24 26 Proposed Completion 12/18/2014 TRSSSV @+/-349' • [ 2 7/8"Chemical Injection - _ mandrel @+/-2517' 20" L80 120'TVD 1:1 120# BTC 120'MD . r ..' ;; + . .y All sleeves shift down to y;. 12 1/4"Hole open and up to close. 9 5/8" L80 2,750'TVD 40#SD BTC 2,870'MD Sliding Sleeve @ 5,147' i T...._ Perforations Zone#1 li Current Perforations(TVD) MD HB PHL Hydraulic Set Packer @ 5,194' (4960'-4977') 5262'-5280' Sliding Sleeve @5,213'MD (5438'-5472') 5765-5800' Y Block 2"guns 0 degree phase (5578'-5600') 5911'-5934' (5654'-5668') 5991'-6005' (8625'-8671') 8970"-9016' (8149'-8183') 8494'-8528' Zone#2 I 1 (8589'-8600') 8917'-8932' HB PHL Hydraulic Set Packer©5,851' Additional Perforations(TVD) MD: Sliding Sleeve @5,897'MD (8,149'-8,183') 8,494'-8,528' Y Block 2"guns 0 degree phase (8,458'-8,467') 8,803'-8,812' CM a (8,598'-8,620') 8,943'-8,965' , I Zone#3 OLG DHL Hydraulic Set Packer @ 8,415' XN Nipple @ 8,460' =a Q 2 7/8"6.5#L80 EUE-M Tubing 4 5/8"TCP or 2"Wireline Guns • Q D 8 3/4"hole TD a 7" L80 9,379'TVD 9,404'TVD la 26# GEOCON 9,725'MD 9,750'MD Note:It is as tied into WLM which is 4'Shallower than tubing measurements 0' WLM=4'Tubing measurements.Packer Details on next tab Cook Inlet Energy 1. WELL NAME - North Fork Unit 24 26 Requirements of 20 MC 25.0050 Well Summary Current Status: Well has been drilled to TD, completed, and we have begun perforating zones and using nitrogen to lift the well. Scope of Work: • Perforate additional zones and successfully bring on well General Well Information: Reservoir Pressure /TVD: 3728 psi @ 8,670'TVD MASP: 3,300 psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Gas Well Estimated Start Date: January 9, 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 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,January 09, 2015 1:32 PM To: 'Courtney Rust' Cc: Conrad Perry Subject: RE: Sundry APP: PTD: 214-166 Courtney, You have verbal approval to perforate the additional zones as outlined in the attached email as listed below. TVD ` MD • (8,149'-8,183) 8,494'-8,528' (8,458'-8,467') 8,803'-8,812' (8,598'-8,620') 8,943'-8,965' 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(Guv.schwartz@alaska.gov). From: Courtney Rust [nailto:Courtney.Rust@cookinlet.net] Sent: Friday, January 09, 2015 1:28 PM To: Schwartz, Guy L (DOA) Cc: Conrad Perry Subject: Re: Sundry APP: PTD: 214-166 Guy, It was listed on the original schematic as a"future perforation". It has not yet been perforated, therefore we included it in the "additional perforation", or more accurately a"to be perforated" section. Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 On Jan 9, 2015, at 4:22 PM, Schwartz, Guy L (DOA)<guy.schwartz@alaska.gov>wrote: Is the zone 8494-8528 'a re-perf?? 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 cr,alaska.gov). From: Courtney Rust [mailto:Courtney.Rust@cookinlet.net] Sent: Friday, January 09, 2015 12:57 PM To: Schwartz, Guy L (DOA) Cc: Conrad Perry Subject: Sundry APP: PTD: 214-166 Guy, Here is an electronic copy of the sundry application you will be receiving shortly. We are requesting these additional perfs: TVD MD (8,149'-8,183') 8,494'-8,528' (8,458'-8,467') 8,803'-8,812' (8,598'-8,620') 8,943'-8,965' Thank you. Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it, are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 2 a Schwartz, Guy L (DOA) From: David Kumar <David.Kumar@cookinlet.net> Sent: Friday, January 09, 2015 9:48 AM To: Regg,James B (DOA) Cc: Schwartz, Guy L (DOA) Subject: Re: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing v /4 -16 er- Thank you for the quick response. Will keep you informed Thanks and Regards David Kumar From:<Regg>, "James B (DOA)" <jim.regg(a@alaska.gov> Date: Friday,January 9,2015 at 9:04 AM To: David Kumar<david.kumar@cookinlet.net> Cc: "Schwartz,Guy L(DOA)"<guy.schwartz@alaska.go\ > Subject: RE: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing AOGCC will witness the SVS performance test once the well is online with stable production. Notification procedures are outlined in the attached guidance document;test witness notification form can be found at the following link:Test Witness Notification. If stabilized flowing conditions do not occur within 5 days of commencing production,contact me for further instructions about testing the SVS. 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: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Thursday, January 08, 2015 7:20 PM To: Regg, James B (DOA) Subject: Update on CIE's New Well at North Fork: NFU 24-26 for SVS Testing Dear Mr Regg, As per the regulation 20 AAC 25.265,Cook Inlet Energy(CIE) is supposed to offer the Commission a witnessed SVS performance test after placing the well in service .CIE as usual function tested and ensured the closure of both the SSV and SSSV before perforating.As the Commission is well aware NFU 24-26 has three zones for potential production,which are isolated with a combination of packers and sliding sleeves. CIE perforated Zone 3 on 1/2/2015 and encountered water and was unsuccessful in unloading it. CIE perforated Zone 2 on 1/6/2014 and ran it briefly through test and was unsatisfied with the flow rates. CIE then proceeded to perforate Zone 1 on 1/7/2014 and was not able to detect any significant amount of gas.CIE is in the process of re-evaluating all these zones 1 Currently,we have a coil tubing unit on site getting ready to rig up and unload water from Zone 3.We are hoping to bring this zone to production. CIE will also be conducting the multipoint back pressure test on this zone as per 20 AAC 25.255 before placing the well into production. I am hoping that we should be able to offer the commission at the earliest, an opportunity to witness an official SVS performance test once this zone cleans up followed by conducting the multipoint back pressure test before placing in production due to ongoing well operations. If you wish to perform this test before or between the above mentioned events, please let me know at the earliest so that I can arrange for it . Please feel free to call me if you have any questions regarding this email Thanks and Regards David Kumar Production Manager Cook Inlet Energy o0 W.5th Acenua.Suite 310.Anchorage,AK 99501 007-133-3S22(Direct)!907-903-4164(Mobilel -- -5(Main) 1907-334-o735(Faa) David.Kumar@cookiniet.net 2 2- \SCP ♦ OF Ty 4,(PP I//7 e mss THE STATE Alaska Oil and Gas �rw�;,-ice �, of Conservation Commission ,, __== ALAsKA � t# 333 West Seventh Avenue trop--1 � GOVEKNOR BILL WALKER Anchorage, Alaska 99501-3572 �*+ Main: 907.279.1433 OFALAS Fax: 907.276.7542 www.aogcc alaska.gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage, AK 99501 Re: North Fork Field,Undefined Gas Pool,North Fork Unit 24-26 Sundry Number: 315-014 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, Cathy P. •erster Chair DATED this1-1C-lay of January, 2015 Encl. •- RECEIVED • r STATE OF ALASKA JAN 0 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION S I) 7 LIS pmAPPLICATION FOR SUNDRY APPROVALS AOGCO ‘11/15 20 AAC 25.280 1.Type of Request: Abando❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspen[] Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdow❑ Re-enter Susp.Well❑ Stimulate, Alter Casing❑ Other: IQ-.r L-j-cI- ❑ 2.Operator Name• 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory Q Development ❑ 214-166 • 3.Address: Stratigraphic ❑ Service ICI 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20045-00-00 • 7.If perforating: C• ,j -7 s- 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? - , lS pgr-- r Will planned perforations require a spacing exception? Yes ❑., No 0 q,d,l....F„ Unit 24-26 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211 • Development North Fork Undefinded Gas ' 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): 9750' 9404' 9750' 9404' None None Casing Length Size MD TVD Burst Collapse Structural 120' 20" 120' 120' N/A Conductor Surface 2946' 9 5/8" 2946' 2821' 5750 3090 Intermediate Production 9725' 7" 9725' 9379' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Wellbore See Wellbore 2 7/8"6.5# L80 EUE 9,026' Packers and SSSV Type: SSSV:Halliburton Packers and SSSV MD(ft)and TVD(ft): SSSV:349'MD/TVD 2 x Halliburton Hydraulic Retr.PHL Packer,1 Olgoonik DHL Packer Packers:5194',5,851',8415'MD/4896',5497',8069'TVD 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q •Service ❑ 14.Estimated Date for 1/7/2015 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 7.Thereby hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Courtney Rust 907-433-3809 Email courtney.rust@cookinlet.net Printed Name Conrad erry,Drilling Manager 727-7404 Title 1/7/2015 Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a esentative may witness Sundry Number: Plug Integrity ❑ BOP Test EV Mechanical Integrity Test ❑ n _Location Clearance 0 1 Other: hc- 3 . 7:----.„ t C/! �TS7-2 .3 :0/.. 5c f G�S�i.7 15- Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /c,- Y 0 7 (' L.-•,-,..1;. L L, r 4,44,...i,- APPROVED BY Approved by:L/ 4,1 /" -4-Cr J,�� COMMISSIONER THE COMMISSION Date. / 7... / i-7. /5' `41/L- Form .t• Submit Form andForm 10-403(Revised 10/2012) 12 months from the date of approval. // A ch S n smin Duplicate , ee n . .r nn. !/ / /_ — , . , -7 _ fir" Cook Inlet Energy_ RECEIVED January 7, 2015 JAN 0 7 2015 Ms. Cathy Foerster, Chair AOGGC 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 24 26 API: 50-231-20045-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 24-26, PTD: 214-166 requesting the use of coil tubing to bring the well on to production. If you have any questions, please contact me at (907) 727-7404. Sincerely, Conrad erry Drilling Manager- Cook Inlet Energy 1 Cook Inlet Energy_ 1. WELL NAME - North Fork Unit 24 26 Requirements of 20 AAC 25.0050 Well Summary Current Status: Well has been drilled to TD, completed, and we have begun perforating zones. At this time we are requesting the use of coil tubing to clean the water off the well. Scope of Work: • Rig up coil tubing • Use nitrogen to lift the well General Well Information: Reservoir Pressure /TVD: 3728 psi @ 8,670'TVD MASP: 3,300 psi Wellhead Type/Pressure Rating: 11" Multi-bowl 5K Wellhead Well Type: Gas Well Estimated Start Date: January 7, 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_ Coil Program 1. Move in and RU coil 2. Test Coil BOPs to 35.00-PSI 3. Conduct Simops safety meeting with drilling on NFU 42-35 4. RIH to expected fluid level at 5900' and start N2 5. Continue until well is clean to bottom of perforations at 9016' • 6. Take returns to blow down tank until well comes in then switch to production 7. POH 8. Repeat as necessary to remove water from well bore. 3 NFU 24 26 Proposed Completion 12/18/2014 TRSSSV @+/-349' 2 7/8"Chemical Injection mandrel @+/-2517' 20" L80 120'TVD 120# BTC 120'MD • All sleeves shift down to 12 1/4"Hole open and up to close. , 9 5/8" L80 2,750'TVD 40#SD BTC 2,870'MD Sliding Sleeve @ 5,147' Zone#1 1. I HB PHL Hydraulic Set Packer©5,194' Sliding Sleeve @5,213'MD Y Block 2"guns 0 degree phase 5,261.89'to 5,279.89' 5,764.92'to 5,799.92' Zone#2 111111 HB PHL Hydraulic Set Packer @ 5,851' Sliding Sleeve @5,897'MD Y Block 2"guns 0 degree phase 5,911.34'to 5,934.34' cap 5,990.57'to 6,004.57' 2 7/8"6.5#L80 EUE-M Tubing Zone#3 OLG DHL Hydraulic Set Packer @ 8,415' XN Nipple @ 8,460' 4 5/8"TCP or 2"Wireline Guns 8,970'to 9,016' 1. 8 3/4"hole TD >c 7" L80 9,379'TVD 9,404'TVD 26# GEOCON 9,725'MD 9,750'MD Future Perfs 8,494'to 8528' Note It is as tied into WLM which is 4'Shallower than tubing measurements 0' 8,917'to 8,932' WLM=4'Tubing measurements.Packer Details on next tab P.m 2a4I(o Regg, James B (DOA) From: North ForkDSM <northforkdsm@cookinlet.net> &r6.1 (Zf 4IQ� Sent: Saturday, December 27, 2014 10:49 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: FW: BOPE Test Report Attachments: BOP Test NFU 24-26 AOGCC 12-24-14 Charts A.pdf Drill Site Manager/Cook Inlet Energy North Fork Unit / 907-433-3549 northforkdsm(a.cookinlet.net From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Friday, December 26, 2014 4:59 PM To: North ForkDSM Subject: RE: BOPE Test Report Corrected test report attached to the extent I can verify test results. I cannot follow the test sequence as presented on the test charts (compared to the written test procedure). The following comments are based on my review of 12-24-14 BOPE test charts: - API# is incorrect on all charts - Only 3 test charts show the reported test date 12-24-14; one chart is labeled 12-23-13; four test charts do not have a date - Some of the tests are not labeled (indicate component failures); one appears to be a test of the hydraulic choke - Test report lists 13 Choke Manifold valves; no documentation of testing valve 13. 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: North ForkDSM [mailto:northforkdsm©acookinlet.net] Sent: Thursday, December 25, 2014 9:30 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: BOPE Test Report Drill Site Manager I Cook Inlet Energy 549 northforkdsm(a�cookinlet.net 1 STATE OF ALASKA n, OIL AND GAS CONSERVATION COMMISSION ge ' SIJ repard--- BOPE Test Report Submit to: jim.regq a( ,alaska.gov AOGCC.Inspectors(a alaska.gov -j2_ (LI 3JI t k phoebe.brooks a(�alaska.gov Contractor: Miller Rig No.: 37 DATE: 12/24/14 Rig Rep.: J Steiner/L.Benjamin Rig Phone: 907 272-5004 Operator: Cook Inlet Energy Op. Phone: 907 272-5003 Rep.: R Maniaci/T.McKiernen E-Mail northforkdsm©cookinlet.net Well Name: NFU 24-26 PTD# 2141660 Sundry# N/A Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly: Test Pressure(psi): Rams: 250/4000 Annular: 250/2500 Valves. 250/4000 MASP: 3543 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8"5k P Pit Level Indicators P P #1 Rams 1 2 7/8" FP ' Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7/8"x 5 1/2" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/16 x 5k P Inside Reel valves 0 NA HCR Valves 1 3 1/16 x 5k P Kill Line Valves 3 2 1/8"x 5k P Check Valve 1 2 1/8"x 5k P ACCUMULATOR SYSTEM: BOP Misc 3 leaks FP - Time/Pressure Test Result System Pressure(psi) 3000 P CHOKE MANIFOLD: Pressure After Closure(psi) 1500 P 1 Quantity Test Result 200 psi Attained (sec) 26 P No Valves 12 P Full Pressure Attained(sec) 175 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (#and psi): 4/2025 P CH Misc 1 FP ✓ ACC Misc 0 NA Test Results Number of Failures: 5 Test Time. 17.5 , Hours I Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors aealaska.gov Remarks: Plug on choke manifold leaked, tighten and retest OK. Upper Pipe Ram leaked, open doors, inspect and dress, still would not test, Install new rams, retest OK Bottom flange on LPR body had slight leak, made up same and retest OK Grey Lok clamp on kill-line leaked, replace gasket, retest OK. AOGCC Inspection 24 hr Notice Yes Date/Time 12/17/2014 Waived By Jim Regg Test Start Date/Time. 12/24/2014 1:00 - (date) (time) _ Witness Test Finish Date/Time 12/24/2014 18:30 Form 10-424(Revised 06/2014) 2014-1224_BOP_Miller37_NFU_24-26.xlsx AAOA vPSI I JOB SAFETY CIE Rig 37 Job/Task/Operation Analysis performed by: Approved by: Pete Dickins Analysis revised by: Approved by: Crew: +� i9t_4c� -1-i Additional rroc Potential Hazards 1. Verify that well is static. Well control 2. Drain BOP stack. Leave annulus valve open. Working around cellar Annulus must be monitored when in open position. Pinch points installing test sub 3. Remove wear bushing. (back out lock down screws) Misalignment of valves 4, Make up test joint to test plug. Seat test plug in Trapped pressure well head. Equipment failure 5. Make up side entry sub, safety valve and IBOP valve to test joint. Hook up test manifold to side entry sub. Make up test sub to top drive. Use jumper hose to connect test manifold to TD test sub. 6. Close choke manifold valves# 10, 11 & 12. Open remainder of valves. Open needle valve on top of choke manifold to vent air. Open Super Choke. 7. Fill BOP and CMVs with water to top of annular, close annular, continue to fill to top of IBOP, close IBOP, continue to fill to top of needle valve. Open Kill line valve & bleed valve on standpipe manifold. 8. Install test chart and set clock on "96" minute 9 Test BOPE- 1st test, Annular, IBOP, Check Valve, re, # 1, 10, 11, & 12 CMVs. )lug from chk valve, Upper Rams, Safety valve, Outside Kill, Lower TO, #6, 8 & 9 CMV Disconnect Top Drive, blow down if necessary. 3rd test, Inside Kill, #2, 7 & 5 CMVs 4th test, HCR 5th test, Inside choke line valve 6th test, Lower pipe rams Unscrew from test plug & remove test joint. 7th test, Blind rams, # 3 &4 CMVs 10.Screw test joint into test plug. .Perform accumulator precharge test. Test gas alarms. 11.Pull test plug and rig down test equipment. 12.Install wear bushing & close annulus valve. 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',-- - k I � I 1 _ I '-. { f ffO Nru Op% O 0LocATtoN - " TOO / PEMARKS _ N / / `-- zH / / / /i \\ \ F Of ' /OD1 / i \ \ Op f --' Op / \ ‘\\ \ \ \\'''':24,...„7:..,..„700g.----,-, 1 , �.y /')\� o // \ 1 •-, -' 1 / / \,....,c(.,:> \\NN NN,,,/ '''''''--„j : - - __,-- \ VA>CP c:// // / ib 4op - _ ._ r �p �' oo0 /Of _ __- i \\N. -..-7 °C) --- - ,V)C Cf / CV -- __ _ -- .Ar..--' ,,,,,,,,7\-.)0 /././ sb_ ex- Niiiiii. 0as\\ � s - , — , \ q — wd 9 P 214 i ►cC,c Regg, James B (DOA) From: North ForkDSM <northforkdsm@cookinlet.net> ` 'ef ll (2_1N)114 Sent: Saturday, December 27, 2014 5:04 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA) Subject: Production packer test. Attachments: Upper annulus test to top production packer Test NFU 24-26_12-27-14.pdf Test on Upper production packer on NFU 24-26 completion. i%e, s n Fork northforkdsm(a cookinlet.net 1 11 NOON 9 5500 I �/ __ _ 500074_ _ 7..N.,, / _� _ 4___ 4000 j-� --3500 . ,`-----„Z ---"--..--,•-_, .._----- _ 3000o 63 O ___ 2500 o -' 2000 o T, eo /\ / P� ,/ \-\\_____\. O° �° /�' 1500 \ \ \ �`� o°/ L ,00- i >,,,, , ' / • l / f ppo ,~ ' ,� 1, / / `p0 .: \ l SO N000 X00. / / J i jr ! `po� ��` 000 O \ A-- ! i - , k) �� i._ 1 ,� ,-, )6* a�y..s.„ '' eto - / 1 ; ! i _ _ _ i _ _ 1 _ ‘`r ZS R3 T . o l _ o 00 00�\ U �� o oc) . —\ ; o (t iAJ o . 0 `o o 000 0� F `� Cr o° Oti 0 0 N CI/ �l o 00 0 00 , o,�, . or, /-.1.- •••, (0 rt., ,�� 1 �\. . O\ a� `t \\ - -4. ~ OOS t / pow / 1 j '� p0°. _ . 1 i \ /% 0001-' OOSi / ~ ,� OOOZ �__ f� j .--\-----:______77) : -- _ --: ____------4----- � 000 OQg _ oars I __ 1 P-ro 214 -/Lc Loepp, Victoria T (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Friday, December 26, 2014 8:16 AM To: Schwartz, Guy L(DOA) Cc: Regg, James B (DOA); Loepp, Victoria T (DOA); Stephen Ratcliff; Conrad Perry; Evan Harness;Tyler Wagner Subject: PTD 214-166 NFU 24 26 Summaries Attachments: NFU 24 26 PTD 214 166 Summaries.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, Please find the daily drilling summaries for the NFU 24 26 well attached.We have reached TD, ran our 7"casing,cemented, and are currently running our completion. Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 North Fork Unit 24 26 PTD: 214-166 Drilling Summaries 11-20-14 to 11-23-14 Rig Move, site prep 11-24-14 Diverter test. 11-25-14 Diverter Test 11-26-14 PU BHA and HWDP, Spud Weil. Drill from 140'-156' 11-27-14 Drill from 156'-430'. 11-28-14 Drill ahead from 430'-1295'. 11-29-14 Drill ahead from 1295'-2157'. 11-30-14 Drill ahead from 2157'-2946'.TD hole section. Circ and condition for short trip. Pump dry job. 12-1-14 Short trip and RIH back to bottom. Circulate. POH RU for casing 12-2-14 RU to run casing. Run 9 5/8" 40# Special Drift casing to 2943'. Circulate and reciprocate casing. 12-3-14 RU cementers. Pump spacer,test lines, 38 bbls 9.6# Batch and pump lead 12.5#, 281 bbl total lead. Pump 14.8#tail cement 41 bbl,kick out top plug and displace cement. Bump plug.WOC. ND Diverter 12-4-14 ND Annular Install 9 5/8"wellhead test void. NU BOPE. 12-5-14 NU and test BOPE. PU BHA. 12-6-14 PU Directional and MWD tools. Load LWD nuclear source. RIH to bottom.Test Casing to 3000psi. Drill cement to 2890'. Drill up float equipment from 2890 to 2938. Drill ahead from 2946 to 2970. CBU. Perform FIT, EMW of 13.62 ppg. Drill ahead to 3230. 12-7-14 Drill ahead from 3230-4300'. 12-8-14 Drill ahead from 4300'-5490' 12-9-14 CBU. Drill ahead from 5490'-6144'. 12-10-14 Drill ahead from 6144'-6837. POH. 12-11-14 POH.Test BOPE. 12-12-14 Continue testing BOPE. Run CBL. RD wireline. PU motor and BHA. RIH. Drill ahead to 6852'. 12-13-14 Drill ahead from 6852'-7596'. 12-14-14 Short trip. Drill ahead from 7596'-8522' 12-15-14 Drill ahead from 8522'-8970'. Short trip. 12-16-14 Continue POH. RIH to 5000'. 12-17-14 RIH to bottom. Drill ahead to 9524'. 12-18-14 Drill ahead to TD @ 9750'MD. Pump HI VIS Sweep. POH. LD drill pipe. 12-19-14 LD pipe, LWD tools, PU 5"test joint,test BOPE. 12-20-14 Continue testing BOPE. RU Weatherford CRT. PU 7" shoe track RIH to 3970'. 12-21-14 RIH with 7" casing to 9740'. 12-22-14 RU cementers. Drop bottom plug and chase with water. Pressure test lines. Pump 38.5 bbl spacer batch 12.7 ppg class G cement,pump 161 bbl,pump 99.5 tail cement at 13.5 ppg. Drop top plug and displace with 371 bbl 8.5 ppg 3%KCL brine. Bump plug. RD cementers, LD 5" 12-23-14 Change rams and test BOPE. PU Pollards for CBL. RD Pollards. Change rams to VBR and test. 12-24-14 Test BOPE.Test casing to 4000 psi. PU and RIH with taper mill and scraper. 12-25-14 Continue clean out. Run guage ring. LD tools. RU to run completion. PU guns. Tii•(COF ��7 ?,v THE STATE Alaska Oil and Gas s �A, o Conservation Commission �. - - ==� fALASI�:.A • �4 -ice_ _ :_ 333 West Seventh Avenue '" ; GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ti t. Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool, NFU 24-26 Sundry Number: 314-676 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, 1 9 1 Ale D avid J. Mayberry Commissioner DATED this 13"day of December, 2014. Encl. ' RECEIVED STATE OF ALASKA DEC 18 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION D7S )21231 (4— 0 fey APPLICATION FOR SUNDRY APPROVALS 0300 Ilo 20 AAC 25.280 1.Type of Request: Abandon Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program n Suspen❑ Plug Perforations❑ Perforate❑✓ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q 214-166 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-231-20045-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes 0 No ❑ N, +Foit_Unit 24 26 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211 Development North Fork Undefinded Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 6,592' 6,247' 6,592' 6,592' None None Casing Length Size MD ND Burst Collapse Structural 120' 20" 120' 120' N/A Conductor Surface 2946' 9 5/8" 2946' 2821' 5750 3090 Intermediate Production 9725' 7" 9725' 9379' 7240 5410 Liner 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 Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory LI Stratigraphic❑ Development[] Service ❑ 14.Estimated Date for 12/20/2014 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑✓ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: I Z- /c)^ p-i WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: s---;-_/.......-C' ....,_,{7.-- GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and orrect to the best of my knowledge. Contact Courtney Rust 907-433-3809 Email courtnev.rust(a�cookinlet.net Printed Name Conrad,Drilling ger 727-7404 Title 12/17/2014 Signature Atill ' • e Date / COMMISSION USE ONLY Conditions of approval: Notify Commission so tha Apresentative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: * Li 6&Q r, ,,,,: .66 ft- Ro,.vCitetl WQ va' dF' 2426?,5. 4J ( 9-vrre,J ent, 1:5Ofdr•ed , y L44 n accmrr�a4CG wr'r6 �o 2S` 2✓.SCd)CO F4.-,.47 O•- l '^ �' ^ jn an c/iOc, 'a1 i"' Spacing Exception Required? Yes ❑ No Ixl Subsequent Form Required: /n— , I l'` lel et,(7 �L • APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: P.12 3 f I y n j r1 A l Submit Form and RBDMSF 10-403(Revised 10/2012) v d I ��vn I a d for 1 onths from the date of approval. Attachments innDuplicate JAN - 4 253 - rz. Z. ,4' Cook Inlet Energy_ December 17, 2014 Ms. Cathy Foerster, Chair RECEIVED Alaska Oil and Gas Conservation Commission c 333 West 7th Ave., Suite 100 DEC 18 2014 Anchorage,Alaska 99501 AOGCC Re: Completion Sundry V Cook Inlet Energy, LLC: North Fork Unit 24 26 API: 50-231-20045-00-00 / PTD: 214-166 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completion sundry for North Fork Unit 24-26, PTD: 214-166. Included in the submittal is a completion program and proposed wellbore schematic. We are currently drilling ahead and expect to set our 7" casing sometime later next week immediately followed by our completion. 20 AAC 25.225. Potential of gas wells CIE requests waiver of the multipoint gas test for this development well. There are 5 producing wells in this field already with a significant amount of detailed well test data. CIE does commit to perform well tests on each of the completion zones within the first 6 months of production. "All gas wells must be tested by a multi-point back-pressure method before regular production. The commission will approve alternative test methods if the commission determines that they provide substantially the same information as the multi-point back- pressure method. The test results and calculations must be reported to the commission on the Gas Well Open Flow Potential Test Report (Form 10-421) within 30 days after the test." AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE is requesting permission to flare or vent in the unlikely event the well is difficult to bring on line and has to be taken to atmospheric pressure to clean up. If well cleanup is normal,it will be flowed immediately into the North Fork production facility. CIE requests permission to vent or flare gas from the North Fork Unit 24 26 well test for a period of 14 total 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 period. 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax If you have any questions, please contact me at (907)-727-7404. Sincerely, Conrad ' - ry - Drilling Manager- Cook Inlet Energy NFU 24 26 ProWused Completion 12/18/2014 SSSV @+1-350' 2 7/8"Chemical Injection i.-. . mandrel @+/-2500' 20" L80 120'TVD 120# BTC 120'MD ..:• t.I 1 1— ,r; 7 r' r0 w' ti 1 42 2 1/4"Hole In 9 5/8" L80 2,750'ND iT_ 40#SD BTC 2,870'MD Zone#1 • 'I ' I Hydraulic Set Packer @ 5,190' '7' Sliding Sleeve @5,250'MD Y Block 2"guns 0 degree phase 5,262'to 5,284' - , _ 5,765'to 5,800' -. _ Zone#2 Hydraulic Set Packer @ 5,850' Sliding Sleeve @5,880'MD s. Y Block 2"guns 0 degree phase m am 5,911'to 5,938' 5,990'to 6,004' !(14 2 7/8"6.5#L80 EUE-M Tubing Zone#3 Hydraulic Set Packer(r)8,450' XN Nipple @ 8,480' is Q 3 3/8"TCP or 2" , reline Guns m 8 3/4"hole 8,494'to 8528' 8,917'to 8,9 ' z ti z 8,970'to 9,'16' TD 4 =' 7" L80 9,379'ND 9,404'ND Ilk 26# GEOCON 9,725'MD 9,750'MD 1 / 1 a . NFU 24-26 Completion Procedure 12-18-2014 1) Displace 7" top plug with 3%filtered KCI Brine (+/-8.5 ppg) 2) Lay down 5" Drill Pipe 3) WOC for 24 hours—Rig up and Run CBL to TD. 4) Evaluate CBL. Develop Squeeze program if needed. 5) Test 7" Casing to 4,000 psi for 30 minutes on chart 6) Test BOPs to 4,000 psi on 2 7/8"tubing 7) Pick up 2 7/8"TCP Packer Assembly as follows: a. Mule shoe b. 3 3/8"TCP guns 6 spf for following intervals i. 8970'to 9016' ii. 8917'to 8922' iii. 8494'to 8528' c. TCP Drop Bar firing head without delay d. 2 7/8"XN nipple at 8480' e. Halliburton 7" Hydraulic Packer at 8450' f. 2 7/8"tubing to Halliburton Sliding sleeve (closed)at 5880' g. 2 x Halliburton 2"Y block guns strapped to 2 7/8"tubing with 18 minute delay pressure firing heads over following interval: i. 5990'to 6004' ii. 5911'to 5938' h. Halliburton 7" Hydraulic Packer at 5850' i. 2 7/8"tubing to Halliburton Sliding sleeve at 5250' j. 2 x Halliburton 2"Y block guns strapped to 2 7/8"tubing with 18 minute delay pressure firing heads over following interval: i. 5765'to 5800' ii. 5262'to 5284' k. Halliburton 7" Hydraulic Packer at 5190' I. Halliburton Sliding sleeve(closed)at 5160' m. 2 7/8"tubing to chemical injection mandrel at 2500' n. 2 7/8"tubing to Tubing Retrievable SSSV at 350'. o. 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 8480. Pressure up and set all three hydraulic packers according to Halliburton 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 4000 psi. 21) Swab well to have 1000 psi underbalance. 22) Drop bar and flow Zone 3 to Test. 23) At completion of Zone 3 test, set plug in XN nipple at 8480' 24) Open Sliding sleeve at 5880' 25) Rig up N2 26) Pressure up tubing with N2 to XXXX psi firing pressure. 27) Bleed pressure to result in 1000 psi underbalance with in 18 minute time delay 28) Fire guns and flow to test. 29) Close Sliding sleeve at 5880' 30) Open Sliding sleeve at 5250' 31) Rig up N2 32) Pressure up tubing with N2 to XXXX psi firing pressure. 33) Bleed pressure to result in 1000 psi underbalance with in 18 minute time delay 34) Fire guns and flow to test. Davies, Stephen F (DOA) From: Roby, David S (DOA) Sent: Monday, December 22, 2014 4:52 PM To: David Kumar; Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Cc: Conrad Perry; David Hall; Davies, Stephen F (DOA) Subject: RE: Cook Inlet Energy: NFU 24-26 Well Test David, The AOGCC's regulations for testing of gas wells requires a multi-point test for all gas wells, not just those that are not located in a well-established field. The only waiver option we have under the regulations is for an alternative testing method that will provide substantially the same information as a multi-point test. I do not believe that the testing that you propose below and in the sundry application would provide "substantially the same information" as a multi-point test. I also note that the regulations require the testing to be conducted prior to commencement of regular production yet in the sundry application it is stated that testing will occur within the first 6 months of production. As such, I will be recommending to the Commissioners that we not approve the requested waiver of 20 AAC 25.225. If you can come up with an alternative testing method that will provide substantially the same information as a multi-point test I'll reconsider my recommendation. In the sundry application there was also a request to vent or flare gas in association with well cleanup. Well cleanup itself is considered a normal oil and gas field operation and thus approval to vent or flare for that is not required. I am curious on what the basis of requesting authorization to flare or vent for 14 days during well cleanup is. Can you please provide more detail on how the 14 days were arrived at? After cleanup if flaring or venting is required to conduct the multi-point test then approval under 20 AAC 25.235(d)(6) is required and I will recommend to the Commissioners that we do approve flaring for the purposes of conducting the multi-point test, since this test is a regulatory requirement. If you have any questions please let me know. Regards, 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). If 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.robv@alaska.gov. From: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Monday, December 22, 2014 10:25 AM To: Roby, David S (DOA); Schwartz, Guy L (DOA) Cc: Conrad Perry; David Hall Subject: Cook Inlet Energy: NFU 24-26 Well Test Dear Mr. Roby, As per our phone conversation regarding the testing of our new well NFU 24-26 post completion, Cook Inlet Energy(CIE) is requesting a waiver for the conventional four point back pressure testing due to the following reasons: 1 , • North Fork unit is a well established field and there has been multiple well tests submitted to the Commission over different productive zones from existing wells at the pad. • Due to the back pressure ('x850 psi) exerted from the pipeline and flow restrictions,there will be a very narrow operating range over which the 4-point test will have to be conducted which might not fall in the 95%to the 75 range of the shut in well head pressure as recommended by the Commission. • For a proper multi-point back pressure test CIE will be forced to use a test skid which will result in flaring of gas over the entire period.This duration will be tripled due to the fact that we have three prospective zones included for individual testing. These zones are expected to flow at over 5 MMCF/Day depending upon choke settings • However, by conducting the well test via process, CIE will be able to provide the Commission will all data collected for all the three zones which would include Well Head Pressures (Flowing and Shut-in),Temperatures,Choke settings, Gas Properties,Volumes of any fluids recovered and well as their Composition and Stabilized Flow Rates at any Choke settings used. This will be able to provide the Commission with data on the productivity of these zones .This will also prevent any unnecessary flaring, expect when absolutely required for initial cleaning up of the well. If you have any questions regarding this matter, please don't hesitate to contact me. Thanks and Regards DAVID KUMAR Production Manager David Kumar@cookinlet net 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 19, 2014 2:28 PM To: 'Courtney Rust' Cc: Stephen Ratcliff; Conrad Perry; Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Sundry Completion Request for NFU 24-26 (ptd 214-166) Courtney, Verbal approval granted. Approved Sundry will outline well testing requirements once fully vetted by AOGCC reservoir engineer. (D Roby). 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: Courtney Rust [mailto:Courtney.Rust@cookinlet.net] Sent: Friday, December 19, 2014 2:12 PM To: Schwartz, Guy L (DOA) Cc: Stephen Ratcliff; Conrad Perry; Davies, Stephen F (DOA); Roby, David S (DOA) Subject: Re: Sundry Completion Request for NFU 24-26 (ptd 214-166) Guy, We are requesting verbal approval to run completion per the sundry we have submitted. Courtney Rust Cook Inlet Energy Drilling Engineer Cell: 907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential.If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 From:<Schwartz>, "Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Friday, December 19, 2014 5:03 PM To: courtney Rust< _irtney.rust@cookinlet.net>, Conrad Perry<Conrad.Perry@cookinlet.net> Cc:Stephen Ratcliff< tephen.Ratcliff@cookinlet.neL>, "Davies,Stephen F(DOA)"<steve.davies@alaska.gov>, "Roby, David S(DOA)" < ve.roby@alaska.gov> Subject: RE: Sundry Completion Request for NFU 24-26 (ptd 214-166) Conrad/Courtney, I think I have everything now. /need a request in writing (just email back)for verbal approval to run completion as per sundry. I will need to talk to Roby about the waiver on gas Potential tests but that can be settled later. He will be here Monday. Also, if CBL comes in different than expected (TOC or quality) then contact the Commission for follow-up cementing work before completion is run. 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(c�alaska.gov). From: Courtney Rust [mailto:Courtne'• ,st@cookinlet.net] Sent: Friday, December 19, 2014 12:59 PM To: Schwartz, Guy L (DOA); Conrad Perry Cc: Stephen Ratcliff; Davies, Stephen F (DOA) Subject: Re: Sundry Completion Request for NFU 24-26 Guy, Please find the updated wellhead diagram attached. From:<Schwartz>, "Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Friday, December 19,2014 1:53 PM To: Conrad Perry<conrad.perry@cookinlet.net> Cc: Courtney Rust<courtney.rust@cookinlet.net>,Stephen Ratcliff<Stephen.Ratcliff@cookinlet.net>, "Davies,Stephen F (DOA)"<steve.davies@alaska.gov> Subject: RE:Sundry Completion Request for NFU 24-26 Conrad, Which pools are associated with the 3 zones? May be some comingling issues that need to be addressed. Also the well sketch shows a liner hanger at the surface casing shoe. I believe the 7" is run all the way back to surface. What type of SSSV at 350 ft? Noted on sketch but not actually shown. Also need a wellhead sketch and tree diagram .. SVS positioning shown. Guy Schwartz Senior Petroleum Engineer AOGCC 2 907-301-4533 cell 907-793-1226 office CONFIDENTIALITYNOTICE: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.schwartzalaska.gov). From: Conrad Perry [mailto:Conrad.Perry(a�cookinlet.net] Sent: Thursday, December 18, 2014 4:27 PM To: Schwartz, Guy L (DOA) Cc: Courtney Rust; Stephen Ratcliff Subject: Sundry Completion Request for NFU 24-26 Guy, We have just dropped off the completion sundry for NFU 24-26. We are completing it in three zones isolated by packers and sliding sleeves. The lower zone will be perforated with conventional TCP/drop bar firing head. The upper two zones will be perforated with Y Blocks (2" pressure fired guns clamped to the 2 7/8"tubing.) This was successfully used on our Sword#1 well G zone completion. It allows us to selectively perforate each of the two upper zones underbalanced. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage,AK 99501 (907)433-3816—Office (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356-Cabin conrad.perry@cookinlet.net CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. 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If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 3 NFU 24 26 Proposed Completion 12/18/2014 TRSSSV @+/-350' 2 7/8"Chemical Injection mandrel @+/-2500' 20" L80 120'ND 120# BTC 120'MD 12 1/4"Hole 9 5/8" L80 2,750'ND 1- 40#SD BTC 2,870'MD Sliding Sleeve @ 5,160' Zone#1 1>'r- I Hydraulic Set Packer @ 5,190' Sliding Sleeve @5,250'MD Y Block 2"guns 0 degree phase 5,262'to 5,284' 5,765'to 5,800' Zone#2 Hydraulic Set Packer @ 5,850' Sliding Sleeve @5,880'MD Y Block 2"guns 0 degree phase 5,911'to 5,938' CIE 5,990'to 6,004' -"tr _ 1 2 7/8"6.5#L80 EUE-M Tubing v Hydraulic Set Packer @ 8,450' XN Nipple @ 8,480' =ix K2 3 3/8"TCP or 2"Wireline Guns 8 3/4"hole 8,494'to 8528' 8,917'to 8,932' ao 8,970'to 9,016' TD r, = 7" L80 9,379'ND 9,404'ND 26# GEOCON 9,725'MD 9,750'MD • • . 1.6 GE Oil & Gas 36.6" (:, 30.2' o 2-9116"5M Qo (ol A 0 29/16'5M 2-0/18'5M B T .i 1 _� 11.a• • • uu iim 1 /•• L INIMENI 2-9/16'5M - - 2-9/16"SM;• ::'((-O)) 1 1. �o c ._!--- „,,_,_—_—_„.,,„r.f 45.8” iiirr-''— ®(•.,.- 2-9116'SM 127.2" \ ''.111\ / __.1__ # 11"5W kit — M7---1",, + ' 1 28.5'to c 19.0" t �i ��_. al �1 ( 71"5M 1i. ' =i I� J ' _ a\, 2-1116'5M 1..—► , I Ili -\ I II ETIG.` j ( 28.5"toL �11� 1 l I r3 i _ �� I 1� . 11_ y 31.7" aur1._ ;a11.OYO� 1. —. _ 2-1/16"5M ill A 1.11.111111111111 26"O.D.Base Plate 9-5/8''Casing T 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 ENERGY neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. NFU 24-26 DRAWN VJK 19DEC14 9-5/8" x 7" x 2-7/8" 5M SH2 Wellhead Assembly, APPRV KN 19DEC14 With T-M40-CCL Tubing Hanger and M40-CCLAdapter Flange FOR REFERENCE ONLY DRAWING NO. 1001107-1C Davies, Stephen F (DOA) From: Tim Jones <Tim.Jones@cookinlet.net> Sent: Thursday, November 13, 2014 8:30 AM To: Davies, Stephen F (DOA) A_i -lr5-• ey' Subject: RE: NFU 24-26 Bottom-hole Location Questtion 16 ��: i„.-" C Steve, . y --t,/j ( " AiD From our head geologist— 1) ,,,,/,(y/ . t ,,f i The subject well is being planned at its current location in order to capture gds reserves not currently capable of being drained by existing wells in an upthrown fault closure. The well as designed would be between 1500' and 2000' away from the closest well capable of production i ' xisting reservoirs. Multiple objectives have potential for gas production in the proposed well, some of which are not Eurrently being produced in the adjacent wellbores. As designed, the well will be the Northern most well drilled in the fault block. Structural closure in this Fault block strikes North South along the normal fault. A successful completion in the NFU 24-26 well could significantly extend reservoir limits and may prove up one to two more locations. In order to drill a well conforming to current spacing the well would have to penetrate objective sands in Sec 27 T 4S R 14W. As currently interpreted, this would be significantly downdip and most likely below currently established Lowest Known limits for the existing gas reservoirs. A well drilled conforming to current spacing would be a very high risk project and likely would not meet minimum economic criteria. Please let me know if you need any further information. Tim From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent:Wednesday, November 12, 2014 2:52 PM To:Tim Jones Subject: NFU 24-26 Bottom-hole Location Questtion Tim, Could CIE provide a brief statement as to why CIE has chosen the planned bottom-hole location for North Fork Unit No. 24-26 rather than drilling the well to a bottom-hole location that conforms to statewide spacing regulations? Please let me know if you have any questions or if I can help further. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 1 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 • r°tk4 Regg, James B (DOA) From: North ForkDSM <northforkdsm@cookinlet.net> Sent: Tuesday, December 23, 2014 9:20 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: BOPE Test Report Attachments: BOP Test NFU 24-26 AOGCC 12-19-14.xls Updated BOP test form. Drill Site Manager/Cook Inlet Energy North Fork Unit / 907-433-3549 northforkdsmacookinlet.net From: North ForkDSM Sent: Monday, December 22, 2014 10:06 PM To: Jim Regg (jim.regg@alaska.gov); 'AOGCC.Inspectors@alaska.gov'; 'phoebe.brooks@alaska.gov' Subject: RE: BOPE Test Report Drill Site Manager l Cook Inlet Energy North Fork Univ northforkdsm(a)cookinlet.net From: North ForkDSM Sent: Monday, December 22, 2014 9:59 PM To: Jim Regg (jim.regg@alaska.gov); 'AOGCC.Inspectors@alaska.gov'; 'phoebe.brooks@alaska.gov' Subject: RE: BOPE Test Report 8 MB northforkdsmAcookinlet.net From: North ForkDSM Sent: Monday, December 22, 2014 9:42 PM To: Jim Regg (jim.re•g@alaska.gov); 'AOGCC.Inspectors@alaska.gov'; 'phoebe.brooks@alaska.gov' Subject: RE: BOPE Test Report Drill Site Manager/Cook Inlet Energy North Fork Unit / 907-433-3549 northforkdsm(a.cookinlet.net From: North ForkDSM Sent: Monday, December 22, 2014 7:45 PM To: Jim Regg (jim.regg@alaska.gov); 'AOGCC.Inspectors@alaska.gov'; 'phoebe.brooks@alaska.gov' Subject: RE: BOPE Test Report 0 - 44 T A y� - lR:l r� �? 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O �° r° tit - \ -\ , }._ /`y — — NOI1V001 0 O0 .-0- O- 0 0U 0C -! � fl w M �10 O O O O 0 0 O 0 Cn NO 1nd laVHO . ._ I 0 330 N3KV1 z 83.13w � / I 1 =i _--- ao 0009-dW ��_ . o .0 0W ON IYH0 vN \ iri, � 7I '2 V1qt x.,>. / // i,iu��x�lply; II f , 00! °p1 ., / j x Q001 �� .S p 0002 — N , '' -- .1 - - 4-7; --:-\" . / - c-7 / 1 00 ti_r 0 t .64 p o r Q - c ..- r - .--"--:--I-:" 00 - _ 1,-_,_-_--_,,:....-,iiii,:::::,,,,_-,:,, ooc,c), /./ Cv ....r Ogs, - - —t 4 Loepp, Victoria T (DOA) From: Roby, David S (DOA) Sent: Monday, December 22, 2014 4:52 PM To: David Kumar; Schwartz, Guy L(DOA); Loepp, Victoria T (DOA) Cc: Conrad Perry; David Hall; Davies, Stephen F (DOA) Subject: RE: Cook Inlet Energy: NFU 24-26 Well Test Follow Up Flag: Follow up Flag Status: Flagged David, The AOGCC's regulations for testing of gas wells requires a multi-point test for all gas wells, not just those that are not located in a well-established field. The only waiver option we have under the regulations is for an alternative testing method that will provide substantially the same information as a multi-point test. I do not believe that the testing that you propose below and in the sundry application would provide "substantially the same information" as a multi-point test. I also note that the regulations require the testing to be conducted prior to commencement of regular production yet in the sundry application it is stated that testing will occur within the first 6 months of production. As such, I will be recommending to the Commissioners that we not approve the requested waiver of 20 AAC 25.225. If you can come up with an alternative testing method that will provide substantially the same information as a multi-point test I'll reconsider my recommendation. In the sundry application there was also a request to vent or flare gas in association with well cleanup. Well cleanup itself is considered a normal oil and gas field operation and thus approval to vent or flare for that is not required. I am curious on what the basis of requesting authorization to flare or vent for 14 days during well cleanup is. Can you please provide more detail on how the 14 days were arrived at? After cleanup if flaring or venting is required to conduct the multi-point test then approval under 20 AAC 25.235(d)(6) is required and I will recommend to the Commissioners that we do approve flaring for the purposes of conducting the multi-point test, since this test is a regulatory requirement. If you have any questions please let me know. Regards, 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.robv@alaska.aov. From: David Kumar [mailto:David.Kumar@cookinlet.net] Sent: Monday, December 22, 2014 10:25 AM To: Roby, David S (DOA); Schwartz, Guy L(DOA) Cc: Conrad Perry; David Hall Subject: Cook Inlet Energy: NFU 24-26 Well Test Dear Mr. Roby, 1 As per our phone conversation regarding the testing of our new well NFU 24-26 post completion, Cook Inlet Energy(CIE) is requesting a waiver for the conventional four point back pressure testing due to the following reasons: • North Fork unit is a well established field and there has been multiple well tests submitted to the Commission over different productive zones from existing wells at the pad. • Due to the back pressure("850 psi)exerted from the pipeline and flow restrictions,there will be a very narrow operating range over which the 4-point test will have to be conducted which might not fall in the 95%to the 75% range of the shut in well head pressure as recommended by the Commission. • For a proper multi-point back pressure test CIE will be forced to use a test skid which will result in flaring of gas over the entire period.This duration will be tripled due to the fact that we have three prospective zones included for individual testing.These zones are expected to flow at over 5 MMCF/Day depending upon choke settings • However, by conducting the well test via process,CIE will be able to provide the Commission will all data collected for all the three zones which would include Well Head Pressures(Flowing and Shut-in),Temperatures,Choke settings, Gas Properties,Volumes of any fluids recovered and well as their Composition and Stabilized Flow Rates at any Choke settings used.This will be able to provide the Commission with data on the productivity of these zones.This will also prevent any unnecessary flaring,expect when absolutely required for initial cleaning up of the well. If you have any questions regarding this matter, please don't hesitate to contact me. Thanks and Regards DAVID KU MAR Production Manager {.:.:;1 11,11.t E-t..a;Y J[i,r,ver:uc,Suite 310,Anchorage.AK 99501 907-433-3822(Direct)1907-903-4164(Mobile) 907-334-6745(Main) I 907-334-6735(Fax) David.Kumar@c oohinlet.net 2 Loepp, Victoria T (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Friday, December 19, 2014 11:08 AM To: Schwartz, Guy L (DOA) Cc: Loepp,Victoria T (DOA); Regg,James B (DOA); Stephen Ratcliff; Conrad Perry; Evan Harness;Tyler Wagner Subject: NFU PTD: 214 166 Drilling Summaries Attachments: NFU 24 26 PTD 214 166 Summaries.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, Please find our daily drilling summaries attached for the NFU 24 26 well. We have reached TD. Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE: This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 North Fork Unit 24 26 PTD: 214-166 Drilling Summaries 11-20-14 to 11-23-14 Rig Move,site prep 11-24-14 Diverter test. 11-25-14 Diverter Test 11-26-14 PU BHA and HWDP, Spud Well. Drill from 140'-156' 11-27-14 Drill from 156'-430'. 11-28-14 Drill ahead from 430'-1295'. 11-29-14 Drill ahead from 1295'-2157'. 11-30-14 Drill ahead from 2157'-2946'.TD hole section. Circ and condition for short trip. Pump dry job. 12-1-14 Short trip and RIH back to bottom. Circulate. POH RU for casing 12-2-14 RU to run casing. Run 9 5/8" 40#Special Drift casing to 2943'. Circulate and reciprocate casing. 12-3-14 RU cementers. Pump spacer,test lines, 38 bbls 9.6# Batch and pump lead 12.5#, 281 bbl total lead. Pump 14.8#tail cement 41 bbl,kick out top plug and displace cement. Bump plug.WOC. ND Diverter 12-4-14 ND Annular Install 9 5/8"wellhead test void. NU BOPE. 12-5-14 NU and test BOPE. PU BHA. 12-6-14 PU Directional and MWD tools. Load LWD nuclear source. RIH to bottom.Test Casing to 3000psi. Drill cement to 2890'. Drill up float equipment from 2890 to 2938. Drill ahead from 2946 to 2970. CBU. Perform FIT, EMW of 13.62 ppg. Drill ahead to 3230. 12-7-14 Drill ahead from 3230-4300'. 12-8-14 Drill ahead from 4300'-5490' 12-9-14 CBU. Drill ahead from 5490'-6144'. 12-10-14 Drill ahead from 6144'-6837. POH. 12-11-14 POH.Test BOPE. 12-12-14 Continue testing BOPE. Run CBL. RD wireline. PU motor and BHA. RIH. Drill ahead to 6852'. 12-13-14 Drill ahead from 6852'-7596'. 12-14-14 Short trip. Drill ahead from 7596'-8522' 12-15-14 Drill ahead from 8522'-8970'. Short trip. 12-16-14 Continue POH. RIH to 5000'. 12-17-14 RIH to bottom. Drill ahead to 9524'. 12-18-14 Drill ahead to TD @ 9750'MD. Pump HI VIS Sweep. POH. LD drill pipe. 214 c. Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, December 19, 2014 8:31 AM To: Courtney Rust Cc: Loepp, Victoria T (DOA);Wallace, Chris D (DOA) Subject: RE: 214-166 Sundry Application Will look at it today and see if I can get verbal ...Victoria will cover for me next week. 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(907-793-12261 or(Guy.schwartz@alaska.gov). From: Courtney Rust [mailto:Courtnev.Rust©cookinlet.net] Sent: Friday, December 19, 2014 7:29 AM To: Schwartz, Guy L (DOA) Cc: Loepp, Victoria T(DOA); Wallace, Chris D (DOA) Subject: PTD: 214-166 Sundry Application Guy, I have attached a corrected well bore for the completion sundry.The previous version was missing a sliding sleeve in the diagram. Also, I believe you are out this week?Whom may I contact(harass) about a verbal approval so that we might begin our completion on Sunday? Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE: This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 2 Loepp, Victoria T (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Friday, December 19, 2014 7:29 AM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA);Wallace, Chris D (DOA) Subject: PTD:214-166 Sundry Application Attachments: NFU 24 26 Completion Schematics 12-18.xlsx Guy, I have attached a corrected well bore for the completion sundry.The previous version was missing a sliding sleeve in the diagram. Also, I believe you are out this week?Whom may I contact(harass)about a verbal approval so that we might begin our completion on Sunday? Courtney Rust Cook Inlet Energy Drilling Engineer Office-907-433-3809 cell-907-350-0091 CONFIDENTIALITY NOTICE: This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review, disclosure,copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 3 NFU 24 26 Proposed Completion 12/18/2014 SSSV @+/-350' 2 7/8"Chemical Injection mandrel @+/-2500' 20" L80 120'TVD 120# BTC 120'MD 1 1 12 1/4"Hole 9 5/8" L80 2,750'TVD 40#SD BTC 2,870'MD Sliding Sleeve @ 5,160' Zone#1 r Hydraulic Set Packer @ 5,190' Sliding Sleeve @5,250'MD Y Block 2"guns 0 degree phase 5,262'to 5,284' 5,765'to 5,800' Zone#2 I' Hydraulic Set Packer @ 5,850' Sliding Sleeve @5,880'MD Y Block 2"guns 0 degree phase cap 5,911'to 5,938' cas 5,990'to 6,004' 1,14 2 7/8"6.5#L80 EUE-M Tubing v Hydraulic Set Packer @ 8,450' XN Nipple @ 8,480' 3 3/8"TCP or 2"Wireline Guns 8 3/4"hole 8,494'to 8528' 8,917'to 8,932' i i _ 8,970'to 9,016' TD z 7" L80 9,379'ND 9,404'ND a 26# GEOCON 9,725'MD 9,750'MD 1//7 :,,,s,,71 HE STATE 1�e,s . r:�i;- a.El 6mea ti f� � _-- --- s33 \ve, f Sc ,r h enue 11,,..-%.:,;.,-.,,,,,_:-..!...::-. � -_ ( o\'?.:oR SI:,\'‘ PARN I.L Anel oraae, t Save 99501 35.72 0 - F Lf.�. Stephan Hennigan Consulting Project Engineer Cook Inlet Energy 601 W. 5th Ave., Suite 310 Anchorage, AK 99503 Re: North Fork Field,North Fork Undefined Gas Pool,North Fork Unit #24-26 Cook Inlet Energy Permit No: 214-166 Surface Location: 648' FSL, 1542' FEL, SEC. 26, T4S, R14W Bottomhole Location: 190' FSL, 2220' FWL, SEC. 26, 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 drill and complete 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, avid . Mayberry Commissioner DATED this ((- ay of November, 2014. STATE OF ALASKA AL X OIL AND GAS CONSERVATION COMP DN PERMIT TO DRILL 20 MC 25.005 la.Type of Work: 1b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1c.Specify if well is proposed for: Drill 'E Lateral ❑ Stratigraphic Test ❑ Development-Gas❑� ' Service-Supply ❑ Multiple Zone E • Coalbed Gas 0 Gas Hydrates 0 Redrill 0 Reentry 0 Exploratory 0 Service- WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well 11 Well Name and Number: Cook Inlet Energy Bond No. l_b b(Z I Z4 7b 'a ,`"r"'" North Fork Unit #24-26 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3000 A Street,Suite 410-Anchorage AK 99503. MD: 10000' TVD: 9628' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 41 North Fork Surface: (, P.6JtfFSL&.,1•7•5131 FEL Sec 26 4S 14W - - 4 ,4p 91211 I-5912'1'0' ± 10.1 ' Top of Productive Horizon: 15'/2- /-,>,c)./5`-/`'• 8.Land Use Permit: 13.Approximate Spud Date: ' &' Sec 4 LOCI 10-004 20-Oct-14 • Total Depth: 9.Acres in Property: 14.Distance to Nearest Property,Lease 190'FSL&2220'FW L Sec 26 4S 14W 4 2520/1920 190 1750 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elev above MSL: 678 • feet 115.Distance to Nearest Well Open Surface: x- 199,870 ' y- 2,121,192 ' Zone- 4 GL Elev above MSL: 658 • feet to Same Pool: 1,450' 16.Deviated wells: Kickoff depth: ±300 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: ±24 degrees Downhole: 4506 • Surface: 3543 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 16 1/2 N8OHC Welded R3 0 0 120 120 Driven R3 0 0 na 12 1/4 9 5/8 40 N/L 80 SP DRFT BTC R3 0 0 2870 • 2750 Osx Lead @ Oppg+790sx Tail @ 12pp9 8 3/4 7 26 N/L 80 BTC-M R3 0 0 10000 • 9628 460sx Lead @ 13.5ppg+370sx Tail @ 15.8r 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 TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface 1 '0L--., Mel ' 1 . Intermediate r Production it C i (i 9 (iJ i Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): A.0 ;;!C 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21 Verbal Approval: Commission Representative: Date 10/9/2014 22. I hereby certify that the foregoing is true and correct. Contact Stephen Hennigan 337 849-5345 Email shennigan(a�peiinc.com Printed Name Stephen F.Hennigan Title Consulting Project Engineer for Cook Inlet Energy Signature ,„54,4•64----*".4•64----' g Phone (337)849-5345 Date 10/9/2014 Commission Use Only Permit to Drill -• /�{/��/�� API Number: � 2 '9`� ' �-�,` Permit Approval 1 I�I See cover letter for other Number: 7Z- l[�fCi' 50- / --ZL- )1/S Oa) Date: k\ \\14 14 requirements. . Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, s hydrates,or gas contained in shales: El 1 Other: - Li Q£c` ,/�s` BE, + 7";._5. Samples req'd: Yes❑ No ' Mud log req'd:Yes 0 No 1 I 7 H2S measures. Yes❑, Nog Directional svy req'd:Yes g No 0 i1 7 , 4`) I --1-7-) .(--- `---CSpacing exception req'd: Yes[ No0 Inclination-only svy req'd:Yes 0 No [V7 c/ .,, )cti,,v,t_i r e_ 7 Lt_...--r C--t t,/, (1-11_ 1,:c_e€ C 07,Lf(-k* ;.‘6-1--- , APPROVED BY Approved by. COMMISSIONER THE COMMISSION /Date:: t i)iii IL( �1 w0,/9'6/'ilbmd Form and rr Form 10-401(Revised 10/2012) This p it viliGr/NA to:the date of approval(20 AAC 25.005(g)) A t �nts in upe' ate Cook Inlet Energy_ RECEIVED October 9, 2014 OCT 0 9 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#24-26 Dear Ms. Foerster, Cook Inlet Energy, LLC (CIE)hereby applies for a Permit to Drill an onshore gas production well near Anchor Point on the Kenai Peninsula. CIE plans to spud the well in October, 2014. 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. A spacing exception is being submitted for this well. CIE requests permission to drill and complete,but not flow the well until the spacing exception is granted. This well is in a established e ct c,- producing field and is well within acreage we own and is farther than 3,000' from any other operators or landowners making correlative rights issues very unlikely. CIE understands the risks should the spacing exception be rejected. 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 • 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 and Clearance Report • Drilling Operations Plan • Wellhead diagram • Diagrams and Descriptions of the BOP Equipment to be used • Drilling Fluids • Solids handling and disposal 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Other information is included as well. 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 at 907.727.7404 Thank you. Sincerely, Conrad Perry Drilling Manager Cook Inlet Energy, LLC Enclosures Cc: file Stephen Hennigan—Petroleum Engineers for AAO and CIE 21Page hp EDGE OF R.O.W. *lib OF \%11 NORTH FRK ROAD of q� �s,II O RI V V N 2121143.9950 �� i 'en /1 cP, 00°' E 1340068.0700 / i yir 49 TH%\ *,I N 2121137.2190 ELEV 666.07' or E 656•6100 EDGE OF R.O.W• / /f/�/r`Y` 00 ELEV 656••' O. >C/ � / 4iiiii 00 A.-- 8 ONE55 " 660 ONE ,mak �, STAN A. McLANE a� .. am 63 �� ___-6�n 'P'‘,.6.,. 4637-S . �� Es- F .10/3/14.. =I l 0 ,I 1 1 ROFESS 1 ONP\-:`� :" Tract 18 �s rf (�h S GATE b f n Xp 7 f 34-26 WELL 32-35 WELL 14-25 WELL • � 1542' FEL ►- E_J 23-25 WELL j NFU 24-26 WELL X 1 x CD N:2121191.499- I ..--.1 E: 199870.419 - WI LAT:59°47'46.960"N I MIN LON: 151°37'46.655"W '' w <I o' NAD27 ASP Z4 - ' Li ELEV:657.8'(NAVD88) . I �I ' 61 I • I Elcr, \ ,,t, LU I U Tract 19 1 I CO 0 / I 0 North Fork Acres Subd. No. 2 r Ca of ~ J 1 0 �i 2 ! 0! W 652 655 /� QI 66.0 0! C660 665 bb 1 �� TOP OF BERM (11W a' N 2120505.98 ' I E 201396.26 S26 S25 Section 26,T04S,R14W,S.M.,AK. j ! I 0 S35 S36 c NOTES 1 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 NORTH ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS 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' "IIIIIIIIIIIII I"'iiiii1111111116111111" 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. SCALE 0 00 200 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 FEET AND NOT THE PROTRACTED SECTION CORNER VALUES. PROJECT REVISION: NORTH FORK 24-26 WELL DATE: 10/3/14 Cook Inlet Ener AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BOB Energy / NAD27 FOR INFORMATIONAL PURPOSES SCALE: 1'100' ONLY PROJECT NO. 143135 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. - ConsultIng Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET tit- 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 • h� \ • — . . — EDGE OF R.O.W. `��\�\\I�1 NORTH FORK ROAD _ �� OF q� 1�� _ ..qs�, _ — ; CP-2 �Q. 4) 100 RAIN N 2121143.9950 — CEJ ' �' ...-7 I' CP-1 E 1340068.0700 I *. 4 9 TH 1\ .. * N 2121137.2190 _____ELEV 666.07' , E 1339704.6100 EDGE OF R.O.W. N. 00 0. ELEV 656 R9 - / 73 _� 0 1._ 660 Off`— — IL I 1, STAN A. McLANE p_� .�-_ 6y3i . _ ` re --",t,;•..s, 4637—S .• 1` //////p �/// f _--� 6c n FPF 10/3/14 5 / m I O A ' . .. P�� (f• ( ''''11 er., I 0 —\ cp.: ( 1411%,XXN. N �� so Tract 18 a- GATESso so W In0 1 111! I 34-26❑WELL 32-3®WELL 14-25❑WELL 232 5L !III _ 1542' FELIJ NFU 24-26 WELL m x i''CD N:2120946.659 --x E: 1339895.834 W• LAT:59°47'44.758"N > EMI LON: 151°37'54.424"W Li ■ NAD83 ASP Z4 ''/ELEV:657.8'(NAVD88) IUr 1 -:.: < J LCL HE— W I Tract 19 - 0 =North Fork Acres Subd. No. it.)F 1--.0 X � 652 655 ' / 1 650 I O -'----k--____________\`'"------\, bp ` 65 bb U \l \ /b TOP OF BERM �W - •-:__=.— :. ) ---" --'' H II I N 2120261.15 _ Section 26,TO4S,R14W,S.M.,AK. — 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 N OR TH BASE STATIONS"KENS","TSEA"AND"KOD5" OBSERVED DEC.13,2007 ON _ NF1 3 1l2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' ^19111111111111 i 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. NAVD88 DATUM. 0 SCALE 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 200 I i SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 I FEET AND NOT THE PROTRACTED SECTION CORNER VALUES. J PROJECT REVISION: NORTH FORK 24-26 WELL DATE: 10/3/14 Cook Inlet Energy AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BGB NAD83 SCALE: 1,100' PROJECT Na 143135 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. - Consulting Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET VOICE:(907)283-4218 FAX:(907)283-3265 SW 1/4 SE 1/4 1 W r�li EMAIL SAMCLANE@MCLANECG.COM S26 T4S R14W SEWARD MERIDIAN, ALASKA OF • h • — ' • •EDGE,.,F R.O.W. ```NVVt111 1 NORTH FORK ROAD of A� S.�I -\ •. q �Q 4, 1001 RA/NI N 2121143.9950 vl-. �'/' .-•9 ' CP_, 2 E 1340068.0700 * :.49 TE i` .' * �. N 2121137.2190 — ELEV 666ATIf E 1339704.6100 EDGE OR.9-VY. '� �j�� / ELEV 656,1..� • • / 02.....------ 9 OHE —�— otic oHE j30 STAN A. MCLANE : .gi 653 POST POST"METER EL POST �, S� 4637—S ' / - n. A95, m II FPFo 1•. .•• ''„o� / - '-� X -:._.. > COVERED A O ,,„,,,ss,•` EIONAI.‘-P``� ELE.PANEL Q 656/ CONEX CONE) BL \ ��`` C �'ANTENNA N w � 6 S `o � (/ COVERED IOy� Tract 18 S9 - GATE ar ELE.PANEL / aliw I VAULT VAULT O VAULT 1 ` LINe htTR — o ��`, BLDG a )n i 4' '7) ' �J23-25 WELL r r 34-26 WELL 32-35 WELL 14-25-WELL 1 •,4, I IIBS&B BLDGC� XTANKCD N PW // x / 03 DE-HY NFU 24-26 WELL / > _ BLDG. • 5'x 6'TANK Ce ON LINER LL. .'I 14'x7.6'TANK ❑ ON LINER GARBAGE \ /\ �,�� HE fIISKID • METER NFU 2-35 WELL rt COVERED BLDG. Tract 19 i i ELE.PPANEL Cl North Fork Acres Subd. Noi2 0 X_ X x 652 -- 65 —, \ 1p TOP OF BERM 1 • 1 I I ii 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 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. 0 SCALE LE 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT I 0 I I SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 AND NOT THE PROTRACTED SECTION CORNER VALUES. FEET `` PROJECT REVISION: NORTH FORK 24-26 WELL DATE: 10/7/14 Cook Inlet Energy RIG 37 LAYOUT DRAWN BY: BGB SCALE: 1,100' PROJECT NO. 143135 if ENGINEERING/MAPPING/SURVEYING I TESTING BOOK NO. - Consulting Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET VOICE:(907)283-4218 FAX:(907)283-3265 S W 1/4 S E 1/4 EMAIL:SAMCLANE5MCLANECG.COM S26 T4S R14W SEWARD MERIDIAN, ALASKA 1 OF 1 ca Q.) e t ^) r Ct3 0 U- 41 © o Z P +d� c7 Tv En D D v o c‘11 6 Qn ■ I ll 1 Cook Inlet Energy 0 North Fork Unit #24-26 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.:214 ??? PP MW FG CS (ppg or ppge) EVALUATION MD/TVD cr. CASING&HOLE SIZE USDW:' 1`.sl Rkb ZU' Air Gap 0' Wtr.Depth 8.3 8.6 9.8 100'pen 120' .5#N80NC Welded Drive Sz so 16 ROP/Gas log Cond/Drive to TD. :! • Pilot Hole .t :t :3 Viii 9.0 160 GR,Res 2870' :10 40#N/L 80 SP DR FT BTC 12 1/4" 2750' r.r !+ 9 5/8" 2750' Casing 1 4859' 4900A SD 5554' 5600 SD 5939' 6000 SD Est TOC=4000'MD 7948' 7800 SD 8009' 7950 SD 8489' 8400 SD �.. 9381' 9200 SD 9628' Casing 2 Mud Logging: Manned: 2 sx/50'0-2000',2 sx/10'2000'-TD "'F 3>:: i 9620' TD 0i° V `E 9.6 /6.5 GR,Res y' 26#N/L 80 BTC-M 8 3/4" dii 9628' BC/URIIIO 7 " a wr: s+�oo ,99soo I i i Feet �r / - 2128700 2,28700/ 2 23 24 r- __LT — - 2123700 2123700- ,7 N. 23,25 25 _ 34-26� NFU-24-26 14-25 c / i 41-35 ' /32-35 _ J - 2118700 2118700- 22-35 - NFU-42-35 ,NFU 31-3 4a N - 2113700 2113700- + \ - 3 2 1 _ 2108700 2108700- Sc le=1:32029 •—Th 10 0 100 2000 3000 n l 1./‘ - , \ - 194800 , ,99800 204800 Al of 04S0144 04S013W 18 13 17 • 19 A 0 c CO North 25 36 For Gas Pool Unit �t1'PA .34 35 36 31 32 1 a � N o S 5 11 12 7 • 05S014W OSS013W Yg.1 SW*Y W+. North Fork Unit •�� Retartai CI North Fork Unit Boundary Leased State Tracts ( p own men n �, , Ill J Cook Inlet Region rJN Gmae� OM`� Fr I Gas Pool#1 PA Section Grid sw :M 0 0.25 0.5 1 Township Grid 1 I 1 1 1 1 1 1 I Miles n..•1 . Mop La:alien .en ,....,,..M.. Cook Inlet Energy 0 North Fork Unit #24-26 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.:214 ??? Time vs Depth Casing Size &Depth 0 i i E Days vs MD ND vs Days Prod Csg/Inr 1,000 2,000 3,000 1 4,000 5,000 6,000 1 7,000 8,000 1 9,000 — I ' 10,000 11,000 0 5 10 15 20 25 30 35 O opo O (6,26 N CO 4ON [T1 N c N- 4k 7 •- .,-.cn C @ I • = C CU CO C L C `d ' o 0 Eu co W Ot` O - / CL Z / CD / . o0 0 M :CL'Cl(713 m N / - r 0 _ o L • O - U 0 2 1 - aC 4, o 0 4o m c LIU rn - o OD 00 N Tr NI Ca COI N AC enO rO • -i - — 0 to liit iliio VW N • 1 t 1 . IC16 U- .c L O 0 Z o y a O O Qh 1ep C M = W m .' CO O C Oa • Q — g$ w $— -e 0 o 0 0 0 ao 1 o o O y o p8 o 0 0 0 0 00 0 0 0 0 0 0 O N M aAI ) O O� COOIs 0) 0 %— u/4;dea Cook Inlet Energy 0 North Fork Unit #24-26 Block/Sec 26 4S 14W North Fork () Kenai Peninsula Bor. 0 Alaska Ser#.:214??? 650'FSL&1750'FEL Sec 26 4S 14W 190'FSL&2220'FWL Sec 26 4S 14W Sand Tops/Significant Markers Objectives Type TVD EMW COMMENTS Casing 1 2750 8.4 4900A SD 4859 8.6 5600 SD 5554 8.8 6000 SD 5939 8.8 7800 SD 7948 8.8 7950 SD 8009 8.8 8400 SD 8489 8.9 9200 SD 9381 8.9 Casing 2 9628 9 TD 9628 9 Directional Program: Directional Per program TVD VS Opn(s) 300 0 Ito 358°AZ,8' Build&trun @3°/100' Lithology 900 -16 to 247.87° Samples: AZ,24°incl 2 sx/50'0-2000',2 sx/10'2000'-TD 1793 156 EOB,Hold 2750 580 Surf Casing Directional Survey: 4859 1515 4900Asd Per regulatory and directional requirements. 5186 1660 EOT,drop 5554 1780 5600 SD 7948 1823 6000 SD 9009 1823 7800 SD 8489 1823 7950 SD 9381 1823 8400 SD Logging Program: Lwd OH OH Possible Cased Hole Mudloqqinq Surface GR,Res none CBL Full Svc resistivity, GR,SR Prod GR,Res Density, High res CBL Full Svc Neutron and LSS 0 0 Cook Inlet Energy 0 North Fork Unit #24-26 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'-TD G�/ „¢ Mud Program: F Interval(TVD) Mud Weight(ppg) Lj (� i `1 From To From To s t Mud Type , e/ 4. 0 8.8 .//". �s �J 2750 9 t` spud 2,750 9628 9 9.6 wbm l/ ! Casing Program: Measured Depth Connection CMTD Est No. Hole Size Casing Size From To Wt(lb/ft) Grade Type with TOC Centralizers 01 o Hate Driven 16 0 120 1/2"wall N8OHC Welded none NA none Drive/Structural 20 0 NO Conductor 12.25 9.625 0 2870 40.00 J/L 80 SP DRF BTC 790 0 10 Surface 8.75 7 0 10000 26.00 N/L 80 BTC-M 830 0 16 Prod 4000 63 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 24 25 26 Run Production.Cement. Bump plug with water. Cleanout. 27 Displace with clean water. POOH laying down DP. 28 Complete 1 Emergency response Information 1.1 Directions to Location Method Directions Air Latitude: 190 Longitude: 2220 Directions from Kenai •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 •Turn right onto Kalifornsky Beach Rd.travel 16.2 mi Ground •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 Anchor Point,Alaska 99556 1.2 Rig Contact Numbers(Tentative depending on rig and communications available at time of MIRU)) Rig Phone List Cell#'s Co.Man: 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 Cell 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 South Peninsula (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 24-hour emergency Spill&Contamination Mgmnt Slidell,LA Witt/O'Brien's Resource Management (985)781-0804 Operations Houston,TX Wild Well (281)784-4700 Main Single Point (866)942-6564 Prepared by Stephen F.Henniganq 10/6/2014 Page 7 1.4 Company Emergency Response Name Position Office Mobile Conrad Perry VP Superintendent/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 (8AM-5PM) Contact 48 hr AOGCC (907)793-1236 Inspection Supervisor(Jim Regg) See Industry Guidance 10-01 ttp://doa.alaska.gov/ogc/forms/TestWitnessNotif.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 10/6/2014 Page 8 4 Drilling Program Summary 4.1 General Well data Name North Fork Unit It 24-26 Lease/Lic 391211 Surface Lcn 650'FSL A 1750'FEL Sec 26 4S 14W StNPad Existing Pad Field North Fork Spud Date(est) 10/20/14 KB(above MSL) County/Prov Kenai API No. GL(above MSL) State AK Permit No. Perm Datum KB Total MD 10,000 Well Class ALL Zones WD na Total TVD 9,628 prig Contractor CIE USDW <+-2700' Rig Name CIE Rig 37 4.2 Working Interest Owners Company Working Interest Address Primary Phone Fax Operator Cook Inlet 100.00% 601 W.5th Avenue STE 310 (907)433-3816 Energy Anchorage,AK 99501 4.3 Geologic Program Summary NAD 27 NAD 83 SHL SHL Prepared by Stephen F.Henniganq 10/6/2014 Page 9 NAD 27;Alaska Zone 4 X Co-ord. Y Co-ord. Surface Location Co-ordinates 199,870 2,121,192 Bottom Hole Location co-ordinates 198,128 2,120,654 Pore Pressure Targets M.D.(ft) T.V.D.(ft) X Co-ord. V Co-ord. (ppg)est 0 0 199870 2121192 8.4 Tie On 21 21 199870 2121192 8.4 Nudge&Build 300 300 199870 2121192 8.4 End of Build,hold 700 699 199870 2121219 8.4 EOH,Build&turn 900 897 199870 2121247 8.4 1021 1017 199867 2121262 8.4 1121 1116 199859 2121271 8.4 EOB,Hold 1822 1793 199691 2121245 8.4 Surface Casing 2870 2750 199293 2121095 8.4 4900A SD 5178 4859 198417 2120764 8.6 End of Tangent(S),DROP 5534 5185 198282 2120712 8.8 5600 SD 5923 5554 198169 2120670 8.8 6000 SD 6311 5939 198129 2120654 8.8 Vertical 6332 5960 198128 2120654 8.8 7800 SD 8320 7948 198128 2120654 8.8 7950 SD 8381 8009 198128 2120654 8.8 8400 SD 8861 8489 198128 2120654 8.9 9200 SD 9753 9381 198128 2120654 8.9 TD 10000 9628 198128 2120654 9.0 4.4 Formation Evaluation Summary Final Hole OH-WL Other OH- Pilot Hole Size MD TVD (Possible) WL(TBD) LWD Mud Logging Cased Hole , Size 120' 120' c NO Conductor 0 0 0 0 0 Surface 12 1/4" 2870' 2750' none 0 GR,Res Full Svc CBL resistivity,GR,SP, Prod 8 314" 10000' 9628' Density.Neutron 0 GR,Res and LSS Full Svc High res CBL 0 0 0 0 0 0 0 0 0 0 'large rotary sidewall core "up to 10 in gas,20 in oil Prepared by Stephen F.Henniganq 10/6/2014 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/ Maintain high gpm/rpm to keep bit/BHA clean Perform Surface additional circulating times Perform multiple conditioning trips Stuck casing ALL circulating 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 Monitor for loss of rtns and differential Possible depleted zones Intm Offset wells indicated no issues sticking. Discontinuity of formations minimizes potential. Monitor for connections in hole. Circulate High drill gas Prod Offset wells indicated no issues hole 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,driller or relief driller is responsible for shutting the well in BOPE or diverter as applicable as soon as warning 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±3000'TVD 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 10/6/2014 Page 11 4.6 Drilling Program Summary 4.6 General Summary Well Name North Fork Unit#24-26 Permit to Drill No. 214 777 Location Surface: 650'FSL&1750'FEL Sec 26 4S 14W Top of Productive Horizon: ' &' Sec Bottom Hole: 190'FSL&2220'FWL Sec 26 4S 14W Planned TD MD: 10000' TVD: 9628' Directional Plan As per program Well Summary A 16"conductor will be driven/drilled to±120'and a cellar will be constructed and installed. Using water-based mud,approximately 700' MD of 13-1/:"hole will be drilled as a"nudged"straight hole prior to kicking off and drilling directionally to the first casing point at±2750' 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 ±10000'/9628'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 Drive/Structural Driven 0 0 120 120 NO Conductor Size Surface 121/4" 0 0 2870 2750 Prod 8 3/4" 0 0 10000 9628 Pore Pressure/ Mud Program The well will be drilled to TD using water-base mud with a weight of±9.3-9.8 ppg in the production hole section and adjusted as necessary while drilling to TD. Mud 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 10/6/2014 Page 12 4.7 Casing program Summary Start Depth Seat Depth Seat Depth Casing Interval Hole Size MD TVD MD TVD Size Wt(Ib/ft) Grade Conn Burst Collapse Tension Drive/ Driven 0 0 120 120 16 " 0.5 N8OHC Welded N/A N/A Structural NO Conductor Surface 12 1/4" 0 0 2870 2750 9 5/8" 40 NIL 80 SP DRFT BTC 5750 3090 916 Prod 8 3/4" 0 0 10000 9628 7 " 26 NIL 80 BTC-M 7240 5410 604 Buck on float equipment @ 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 drilled 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 TVD) MASP= 2750'ND x((8.4 ppge'.052)-0.1 psifft) 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 drilled 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= 9628'ND x((9 ppge'.052)-0.1 psi/ft) 3543 psi ----7/t.r'*\ MADP=((PP ppge)x.052 x ND) `� MADP= 9628'ND x(9 ppg'0.052) 4506 psi Prepared by Stephen F.Henniganq 10/6/2014 Page 13 NOTES Prepared by Stephen F.Henniganq 10/6/2014 Page 14 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. Anal Start Depth Seat Depth Casing * Interval Hole Size MD TVD MD TVD Size Wt(1b/ft) Grade Conn Burst Collapse Tension_ Drive/ Driven 0 0 120 120 16 " 0.5 N8OHC Welded N/A N/A Structural NO Conductor Surface 12 1/4" 0 0 2870 2750 9 5/8" 40 /L 80 SP DRF BTC 5750 3090 916 Prod 8 3/4" 0 0 10000 9628 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± 2750'TVD with BOP's installed/tested with a max anticipated mud wt of± 9 ppg from above MASP(pp)=((PP ppge)x.052 x TVD)-(gg x TVD) MASP= 2750'TVD x((8.4 ppge'.052)-0.1 psi/ft) 926 psi MADP=((PP ppge)x.052 x TVD) MADP= 2750'TVD x(8.4 ppg*0.052) 1201 psi MASP(fg)=((FG+SF ppg)x.052 x TVD)-(gg x TVD) MASP Csg Design= 2750'TVD x((16ppge+.5 ppge)-0.1 psi/ft) 2085 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= 5750/2084.5 2.76 SF 7 Prod 8 3/4" Hole Section—estimated pore pressure of 9 ppg emw This hole section will be drilled to± 9628'TVD with BOP's installed/tested with a max anticipated mud wt of± 9.6 ppg from above MASP(pp)=((PP ppge)x.052 x TVD)-(gg x TVD) MASP= 9628'TVD x((9 ppge'.052)-0.1 psi/ft) 3543 psi MADP=((PP ppge)x.052 x ND) MADP= 9628'TVD x(9 ppg'0.052) 4506 psi Burst Stress= MASP Csg Design= TD MASP is used since this will be a production string 3543 from below Design Factor Burst Strength/Burst Stress= 72401 3543.104 2.04 SF Prepared by Stephen F.Henniganq 10/6/2014 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)-0.1 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= 9628'ND x((9 ppge'.052)-0.1 psi/ft) 3543 psi Design Factor Collapse Rating/Collapse stress= 5410/3543.104 1.53 SF Prepared by Stephen F.Henniganq 10/6/2014 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(Ib/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 2870'MD x 40 ppf*(1-9ppg/65.45) 99014 Design Factor= tensile strength/buoyed wt = 916000/99014 9.25 SF 7 " Prod Buoyed weight= 10000'MD x 26 ppf*(1-9.6ppg/65.45) 221865 pounds Design Factor= tensile strength/buoyed wt = 604000/221865 2.72 SF Prepared by Stephen F.Henniganq 10/6/2014 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) MADP=Maximum Anticipated Downhole Pressure(psi)@ TD Casing Size Casing Equipment Test Pressure Low/ High 16" Structural Casing @ 120' 21-1/4" 1000 Diverter 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 /y' 9.625" Surface Casing @ 2870' r (1) 1 ) "/4.5000 Annular 250/ 250 3 �p( . �I Ill t� 70%of Burst 4025 r (2) 1 5000 Pipe Rams 250/ 3 Po � 5'. Test Pressure 3000 . r (1) 1 5000 Blind Rams 250( 300)3 .4r e‘-' �� 1 MASP 3543 s1/4A � MADP 4506 ` MASP Casing Design 2085 Al'-"- .r f `-• 50%ofminimum internal yield 2875 �'� • 7" Production @ 10000' r (1) 1" 5000 Annular 250/ 2500 70%of Burst 5068 Min.(2) 5000 Pipe Rams 250/ 4000re— Recommended Test Pressure 4800 ' (1) yi 5000 Blind Rams 250/ 4000 ty Test Pressure) 4000 I a •L MASP 3543 i c'2:'" MADP 4506 /` MASP Casing Design 3543 50%of minimum internal yield 3620 „ ' (1) 70%of Burst Mn.(2) Recommended Test Pressure • (1) 0 Test Pressures I MASP N/A MADP N/A MASP Casing Design 0 50%of minimum internal yield I I BOP Test Pressures for Welltest/Completion Production (1) Annular 250/ 2500 70%of Burst of weakest csg 5068 Min.(2) Pipe Rams 250/ 4000 Test Pressure 4000 ' (1) Blind Rams 250/ 4000 Prepared by Stephen F.Hennigana 10/6/2014 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 Casing (in) Burst MADP(psi) MASP(psi) Pressure Test Pressure Fluid Density MINIMUM L250 psi (psi), high (psi) Size&Rating (psl) Rams are to be variable bore to accept 5"&4"DP,2 7/8"tbg NO Conductor 16 " NA NA NA 0 0 0 Surface 9 5/8" 2875 4,506 3,543 3000 9 (1)13 5/8"5M annular 2500 / (1)13-5/8"5M pipe ram ,.3096 ,fee (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 4,506 3,543 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"5M 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 TVD). 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 Top Test=((Previous Frac Gradient-Current Mud Weight)x(0.052)x TVD�,s g9)). 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 10/6/2014 Page 19 4.12 Wellhead Equipment Summary Component/Description Wellhead See drawing BASEPLATE KIT24 OD X 141D X L50 THK W/6 NUMBER I GUSSETS.W/WO2-112 GROUT SLOTS.F/13-5/8 CSGHO HSG.WG.SH2-LWR.11 SM X 10-3/450W W/ORING.W/2 2-1/16 5M FPO.6A-PU-AA-1-2 CSGHGR.WG,SH2.11 x 7 23.0 -26.0 LC BOX BTM X 7.375-4 ACME LH PIN TOP.MIN BORE 6.276.6A-PU-AA-1-2 TBGHGR.WG.T-M40-CCL11 Y. 2-7/8 EU BTM AND TOP,W/2-1/2 HBPV THO AND TWO DHCV PORTS,4130 8OK6A-LU-DD-NL-1-2 Tree 5k tree-TBD USE SPACER SPOOL(s)AS NECESSARY SEE ATTACHED DRAWING Prepared by Stephen F.Henniganq 10/6/2014 Page 20 4.13 Directional Surveying Summary Downhole realtime surveying tool. Magnetic Interval MD(ft) MWDILWD Multi Gyro Multi Elog Other Remarks Drive/Structural 0 120 _ none NO Conductor - Surface 120 2870 x Prod 2870 10000 x 4.14 Directional Program Summary Surveys will be taken per AOGCC regulations. Comments MD Inclination Azimuth TVD Grid East Grid North DLS Turn Rate Vert Sect [ft] [0] [°] [ft] [US ft] [US ft] (°/10O1t] [°f1o0ft] [ft] 0.00 0.00 358.00 0.00 199870.42 2121192 0 0.00 0.00 Tie On 20.80 0.00 358.00 20.80 199870.42 2121192 0 0.00 0.00 Nudge&Build 300.25 0.00 358.00 300.25 199870.42 2121192 0 0.00 0.00 End of Build,hold 700.25 8.00 358.00 698.95 199870.13 2121219 2 0.00 -7.94 EON,Build&turn 900.25 8.00 358.00 897.01 199869.84 2121247 0 0.00 -15.87 1020.80 6.63 331.36 1016.61 199866.57 2121262 3 -22.84 -17.04 1120.80 6.86 305.68 1115.94 199859.17 2121271 3 -25.68 -12.54 EOB,Hold 1822.49 23.94 247.87 1792.56 199690.69 2121245 3 -2.08 155.93 Surface Casing 2870.02 2750.00 199293.15 2121095 580.14 4900A SD 5177.50 23.94 247.87 4859.00 198417.46 2120764 0 0.00 1514.55 End of Tangent 5534.27 23.94 247.87 5185.09 198282.06 2120712 0 (S),DROP 0.00 1659.03 5600 SD 5923.08 12.27 247.87 5554.00 198169.24 2120670 3 0.00 1779.42 6000 SD 6311.20 0.63 247.87 5939.00 198128.52 2120654 3 0.00 1822.87 Vertical 6332.20 0.00 247.87 5960.00 198128.42 2120654 3 0.00 1822.98 7800 SD 8320.20 0.00 247.87 7948.00 198128.42 2120654 0 0.00 1822.98 7950 SD 8381.20 0.00 247.87 8009.00 198128.42 2120654 0 0.00 1822.98 8400 SD 8861.20 0.00 247.87 8489.00 198128.42 2120654 0 0.00 1822.98 9200 SD 9753.20 0.00 247.87 9381.00 198128.42 2120654 0 0.00 1822.98 TD 10000.20 0.00 247.87 9628.00 198128.42 2120654 0 0.00 1822.98 Prepared by Stephen F.Henniganq 10/6/2014 Page 21 PLOT Cook Inlet Energy _.r.n+.ro..rr r•s-•r• 1 Y>•' ,..:.. BAKER • vf rr• Mai Yr-tC+..7r WOGIES •-Jr. -.tr!f••Unl 0911Q:T. qelr. YT.;c.-x 111r1•- �r ..v. •'S ...9..T ..t.•orp90•-.'rte•[s-. s- GA9 e991•1•Ir04?.TY•r..Z.'....5)'. 3.431.4*113444•fu..3..•6C_r:-'- I;/l mow.T1r rw. WOW We e Lob No ilmInsor w.wtko.iN•.Y,or .^....t ..r G.IO•me Y ar :.."wows•Ve w•owne.i:•+ GPM.*,wlfv'Y'.2. + t".a :3'.3 .•.. .:.R Se ax _Y •-o.-f 1 t .1 ... . sr ..1 . ii I 1'•'L.f ••.7,: _'.21. ;.1.'e.'. • SS ;'t; •34.3 41: _al -a c.: 2:'1. ?'�JI ,t: ;.l. •..:it G.aang IZ; -2000•• 1150 -1500 -tl • •�-. —. 0 0 230 030 -.1000 • x_wcc. 0 UM%Crq $401t FOR 1 0 a a,l.Cmwrs.er> nom X70 ,a Lie.I OJ. 1000 tfv a t`yr. r-2$ -'CO lassof x: P,.wlr, 3000 �Ol ®r -730 9 ear.Lmoiy 4.i 4. 7000 4000 s r 3000 ear at tows 413 18014040 0000 M4V_4.1.14110/ 4110.ONO 000 7000 0000 0000 .,11,01_00010 t1Y or M Coq NIIGYn 10000 *G I eAll pp 000 -1000 V D _ J06b, 1101M Zat!'rule 111w1m GOON 0000 Prepared by Stephen F.Henniganq 10/6/2014 Page 22 Spider . Cook Inlet Ener gJV ��yl actcn. COoe Wet A.268.3e•s c3 3 SCI �SY'XCni 83.0-X BAKER Pot NOP1T 11300 We W.' HU ES ..-r. I a tT l-01•,114^-- /Viet e_ Fes. 1n,26 d1erYf _- - __- Well Profile Data _- -:•• _ ._ - - ..... K.R. z . 4. S :s h 0 p - 0 ^ls ID eE Da 1•0030' . • -._..-_-_. .-.".. _ ra 017W Y.e 01 diet 000 COC 0a -1 Era d T..p^+ ]tA a 21 .7Se 01 %I:i' C Z COO U CC End N 6.N .'•,..S.. 0 000 'Ise 01 e00 fe 77 4e S 0? .7 W Ene A'r.w: NM 2.1 401, Y40 U1 067 U' Y.eO -W .'S 47 EMd Y'4.- S. 'i140 POW 24'eY.' 'F4:90 04 Y.' .'.044 '-4' EroO1.,2..1ts; 9634:' 7_410 2N'OF: 5145 3It .S'000 -05110 End o'::,,c:3 4132 20 0 OW 24'472 540:00 .074 4e .172017 :.a Ere 0 1 enzi,1 475220 0 000 24'19•.. VAC W 67440 .172417 490 r_... Era d T.vaa '1=X 0000 24'47: 4424]0 .67400 .172077 000 EasMQ,R.. -MO -1475 -'750 -'an -1700 -']70 -'210 -1t• -1100 -VI -7w -Ra -KO -471 -DI -1, I 677 Po 4a 811.318 Coins bolo — -'D -270 4 -S75 J400 I.� ce -0T /• [ 'al\ -710 Prepared by Stephen F.Henniganq 10/6/2014 Page 23 4.15-4.16 Drilling Fluids Program Summary and Specifications TYPICAL Mud Program Overview Mud Program: . Drill 12.25"hole and r asin•• Fluid Type: , Gel Spud Mud , Fluid Properties Listed Below: Depth Mud Wt. Funnel PV Yield Point Gels pH API FL HTHP FL Chloride SLDS Vis 10 sec/10 min 250'6 '000' (MD) ppg se�Qt W 1811100 tO bf1100fl cc cc I %NOL 9-2750' 8 8-9 2 100-200 15-28 30+ 18-35 8 5-9 5 <18 N/A 0 5000 <8 1 Add Oekaktsisweeps for added viscosity. 2 Run all available solids control equipment for maximum solids control. 3 pH should be controlled with Caustic and/a Soda Ash 4 Add 2-5 ppb MIX II 10 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 F 111d T •-: . . .r JIVBAL_ BtCtn.Y S .,+. , • Fluid Properties Listed Below: Depth Mud WL Funnel PV Yield Point Gels pH API FL HTHP FL Chloride SLDS (MD) 888 Vis1080100 IN 10 sec/10 min cc 250'F V00' %NOL ssolm LONt' a VI 2,750'-10,003'MD 9.49.6\ 40-50 18-26 15-28 18-22 92-102 <5 WA 261<32k <6 1 Drill X25•casing shoe with previous mud on isolated pit.Perform FIT. 2 The WBM should be maintained with KCI,Flowzan and PolyPac UL with sweeps as needed for 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 Desilter 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 tem Equipment Specifications (typical but may not be exact depending on ng) I (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 10/6/2014 Page 24 4.18 Cement Program Summary(Brief vendor prog is attached) Cementing Summary I I I I 1 #VALUEI Surface I Size: 9.625 Setting Depth: 2870 ft. Annular Volume(No Washout): 944.05 cu.ft. Lead Slurry Density: 0 ppg Yield: 0 cu.ft./sx No.Sxs:` 0 I Specifications:None Desired Top of Cement: WA ft 1 Tall Slurry Density: 12 ppg Yield: 2.3 tcu.ft./sx No.Sxs:I 790 I Specifications: I 8 Four Compressive Strength of Tail Slurry: 1000+ psi Total Volume:I 1817 Icu.ft. Desired Top of Cement: 0 ft 790 Intm.Prod.Casing I Size: 7 Setting Depth: 10000 ft. Annular Volume(No Washout): 901.62 cu.ft. Lead Slurry Density: 13.5 ppg Yield: 1.83 CU.ft./sx No.Sxs: 460 Specifications: G Desired Top of Cement: 4000 ft. � t y'� Tail Slurry Density: 15.8 ppg Yield: 1.18 cU.ft./sx No.Sxs:1 370 ,pr /� Specifications: G Desired Top of Crre ent: 8000 ft. Cr� y Total Volume:I 1271 leo-ft. 8 Hour Compressive Strength of Tad Slurry: 1000+ psi 830 I I .1 I I #VALUE I I I I #VALUE � I I I I #VALUE! Comments: See cement prognosis for details and spacer specifications. Actual cement volume pumped will be determined by elog caliper and other parameters. Prepared by Stephen F.Henniganq 10/6/2014 Page 25 4.19 Bit Summary-ESTIMATED illiCidtiew.... Cook Cook Inlet Energy Inlet North Fork Well NT 24-26 Drilling '..,:•:k7."' OPERATOR CONTRACTOR RIG N,It1.1 r.,k C wok Isl.Emory _ /AWU r Rig.r Gerald R A K.tol a.D.. :•=_.7 .A.F.LA LOCATION SPELL WHEEL N.Afl.Folk _NP.24.:6 -... BIT DEPTH DIST DRLC AC C N RI) \. •ILE TYPE OUT DP.LD TIME HOP Mil IN OB HP N I INT DAN• R.E.11ARKS .4- h ' Orel 8 3:4"Q13.3. 1 2-I 4 VMD.; 2S-0 26-0 2$ 100 2- 1.-20 HUGHES Set 9-5S"Cas' 2 S-3 4.. Q121505X 10.000 -130 71 100 99 - 10-15 200 IS Set 7-Casing. . , • •.7 1 T I I I I _ _. Win Wins Prepared by Stephen F.Henniganq 10/6/2014 Page 26 4.20 Casing Test,FIT,Lot procedure Perform Casing Test(CITl -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. NO rE. Larger than 11 3:4"use 75-1 bpm, 11 3,4-9 5,8 use.75-.5 bpm-plot should be±greater 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 10/6/2014 Page 27 Perform Formation Test(LOT,FIT,etcl -enter all the header information for the well.rig.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-F I worksheet(in the blue shaded area). This will require teamwork among at least two,but better with three individuals.If the I ORM 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 drilipipe 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 EMW)=pressure(psi)I.052/casing shoe depth('TVD) +current mud weight(ppg) 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 IF 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 10/6/2014 Page 28 Cook Inlet Energy North Fork Unit 24-26 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 III'"^10.0 ppg Lead Slurry Cement 610 sks Class G Cement+Additives 12.0 ppg, 266.5 BBL Open Hole Excess 100% Tail Slurry Cement 190 sks.' Class G Cement+Additives 13.0 ppg, BL 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 Weight 12.0 Yield 2.48 Water 14.59 Pump time ^'05:00 L Water Loss ^'500cc/30min e , Free Water 0 Compressive Strength P 8 hours 175 12 hours 280 24 hours 640 48 hours 980 PROPERTIES Tail Slurry Weight 13.00 Yield 1.93 Water 10.56 Pump time "04:00 Water Loss —350cc/30min Free Water 0 Compressive Strength 8 hours 450 12 hours 702 24 hours 1486 48 hours 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. Single Slurry System(Option 1) I/ Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 40 BBL Tuned Spacer Ill'"-11.5 ppg Primary Slurry: 1110 sks Class G Cement+Additives ppg - 15.8 ppg 228 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 4000' PROPERTIES Primary Slurry Weight 15.8 Yield 1.16 Water 4.95 Pump time ^'06:00 Water Loss ^'100cc/30min Free Water 0 Compressive Strength 8 hours 900 12 hours 1725 24 hours 2450 48 hours 2950 72 hours 3200 Lead/Tail System(Option 2) Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 40 BBL Tuned Spacer III""-11.5 ppg Lead Slurry: 460 sks Class G Cement+Additives ppg - (13.0 ppg) 150 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 Weight 13.00 Yield 2.44 Water 13.589 Pump time 4:23 Water Loss 150cc/30min Free Water 0 Compressive Strength 8 hours 0 12 hours 50 24 hours 450 48 hours 900 72 hours 1230 PROPERTIES Tail Slurry Weight 15.8 Yield 1.16 Water 4.95 Pump time ^'06:00 Water Loss ^'100cc/30min Free Water 0 Compressive Strength 8 hours 900 12 hours 1725 24 hours 2450 48 hours 2950 72 hours 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. HALLIBURTON COOK INLET ENERGY LLC - EBUS DONOTMAIL-601 W 5TH AVE STE 310 ANCHORAGE, AK, 99501 US North Fork Unit 24-26 KENAI PENINSULA BORO, AK US Cook Inlet Energy North Fork Unit 24-26 Cementing Quote for NFU 24-26 Proposal 134849 - Version 1.0 October 02, 2014 Submitted by: Ryan Plieness 6900 Arctic Blvd Anchorage, AK -99518-2146 USA HALLIUURTON COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 Contents 1 Foreword 3 2 Surface Casing 4 2.1 Job Information Surface Casing 4 2.2 Estimated Calculations Surface Casing 5 2.3 Job Volume Estimates Surface Casing 6 2.4 Volume Estimate Table Surface Casing 7 2.5 Cost Estimate 8 3 Production Casing-Single Slurry 10 3.1 Job Information Production Casing-Single Slurry 10 3.2 Estimated Calculations Production Casing-Single Slurry 11 3.3 Job Volume Estimates Production Casing-Single Slurry 12 3.4 Volume Estimate Table Production Casing-Single Slurry 13 3.5 Cost Estimate 14 4 Production Casing-Lead/Tail System 16 4.1 Job Information Production Casing-Lead/Tail System 16 4.2 Estimated Calculations Production Casing-Lead/Tail System 17 4.3 Job Volume Estimates Production Casing-Lead/Tail System 18 4.4 Volume Estimate Table Production Casing-Lead/Tail System 19 4.5 Cost Estimate 20 5 Conditions 22 HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 2/22 2014 Halliburton All Rights Resen ed COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 Halliburton appreciates the opportunity to present this cost estimate and looks forward to being of service to you. 1 Foreword Enclosed is our cost estimate for cementing the casing strings in the referenced well. The information in this cost estimate includes well data, calculations, materials requirements, and cost estimates. This cost estimate is based on information from you the customer,our field personnel,and previous cementing services in the area. The selection and use of non-Halliburton plugs and casing attachments can compromise and may jeopardize the overall objective for effective zonal isolation. Furthermore, Halliburton is not involved in the design, manufacture or use of plugs and casing attachments supplied by other manufacturers and assumes no liability for their installation and operation. For this reason we recommend Halliburton plugs and casing attachments be used when Halliburton performs any zonal isolation operation. Halliburton Energy Services recognizes the importance of meeting society's needs for health, safety, and protection of the environment. It is our intention to proactively work with employees, customers, the public, governments, and others to use natural resources in an environmentally sound manner while protecting the health, safety,and environmental processes while supplying high quality products and services to our customers. We appreciate the opportunity to present this cost estimate for your consideration and we look forward to being of service to you. Our Services for your well will be coordinated through the Service Center listed below. If you require any additional information or additional designs, please feel free to contact myself or our field representative listed below. Prepared and Submitted by: Ryan Plieness Technical Advisor OPERATION SUPPORT: Deadhorse,AK 907.659.2805 Kenai,AK SERVICE MANAGER: Jeremy Talarovich 907.275.2635 SERVICE COORDINATORS: Ed Jans 907.231.5875 Wes Miller 907.670.5827 TECHNICAL SUPPORT: Anchorage,AK 907.275.2600 TECHNICAL ACCOUNT REP: Ryan Plieness 907.230.9718 ENGINEERING TEAM: Savannah Afoa 907.223.7278 Gareth Pollock 907.943.0291 HALLIBURTON Proposal134849 v1.0 CONFIDENTIAL 3/22 x 2014 11alliburt0n :111 Riv.Iri,12,sencd COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 2 Surface Casing 2.1 Job Information Surface Casing Job Criticality Status: GREEN Well Name:North Fork Unit Well#: 24-26 Conductor Casing 0- 120 ft(MD) Outer Diameter 16 in Inner Diameter 15.01 in Linear Weight 84 lbm/ft Open Hole Section 120-2870 ft(MD) Inner Diameter 12.25 in , Excess Factor 100 Surface Casing 0-2870 ft(MD) Outer Diameter 9.625 in Inner Diameter 8.835 in Linear Weight 40 Ibm/ft Shoe Joint Length 84 ft Drill Pipe 0- 2786 ft(MD) Outer Diameter 4.5 in Inner Diameter 3.958 in Linear Weight 14.06 lbm/ft HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 4/22 0201311allibwton :\II RI at,Reserved COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 2.2 Estimated Calculations Surface Casing Stage 1 CEMENT: (2370 ft fill) 2250 ft * 0.3132 ft3/ft* 100% = 1409.34 ft3 120 ft * 0.7235 ft3/ft* 0% =86.83 ft3 Lead Cement = 1496.17 ft3 =266.5 bbl Total Lead =603.34 sack CEMENT: (500 ft fill) 500ft * 0.3132ft3/ft * 100% =313.19ft3 Tail Cement =313.19 ft3 =55.8 bbl Shoe Joint Volume: ( 84 ft fill) ( 84 ft * 0.4257)ft3/ft =35.76 ft3 =6.4 bbl Tail plus shoe joint =349.23 ft3 =62.2 bbl Total Tail = 180.67 sack Total Pipe Capacity: 120 ft * 0.0854 ft3/ft = 10.25 ft3 2666 ft* 0.0854 ft3/ft =227.79 ft3 84 ft * 0.4257 ft3/ft =35.76 ft3 =48.8 bbl Displacement Volume to Shoe Joint: Capacity of Pipe-Shoe Joint =48.8 bbl - 6.4 bbl =42.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 5/22 "_013IiallibtnIon \II Rights 12,LiN,c1 COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 2.3 Job Volume Estimates Surface Casing Stage I Fluid 1: Rheologically Enhanced Spacer 10 lb/gal Tuned Spacer III Fluid Density: 10 lbm/gal 38.32 gal/bbl FRESH WATER Volume : 60 bbl 59.80 lbm/bbl Barite Fluid 2: Lead Slurry SWIFTCEM(TM) SYSTEM Fluid Weight: 12 lbm/gal Volume: 266.5 bbl Slurry Yield: 2.48 ft3/sack Total Mixing Fluid: 14.59 Gal/sack Top Of Fluid: 0 ft Calculated Fill: 2370 ft Calculated sack: 603.29 sack Proposed sack: 610 sack Fluid 3: Tail Slurry SWIFTCEM(TM) SYSTEM Fluid Weight: 13 lbm/gal Volume: 62.2 bbl Slurry Yield: 1.933 ft3/sack Total Mixing Fluid: 10.56 Gal/sack Top Of Fluid: 2370 ft Calculated Fill: 500 ft Calculated sack: 180.52 sack Proposed sack: 190 sack Fluid 4: Water Based Spacer Displacement Fluid Fluid Density: 8.4 lbm/gal Volume : 10 bbl Fluid 5: Spud Mud Displacement Fluid Fluid Density: 9.5 lbm/gal Volume : 32.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 6/22 ?OI I IaIIibunon All Kiehts Re.,,(1 COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 2.4 Volume Estimate Table Surface Casing Calculations are used for volume estimation.Well conditions will dictate final cement job design. Stage 1 ul" ui ype"" iiid Name Surface lli §imate Downhole Volume Density Avg Rate 1111111111111.116 lbm/gal bbl/min 1 SPACER 10 lb/gal Tuned 10 5 60 bbl Spacer III 2 CEMENT Lead Cement 12 4 610 sack 3 CEMENT Tail Cement 13 4 190 sack 4 SPACER Displacement Fluid 8.4 4 10 bbl 5 MUD Displacement Fluid 9.5 5 32.4 bbl NOTE: These slurries and spacers will require lab testing. The additives and concentrations are estimates based on field experience in the area and may need to be modified prior to the job. The proposed spacer is designed to be generally compatible with water base mud systems. Compatibility testing with field mud samples used may indicate changes in the additive package and the related costs. HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 7/22 c 2011 I IallibwYon All Rights Rcscrccd COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 3 Production Casing - Single Slurry 3.1 Job Information Production Casing - Single Slurry Job Criticality Status: GREEN Well Name:North Fork Unit Well #: 24-26 Intermediate Casing 0-2870 ft(MD) Outer Diameter 9.625 in Inner Diameter 8.835 in Linear Weight 40 Ibm/ft Open Hole Section 2870- 10000 ft(MD) Inner Diameter 8.75 in Excess Factor 40% Production Casing 0- 10000 ft(MD) Outer Diameter 7 in Inner Diameter 6.276 in Linear Weight 26 Ibm/ft Shoe Joint Length 84 ft HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 10/22 ©2013 Halliburton \II Richt,Reserved COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 3.2 Estimated Calculations Production Casing - Single Slurry Stage 1 SPACER: (1067 ft fill) 1067 ft * 0.1503 ft3/ft * 40% =224.58 ft3 Total Spacer =224.58 ft3 =40 bbl CEMENT: (6000 ft fill) 6000 ft * 0.1503 ft3/ft* 40% = 1262.77 ft3 HALCEM (TM) SYSTEM = 1262.77 ft3 =224.9 bbl Shoe Joint Volume: (84 ft fill ) (84ft * 0.2148)ft3/ft = 18.05 ft3 =3.2 bbl Tail plus shoe joint = 1280.69 ft3 =228.1 bbl Total Tail = 1107.86 sack Total Pipe Capacity: 2870 ft* 0.2148 ft3/ft =616.56 ft3 7130 ft * 0.2148 ft3/ft = 1531.73 ft3 =382.6 bbl Displacement Volume to Shoe Joint: Capacity of Pipe-Shoe Joint =382.6 bbl - 3.2 bbl =379.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 11/22 2013 I lallIbwton .-AII Rights Reserved COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 3.3 Job Volume Estimates Production Casing - Single Slurry Stage I Fluid 1: Rheologically Enhanced Spacer 11.5 lb/gal Tuned Spacer III Fluid Density: 11.5 lbm/gal 36.09 gal/bbl FRESH WATER Volume : 40 bbl 146.50 lbm/bbl Barite Fluid 2: Tail Slurry HALCEM (TM)SYSTEM Fluid Weight: 15.8 lbm/gal 4.95 Gal FRESH WATER Volume: 228.1 bbl Slurry Yield: 1.156 ft3/sack Total Mixing Fluid: 4.95 Gal/sack Top Of Fluid: 4000 ft Calculated Fill: 6000 ft Calculated sack: 1107.97 sack Proposed sack: 1110 sack Fluid 3: Water Spacer Displacement Fluid Fluid Density: 8.4 lbm/gal Volume : 10 bbl Fluid 4: LSND Displacement Fluid Fluid Density: 9.6 lbm/gal Volume : 369.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 12/22 C 2013 Halliburton !111 Rights Reserved COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 3.4 Volume Estimate Table Production Casing - Single Slurry Calculations are used for volume estimation.Well conditions will dictate final cement job design. Stage 1 r e. Estin Density Avg Rate lbm/gal bbl/min 1 SPACER 11.5 lb/gal Tuned 11.5 4 40 bbl Spacer III 2 CEMENT HALCEM(TM) 15.8 5 1110 sack SYSTEM 3 SPACER Displacement Fluid 8.4 10 bbl 4 MUD Displacement Fluid 9.6 4 369.4 bbl NOTE: These slurries and spacers will require lab testing. The additives and concentrations are estimates based on field experience in the area and may need to be modified prior to the job. The proposed spacer is designed to be generally compatible with water base mud systems. Compatibility testing with field mud samples used may indicate changes in the additive package and the related costs. HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 13/22 ©2013Ilalliburtun :AII Rights Re,cned COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 4 Production Casing - Lead/Tail System 4.1 Job Information Production Casing - Lead/Tail System Job Criticality Status: GREEN Well Name:North Fork Unit Well #: 24-26 Surface Casing 0-2870 ft(MD) Outer Diameter 9.625 in Inner Diameter 8.835 in Linear Weight 40 lbm/ft Open Hole Section 2870- 10000 ft(MD) Inner Diameter 8.75 in Excess Factor 40% Production Casing 0- 10000 ft(MD) Outer Diameter 7 in Inner Diameter 6.276 in Linear Weight 26 lbm/ft Shoe Joint Length 84 ft HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 16/22 :-2U1;Ilallibuiton All102111s12cscrccd COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 4.2 Estimated Calculations Production Casing - Lead/Tail System Stage 1 SPACER: (1067 ft fill) 1067ft* 0.1503ft3/ft * 40% =224.58 ft3 Total Spacer =224.58 ft3 =40 bbl CEMENT: (4000 ft fill) 4000 ft * 0.1503 ft3/ft* 40% =841.85 ft3 Lead Cement =841.85 ft3 = 149.9 bbl Total Lead =455.92 sack CEMENT: (2000 ft fill) 2000 ft * 0.1503 ft3/ft * 40% =420.92 ft3 HALCEM (TM) SYSTEM =420.92 ft3 =75 bbl Shoe Joint Volume: (84 ft fill ) ( 84 ft * 0.2148)ft3/ft = 18.05 ft3 =3.2 bbl Tail plus shoe joint =439.06 ft3 =78.2 bbl Total Tail =380.14 sack Total Pipe Capacity: 2870 ft * 0.2148 ft3/ft =616.56 ft3 7130 ft* 0.2148 ft3/ft = 1531.73 ft3 =382.6 bbl Displacement Volume to Shoe Joint: Capacity of Pipe-Shoe Joint =382.6 bbl - 3.2 bbl =379.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 17/22 ©2013 Halliburton :AII Richts Reserved COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 4.3 Job Volume Estimates Production Casing - Lead/Tail System Stage 1 Fluid 1: Rheologically Enhanced Spacer 11.5 lb/gal Tuned Spacer III Fluid Density: 11.5 lbm/gal 36.09 gal/bbl FRESH WATER Volume : 40 bbl 146.50 lbm/bbl Barite Fluid 2: Lead Slurry HALCEM (TM) SYSTEM Fluid Weight: 13 lbm/gal 10.12 Gal FRESH WATER Volume: 149.9 bbl Slurry Yield: 1.846 ft3/sack Total Mixing Fluid: 10.12 Gal/sack Top Of Fluid: 4000 ft Calculated Fill: 4000 ft Calculated sack: 456.04 sack Proposed sack: 460 sack Fluid 3: Tail Slurry HALCEM (TM)SYSTEM Fluid Weight: 15.8 lbm/gal 4.93 Gal FRESH WATER Volume: 78.2 bbl Slurry Yield: 1.155 ft3/sack Total Mixing Fluid: 4.93 Gal/sack Top Of Fluid: 8000 ft Calculated Fill: 2000 ft Calculated sack: 380.06 sack Proposed sack: 390 sack Fluid 4: Water Spacer Displacement Fluid Fluid Density: 8.4 lbm/gal Volume : 10 bbl Fluid 5: LSND Displacement Fluid Fluid Density: 4 lbm/gal Volume : 369.4 bbl HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 18/22 2OI Ilalliburton All Ki_hls I cecrccd COOK INLET ENERGY LLC - EBUS HALLIBURTON North Fork Unit 24-26 4.4 Volume Estimate Table Production Casing - Lead/Tail System Calculations are used for volume estimation.Well conditions will dictate final cement job design. Stage 1 Fluid# r,. Fluid Type' ut: game Surface— stimatea Oowri yo eo trine Density Avg Rate lbm/gal bbl/min 1 SPACER 11.5 lb/gal Tuned 11.5 5 40 bbl Spacer III 2 CEMENT Lead Cement 13 5 460 sack 3 CEMENT HALCEM (TM) 15.8 5 390 sack SYSTEM 4 SPACER Displacement Fluid 8.4 4 10 bbl 5 MUD Displacement Fluid 4 369.4 bbl NOTE: These slurries and spacers will require lab testing. The additives and concentrations are estimates based on field experience in the area and may need to be modified prior to the job. The proposed spacer is designed to be generally compatible with water base mud systems. Compatibility testing with field mud samples used may indicate changes in the additive package and the related costs. HALLIBURTON Proposal 134849 v 1.0 CONFIDENTIAL 19/22 G 2013 Ilallibunon :AII Rights Reseied Cook Inlet Energy _Cook Inlet Energy_ BAKER Location: Cook Inlet,Alaska(Kenai Peninsula) Slot North Fork#24-26 HUGHES Field: North Fork Well: NFU#24-26 Facility: North Fork Unit(NAD27) Wellbore: NFU#24-26 Wellplan Plot reference welipath is NFU#24-28 Ver#3 True vertical depths are referenced to CIE 37(RT) Grid System:NAD27/TM Alaska SP,Zone 4(5004),US feet Measured depths are referenced to CIE 37(RT) North Reference:True north CIE 37(RT)to Mean Sea Level:678.6 feet Scale:True distance Mean See Level to Mud line(At Slot:North Fork#24-26):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by ulricard on 03/Oct/2014 Well Profile Data Design Comment MD(ft) Inc(°) Az(°) ND(ft) Local N(ft) Local E(ft) DLS(°/100ft) VS(ft) Tie On 20.80 0.000 358.000 20.80 0.00 0.00 0.00 0.00 End of Tangent 300.25 0.000 358.000 300.25 0.00 0.00 0.00 0.00 End of Build 700.25 8.000 358.000 698.95 27.86 -0.97 2.00 -7.94 End of Tangent 900.25 8.000 358.000 897.01 55.68 -1.94 0.00 -15.87 End of 3D Arc(S) 1822.49 23.938 247.872 1792.56 49.22 -180.99 3.00 155.93 End of Tangent(S) 5534.27 23.938 247.872 5185.09 -518.08 -1576.10 0.00 1659.03 End of Drop(S) 6332.20 , 0.000 247.872 5960.00 -579.96 -1728.27 3.00 1822.98 End of Tangent 9752.20 0.000 247.872 9380.00 -579.96 -1728.27 0.00 1822.98 End of Tangent 10000.20 0.000 247.872 9628.00 -579.96 -1728.27 0.00 1822.98 Scab 1inch-eft Easting(ft) -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250250 1 1 I 1 1 1 1 1 1 -.1000- 161n Conductor 0 9.625in Casing Surfacer North Fork#24-26 _ Z N 0 Tie Ond 6. I 16in Conductor o End of Tangent C. -250 2.00°/1005 'z up End of Build ,a 1 000- End of Tangent x 3.00°/1005 .% --500 b.- End of 3D Arc(S) 1T7in : ing Production 2000- FU 7p1 6000sd NFU_7p1_S200sd --750 e 9.625in Casing Surface 3000- E. 4000- t Z. a 0 15000- 't End of Tangent(S) N 3.00°/100ft l0 2NFU_7p1_6000sd End of Drop(S) F 6000- 7000- 8000- 9000- NFU_7p1_9200sd T End of Tangent'+L lin Casing Production 10000- +A. dk? Rvs 1100p 1 I 1 1 1 2000 -1000 Vertical0 Section 2000 3 00 (ft) Scale 1 inch=YWOft Azimuth 251.45°with reference 0.00 N,0.00 E Cook Inlet Energy . North Fork#24-26 BAKER Cook Inlet Energy HUGHES RIG:Miller 37 BOTTOM HOLE ASSEMBLY#1 12.25"Hole DEPTH IN 0' estimate DEPTH OUT 2,870' TOTAL 2,870' OBJECTIVE: ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO. 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(AK01.2°)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/Pres/VSS/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 at a 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#24-26(Oct 1 2014)BHA's.xlsx Cook Inlet Energy i North Fork#24-26 BAKER Cook Inlet Energy_ HUGHES RIG:Miller 37 BOTTOM HOLE ASSEMBLY#2 8.75"Hole DEPTH IN 2,870' DEPTH OUT 10,000' TOTAL 7,130' OBJECTIVE: ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO. DESCRIPTION PROVIDER OD OD ID CONN CONN LENGTH LENGTH M.41;SiSV):. !M4jtC):VXMqiiiMM :XMXWE47: 4VX:M4:q;: 44 M-MX: 1-Vi1034 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(AK01.2°)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 3/412 B 2.00 41.20 6 Ontrak BHI 6.75 6 3/4"T2 P 6 3/412 B 16.84 58.04 7 Modular Stabalizer BHI 8.625 6.75 2.81 6 3/4"12 P 6 3/412 B 3.94 61.98 8 BCPM BHI 6.75 2.81 6 3/412 P 6 3/4"12 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 9205.46 10000.00 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: 42.5VSS: 52.2' Gamma Ray: 43.4' NonMag Below: 28.0' Resistivity: 47.4' NonMag Above: 90.1' NFU#24-26(Oct 1 2014)BHA's.xlsx IIIIINIIIINIIIOIUIIIIIIIIIHI - IllIllUllIllIll IIIIIIII 1 liii11111 I r - 1111 EIIJII1FJ!!!!i HiE N . liii 11111 E 98199898111@919B11I . 1 . c �E 9B191B89199199�R m I \ a'li O J Ol Ol a i hi,o a v o u dm w iii Iii ��9EEOP fl. 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NNNNNNN♦NNN♦NNNYNNN♦N NYNN YN NNN YN♦NNNNNN♦NN♦NN♦NNNNN0�0♦NNN pN pN pN0N0N pN0N pN0N p0 pN pA NN pN pNNN pNNN pNNNNNNNNNNNNNN0 pNN0 ANON OINN pN NN NNNNNNNNNN pNNN CWI�*I+I*�I4a*0)I4I��I+WI�II4 W a ga W g W a W a W 4IW�aa as*WAXXX N a)ID 0000000000000000000000000000000000000000000000 N N Q R N g N g N R N N N N r r N n N r N N n)r r N 4 R tV N N-W W N 0 0 0 O G C G G G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 $8888888 SSgS8g8888888 8$ 88888 8N$8$888888888888 R8R8$88888888R8R888888 888R8 $888RR88q 11 010,1114f `IIPAAf)IIQ53R IIIII1R1111m0 1111111PROPO PIPAIIIIIIIIiII III I m0 Clearance Report FAR Cook Inlet Ener NFU #24-26 Ver#3 BAKER Energy Closest Approach Page 1 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) REPORT SETUP INFORMATION Projection System 1NAD27/TM Alaska SP,Zone 4 !Software System WellArchitecto 4.0.1 1(5004),US feet North Reference True User Ulricard [Scale 1 Report Generated 03/Oct/2014 at 14:20 Convergence at slot n/a Database/Source file WA_Anchorage Server/NFU_#24-26_Wellplan_CR.xml WEE LPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location 648.00 -1542.15 199870.42 2121191.50 59°47'46.960"N 151°37'46.655"W Facility Reference Pt 201396.26 2120505.98 59°47'40.579"N 151°37'16.516"W Field Reference Pt _I 1 201396.26 2120505.98 59°47'40.579"N 1 151°37'16.516"W 1 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 #24-26) 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 16.53°East of TN Dip Angle 72.86° Mag Field Strength 55063 nT }Slot Surface Uncertainty @1SD 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 Fa ceB Clearance Report VA. NFU#24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 2 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 [Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 ,Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 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 i O.00ft Subtract Casing&Hole Size yes Apply Cone of Safety no HOLE& CASING SECTIONS-Ref Wellbore:NFU#24-26 Wellplan Ref 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 Iftl [ft] [ft] [ft] Iftl Iftl [ft] [ft] Iftl 16in Conductor 20.80 120.25 99.45 20.80 120.251 0.00 0.00 0.00 0.00 12.25in Open Hole 20.80 2870.03 2849.23 20.80 2750.001 0.00 0.00 -110.89 -574.72 [9.625in Casing Surface 20.80 2870.03 2849.23 20.80 2750.005 0.00 0.00 -110.89 -574.72 8.75in Open Hole 2870.25 10000.20 7129.95 2750.20 9628.00 -110.92 -574.80' -579.96 -1728.27 .7in Casing Production 20.80 10000.20 9979.401 20.80 9628.00 0.001 0.00 -579.96 -1728.27 SURVEY PROGRAM- Ref Wellbore:NFU#24-26 Wellplan Ref Wellpath:NFU#24-26 Ver#3 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] Iftl [ 20.80, 2870.25 OnTrak(Standard) NFU#24-26 Wellplan _ 2870.251 10000.25jOnTrak(Standard) I NFU#24-26 Wellplan cel Clearance Report FA. Cook Inlet Ener NFU#24-26 Ver#3 BAKER - Energy Closest Approach Page 3 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 [Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan [Facility North Fork Unit(NAD27) CALCULATION RANGE& CUTOFF From: 20.80ft MD [To: 10000.20ft MD C-C Cutoff: (none) OFFSET WELL CLEARANCE SUMMARY(7 Offset Wellpaths selected)Ellipse separations calculated in Closest Approach plane 1 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 EU Sep Ell Sep Dvrg from Status Facility Slot Well Wellbore Wellpath [ft] [ft] [ft] [ft] [ft] [ft] North Fork Unit'North Fork#I4- NFU NFU#14- OnTRAK MWD<204-11700'> 620.80 47.07 9820.80 634.41! 33.01 9920.801 PASS (NAD27) 25(Hemlock) #14-25 25 North Fork Unit North Fork#23- NFU NFU#23- NaviTrak MWD<177- 10000.20 21.481 46.19 1000020 PASS (NAD27) 25 #23-25 25 13045'>OnTrak<3183-10785'> 20.80 59.37 NF#22-35 320.80, 66.229220.80 328.38 53.01 9220.80 PASS North Fork Unit North Fork#22- NF#22- NaviTrakMWD<181- (NAD27) 35 35 2945'>OnTrakMWD<3044-10700'> � North Fork Unit North Fork#34- NFU NFU#34- PGMS GyroData<100-2500'>MWD 1919.91 I 78.14 8520.80 1914.83 58.83 8720.80 PASS (NAD27) 26 #34-26 26 (HAL)<2550-9021'> orth Fork Unit North Fork#42- Mir NFU#42- AD27) 35 #42-35 35 NFU 42-35 Vers#7 20.80 108.02 30025 119.00 94.82 30025 PASS -1 North Fork Unit North Fork#32- NFU NFU#32- OnTrak MWD<196-12070'> 20.80 119.54 9220.80 20.80 106.32 10000.20 PASS (NAD27) 35(Tyonek) #32-35 35 NF#41-35 North Fork#41- NF#41- GyroData PGMS<100-9932'>Inclination (NAD27) 35 35 NF#41-35 ONLY<10070-123345 308.57 1596.24 10000.20 308.5711474.56 10000.20 PASS Ea ceb Clearance Report FA` NFU#24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 4 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 ,Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan (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 ValueM).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] [ftI [ft] [ft] MI Bearing Clear Dist MASD Sep Status 1°J [ft' ]ft] [ft] 20.861 20.80 120.80--1T _ 120.80 0.00r 0.00 121.83 121.62 1.04 -58.50 27 21.151 270.46585 . 12.98 46.36PASS 13.30 45.211 PASS 220.80t 220.80 0.00 0.00 222.35 222.12 2.37 -56.50 272.40 56.56 13.19 43.37 PASS 300.25 300.25 0.00 0.00 301.87 301.60 3.63 -54.55 273.80 54.68 13.33 41.36 PASS 1 320.80t 320.80 g, 0.07 0.00 322.45x, 322.17 3.94 -54.01 274.09 54.16 13.35 40.81 PASS 420.80t 420.76 2.53 -0.09 422.441r_ 422.11 5.51 -51.32 273.32 51.33 13.51 37.82 PASS 520.80t 520.58 8.48 -0.30 522.251 521.88 6.73 -48.55 267.92 48.31 13.72 34.59 PASS 620.80t 620.13 17.90 -0.63 621.64 621.24 6.52 -46.29 256.00 47.07 14.03 33.04 PASS 634.411 633.65 19.46 -0.68 635.19, 634.78 6.51 -45.95 254.05 47.10 14.09 33.01 PASS 700.25 698.95 27.86 -0.97 700.30 699.87 6.19 -44.28 243.41 48.44 14.39 34.05 PASS -�_ 720.801 719.30 30.72 -1.07 720.55 720.12 5.98 -43.75 239.90 49.34 14.49 34.85 PASS [ 820.80t _818.33 44.63 -1.56 819.08 818.60 4.44 -41.25 224.65 56.49 14.97 41.52 PASS 900.25 897.01 55.68 -1.94 897.62; 897.10 3.06 -39.18 215.29 64.46 15.31 49.15 PASS 920.80t 917.36 58.47 -2.13 917.91; 917.38 2.72 -38.64 213.221 66.64 15.40 51.25 PASS 1020.801 1016.61 70.18 -5.57 1017.2 16.63 0.97 -35.52 /0T 75.41 lif 59.51 P 1120.80t 1115.94 78.73 -13.19 1116.50 1115.69 -0.81 -29.28 191.43 81.15, 16.58' 64.57 PASS 1220.80t 1215.08 84.10 -24.97 1212.64 1211.22 -3.38 -18.93, 176.05 87.78 17.01 70.76 PASS 1320.80t 1313.77 86.29 -40.87 1305.67 1303.12 7.345.044 159.06 100.81 17.14 83.68 PASS 1420.801 1411.74 85.28 -60.86 1395.94 1391.68 -11.76 11.82 143.17 122.88 17.15 105.74 PASS 1508.71 81.08 -84.87 1482.74 1476.28 _ -15.97 30.78 130.00 154.41 17.40 137.01 PASS 1620.801 1604.42 73.69 -112.84 1564.22 1555.12 -19.65 51.00 119.67 194.91 17.71 177.21 PASS 1720.80t 1698.61 63.15 -144.70 1638.90 1626.73 -23.24 71.91 111.74 244.03 18.22 225.81 PASS 1820.80t 1791.02 49.47 -180.36 1705.55 1689.89 -26.99 92.83+ 105.64 301.17 18.76 282.41 PASS 1822.49 1792.56 49.22 -180.99 1706.65 1690.93 -27.06 93.20 105.55 302.20 18.78 283.42 PASS I 1920.801 1882.42 34.19 -217.94 1768.98 1749.27 - -30.91 114.77 101.07 364.23 19.28 344.95 PASS 2020.80t 1973.82' 18.91 -255.53 1829.06 1804.87 -34.71 137.22 97.77 430.89 19.74 411.15 PASS 2120.80t 2065.22 3.62 -293.11 1885.05 1856.05 -38.28 159.64 95.29 500.49 20.16 480.33 PASS 2220.80t 2156.62 -11.66 -330.70 1938.56 1904.34 -41.73 182.40 93.35 572.56 20.57 551.98 PASS 2320.80t 2248.01 -26.94 -368.29 1989.25 1949.54 -45.05 205.12 91.81 646.69 20.97 625.72 PASS 2420.80t 2339.41 -42.23 -405.87 2039.46 1993.76 -48.34 228.67 90.55 722.61 21.39 701.22 PASS Ea cel Clearance Report Irak NFU#24-26 Ver#3 CookBAKER Inlet Energy_ Closest Approach Page 5 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION 'Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field ]North Fork Wellbore NFU#24-26 Wel!plan 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 f=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACK Ellipse ACR [ft] [ft] IftI IftI [ft] Iftl IftI [ft] Bearing Clear Dist MASD Sep Status 101 [ft] [ft] [ft] ' 2520.801 2430.81 -57.51 -443.46 2092.09 2039.70 -51.90 254.11 89.54 799.75 21.86 777.88 PASS 2620.80t 2522.21 -72.80 -481.04 2147.97 2088.22 -55.78 281.55 88.72 877.61 22.40 855.21 PASS 2720.80t 2613.61 -88.08 -518.63 2194.52 2128.35 -59.13 304.89 87.99 956.29 22.81 933.48 PASS 2820.80t 2705.01 -103.36 -556.22 2237.35 2164.92 -62.37 326.96 87.34 1036.04 23.22 1012.82 PASS 2920.80t 2796.41 -118.65 -593.80 2279.53, 2200.53 -65.75 349.32 86.79 1116.84 23.38 1093.46 PASS 3020.80t 2887.80 -133.93 -631.39 2329.571 2242.49 -69.84 376.26 86.36 1198.28 23.75 1174.53 PASS 3120.80t 2979.20 -149.21 -668.97 2384.30 2288.25! -74.39 405.94 86.02 1280.02 24.20 1255.82 PASS 3220.80t 3070.60 -164.50 -706.56 2441.20 2335.78 -79.22 436.85 85.73 1361.84 24.70 1337.14 PASS 3320.80t 3162.00 -179.78 -744.14 2496.02 2381.55 -83.95 466.64 85.48 1443.71 25.20 1418.51 PASS 3420.80t 3253.40 -195.06 -781.73 2551.66 'LL 2427.95 -88.69 496.99 85.25 1525.71 25.74 1499.98 PASS 3520.80t 3344.80 -210.35 -819.32 2609.631 2476.27 -93.84; 528.58 85.06 1607.71 26.33 1581.39 PASS 3620.80t 3436.20 -225.63 -856.90 2666.21 2523.43 -98.96 559.42 84.89 1689.72 26.92 1662.80 PASS 3720.80t 3527.60 -240.92 -894.49 2720.62 2568.77 -103.92 589.11, 84.72 1771.77 27.51 1744.26 PASS 3820.80t 3618.99 -256.20 -932.07 2768.63 2608.67 -108.29 615.44 84.54 1854.03 28.04 1825.99 PASS 3920.80t 3710.39 -271.48 -969.66 2825.43 2655.78 -113.54 646.72 84.42 1936.45 28.70 1907.75 PASS 4020.80t 3801.79 -286.77 -1007.24 2880.27 2701.26 -118.79 676.92 84.30 2018.86 29.35 1989.51 PASS 4120.80t 3893.19 -302.05 -1044.83 2928.71 2741.37 -123.47 703.68 84.17 2101.40 29.94 2071.46 PASS 4220.80t 3984.59 -317.33 -1082.42 2991.01 2792.95 -129.21 738.14 84.10 2183.99 30.41 2153.58 PASS 4320.80t 4075.99 -332.62 -1120.00 3052.34 2843.85 -134.56 771.92 84.02 2266.44 30.93 2235.52 PASS 4420.801 4167.39 -347.90 -1157.59 3117.53 2898.04 -140.33 807.70 83.97 2348.76 31.42 2317.34 PASS 4520.80t 4258.78 -363.18 -1195.17 3182.08 2951.85 -145.98 842.91 83.92 2430.85 31.93 2398.92 PASS j 4620.801 4350.18 -378.47 -1232.76 3242.34 3002.16 -151.19 875.67 83.85 2512.82 32.44 2480.39]PASS 4720.80t 4441.58 -393.75 -1270.35 3303.14 3052.97 -156.35 908.67 83.78 2594.75 32.97 2561.78r PASS { 4820.80t 4532.98 -409.04 -1307.93 3369.17 3108.23 -161.83 944.37 83.74 2676.55 33.56 2642.99 PASS 4920.80t 4624.38 -424.32 -1345.52 3431.84 3160.79 -167.10 978.10 83.68 2758.16 34.14 2724.02 PASS 5020.80t 4715.78 -439.60 -1383.10 3489.95 3209.57 -171.78 1009.33 83.61 2839.75 34.70 2805.04 PASS 5120.80t 4807.18 -454.89 -1420.69 3553.38 3262.85 -176.76 1043.40 83.56 2921.31 35.33 2885.98 PASS 5220.801 4898.58 -470.17 -1458.27 3620.21 3319.09 -182.01 1079.10 83.52 3002.68 36.00 2966.68 PASS 5320.80t 4989.97 -485.45 -1495.86 3686.54 3375.00 -187.30 1114.41 83.48 3083.92 36.69 3047.23 PASS 5420.801 5081.37 -500.74 -1533.45 3750.44 3428.97 -192.12 1148.27 83.44 3165.01 37.37 3127.64 PASS Ea ceB Clearance Report VA. Cook Inlet Ener NFU#24-26 Ver BAKER - Energy Closest Approachh Page 6 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy !Slot North Fork#24-26 jArea Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan !Facility North Fork Unit(NAD27) 1 CLEARANCE DATA-Offset Wellbore:NFU#14-25 Offset Wel'path: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] MI IftI [ft] Ift] [ft] Ift] Bearing Clear Dist MASD Sep Status 11 IftI [ft] Iftl 5520.80t 5172.77` -516.02 -1571.03 3819.241 3487.16 -197.24 _ 1184.62 83.40 3246.00 38.10 3207.90 PASS 5534.27 5185.09 -518.08 -1576.10 3829.251_ 3495.64 -197.99 1189.89 83.40 3256.89 38.21 3218.68 PASS 5620.80f 5264.94 -530.63 -1606.95 _ 3891.41 3548.35 -202.65 1222.51 83.39 3325.67 38.87 3286.79 PASS 5720.801 5358.99 -543.41 -1638.39 3967.68 3613.15 -208.38 1262.32L 83.41 3402.11 39.69 3362.42 PASS 5820.80t 5454.69 -554.32 -1665.22 4034.85 3670.25 -213.69 1297.2 83.44 3475.17 40.41 3434.75 PASS 5920.804- 5551.78 -563.33 -1687.38_ 4090.78 3717.69 -218.36 1326.55r 83.47 3544.95 41.01 3503.94 PASS 6020.801 5649.98 -570.42 -1704.80 4150.20 3767.94 -223.37 1357.86 83.54 3611.42 41.61 3569.82 PASS 6120.801 5749.03 -575.56 -1717.44 4231.67 3836.82 -230.23 1400.81 83.68 3674.14 42.39 3631.75 PASS 6220.801 5848.66 -578.74 -1725.26] 4283.58 3880.58 -234.70 1428.38 83.77, 3733.25 42.85 3690.39 PASS 6320.80t 5948.60 -579.95 -1728.24 :4335.64, 3924.22 -239.44 '.1456.37 83.90 3788.91 43.29 3745.62 PASS 6332.20 5960.00 -579.96 -1728.27 4341.63 3929.23 -240.01 1459.62 83.91 3795.03 43.32 3751.71, PASS r6420.801 6048.60 -579.96 -1728.27 4429.65 4002.81 -248.18 1507.21 84.15 3842.35 44.04 3798.32 PASS 6520.801 6148.60 -579.96 -1728.27 4502.74 4064.04 -254.79 1546.58 84.33 3895.61 44.58 3851.03 PASS 6620.801 6248.60 -579.96 -1728.271 4556.87 4109.17 -259.82 1576.04 84.47 3949.45 44.95 3904.51 PASS 6720.80t 6348.60 -579.96 -1728.27 "4629.03` 4169.05 -266.48 1615.76 84.65 4003.90 45.517-37958.39 P, 6820.80t 6448.60 -579.96 -1728.271 4743.52, 4264.35 -277.147 1678.30 84.92 4058.00 46.51 4011.49 PASS _ 6920.801 6548.60 -579.96 -1728.274- 4860.60[ 4362.36 -287.551 1741.50 85.18 4111.51 47.54 4063.97 PASS 7020.801 6648.60 -579.96 -1728.271 4931.68 4422.08 -293.44 1779.59 85.33 4164.68 48.10 4116.58 PASS 7120.801 6748.60 -579.96 -1728.271 4970.35 4454.39 -296.61 1800.60 85.41 4218.60 48.34 4170.26 PASS 7220.80t 6848.60 -579.96 -1728.27 5067.54 4535.28 -304.91 1853.82 85.61 4272.99 49.19 4223.80 PA' 7320.801- 6948.60 -579.96 -1728.27 7700.71 7003.27 -418.66 2567.27 87.85 4298.91 59.74 4239.17 PASS 7420.801- 7048.60 -579.96 -1728.27 7801.221 7103.77 -420.10 2566.03 87.87 4297.62 60.01 4237.62 PASS 7520.801 7148.60 -579.96 -1728.27 7912.83 7215.35 -422.31 2564.55 87.90 4296.23 60.30 4235.93 PASS 7620.801- 7248.60 -579.96 -1728.27 8020.271- 7322.74 -424.93 2562.90 87.93 4294.61 60.60 4234.01 PASS 7720.80t 7348.60 -579.96 -1728.27 8111.27 : 7413.69 -427.37 2561.38 87.96 4292.86 60.90 4231.97 PASS 7820.801- 7448.60 -579.96 -1728.27 8196.74 7499.15 -428.60' 2560.40 87.98 4291.64 61.18 4230.46 PASS 7920.801- 7548.601 -579. 96 -1728.271 1 8285. 71 r- 7588.11 -430.081 2559.45 88.00 4290.52 61.48 4229.04 PASS 8020.801- 7648.60 -579.96 -1728.27 8348.76 7651.14 -430.83 2559.15 88.01 4290.01 61.75 4228.27 PASS 8120.801 7748.60 -579.96 -1728.27 8419.11 7721.50 -431.08 2559.47 88.01 4290.41 62.03 4228.38 PASS 8220.80t 7848.60 -579.96 -1728.27 8511.11 7813.50 -431.48 2560.02 88.02 4291.00 62.35 4228.65 PA Ea ceb Clearance Report Irak NFU #24-26 Ver#3 BAKER Cook Inlet Energy Closest Approach Page 7 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION [Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan 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 lftl lftl lftl lftl lftl lftl Kt' Bearing Clear Dist MASD Sep Status 101 Iftl Iftl IN 8320.80$ 7948.60 -579.96 -1728.27 8571.74 7874.12 -431.65 2560.77 88.02 4292.24 62.63 4229.61 PASS 8420.801 8048.60 -579.96 -1728.27 8668.82 7971.18 -431.31 2562.57 88.02 4294.12 62.96 4231.16 PASS 8520.801 8148.60 -579.96 -1728.27 8748.67 8051.02 -430.99 2564.09 88.01 4296.05 63.26 4232.79 PASS 8620.801; 8248.60 -579.96 -1728.27 8824.36 8126.67 -429.43 2566.04 87.99 4298.67 63.55 4235.12 PASS 8720.80f'348.60 -579.96 -1728.27 8920.10 8222.35 -427.51 2568.79 87.97 4301.62 63.8 37.75 PAS 8820.80$ 8448.60 -579.96 -1728.27 9049.79 8351.95 -423.98 2571.98 87.92 4304.16 64.22 4239.94 PASS 8920.80$ 8548.60 -579.96 -1728.27 9262.89 8564.99 -420.64 2572.98 87.88 4304.23 64.66 4239.57 PASS 9020.80$ 8648.60 -579.96 -1728.27 9375.65 8677.75_ -419.95 2572.46 87.87 4303.80 65.01 4238.79 PASS 9120.801 8748.60 -579.96 -1728.27 9505.28 8807.37 -420.39 2571.05 87.87 4302.68 65.38 4237.30 PASS ; 9220.80$ 8848.60 -579.96 -1728.27 9620.05 8922.11 -419.71 2569.23 87.87 4301.11 65.74' 4,2.3$.37 PASS 9320.801 8948.60 -579.96 -1728.27 9729.65 9031.68 -417.77 2567.21 87.84 4299.35 66.08 4233.27' PASS 9420.801 9048.60 -579.96 -1728.27 9830.64 9132.64 -416.36 2565.26 87.82 4297.47 66.42 4231.05 PASS 9520.801 9148.60 -579.96 -1728.27 9926.921 9228.90 -415.21 2563.34 87.80, 4295.52 66.76 4228.77 PASS 9620.80$ 9248.60 -579.96 -1728.27 10019.80 9321.75 -414.52 2561.65 87.79 4293.73 67.10 4226.63 PASS 9720.80$ 9348.60 -579.96 -1728.27 10084.24 9386.18 -414.3/ 0.75 87.79 4292.38 67.42 4224.96 PASS 9752.20 9380.00 -579.96 -1728.27 10102.45 9404.40 -414.38 2560.62 87.79 4292.15 67.52 4224.64 PASS 9820.80$ 9448.60 579.961 -1728.27 10143.56 9445.50 -414.47 2560.52 87.79 4291.98 67.74 4224.24 PASS 9920.801 9548.60 -579.96' -1728.27 10233.18 9535.13 -414.78 2560.77 87.80 4292.24 68.13 4224.11 PASS 10000.20 9628.00 -579.96 -1728.27 10284.63 9586.58 -414.87 2561.101 87.80 4292.75 68.40 4224.35, PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#14-25 Offset Wellpath:OnTRAK MWD<204- 11700'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft @a ce0 Clearance Report Ira. NFU#24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 8 of 38 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 1 HOLE& CASING SECTIONS-Offset wellbore:NFU#14-25 Offset Welipath:OnTRAK MWD<204-11700'> String/Diameter Start MD End MD ' Interval r Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] MI Iftl Iftl [ft] [ft] 16in Conductor 0.00 178.00 178.00 -21.00 156.98 0.28 -36.19 0.66 -35.63 10.75in Casing Surface 0.00 2977.00 2977.00 -21.00 2760.54 0.28 -36.19 -38.86 204.53 7.625in Casing Intermediate 0.00 5297.00 5297.00 -21.001 4706.76 0.28 -36.19 -98.55 584.68 WELLPATH COMPOSITION-Offset Wellbore:NFU#14-25 Offset Welipath:OnTRAK MWD<204-11700'> Start MD End MD Positional Uncertainty Model I Log Name/Comment Wellbore MI Iftl 0.00 2927.00 OnTrak(Standard) OnTRAK MWD<204-2992'> j NFU#14-25 2927.00 5249.00 OnTrak(Standard) OnTRAK MWD<3016-5306'> j NFU#14-25 5249.00 11700.00 OnTrak(Standard) OnTRAK MWD<5314- 11700'> NFU#14-25 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 10.00ft Fa ceB Clearance Report FAR NFU#24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 9 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 !Field North Fork Wellbore NFU#24-26 Wellplan ;Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-l0785'> Facility:North Fork Unit(NAD27) Slot:North Fork#23-25 Well:NFU#23-25 Threshold Value=0.00 ft $=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Iftl Iftl iftl IftI Iftl Iftl Iftl iftl Bearing Clear Dist MASD Sep Status 11 Iftl Iftl Iftl 20.80 1 20.80 0.00 0.00 25.001 20.77 -0.46!r 59.37 90.44 59.37 12.96 46.41 PASS 21.481. 21.48 0.00 0.00' 25.68i 21.45 _ -0.461 59.37 90.44 59.37 13.18 46.19 PASS 120.801. 120.80 0.00 0.00 124.30 120.06 -0.75E 60.00 90.72 60.01 13.24 46.77 PASS 220.80$ 220.80 0.00 0.00 223.81 219.56 -1.52 61.70 91.41 61.73 13.12 48.611 PASS 300.25 300.25 0.00 0.00 303.34 299.07 -2.18 63.32 91.97 63.37 13.24 501 PASS 320.80t 320.80 0.07 0.00 324.00 319.73 -2.28 63.68 92.12 63.73 13.27 50.471 PASS 420.80$ 420.76 2.53 -0.09 423.79 419.50 -2.55 65.29 94.45 65.59 13.43 52.17 PASS 520.80$ 520.58 8.48 -0.30 _ 522.51 518.19 -2.69 67.89 99.30 69.14 13.64 55.50 PASS 620.80$ 620.13 17.90 -0.63 618.87 614.36 -1.42 73.46 104.62 76.79 13.95 62.84 PASS 700.25 698.95 27.86 -0.97 695.29 690.34 1.15 81.20 108.01 86.83 14.34 72.49 PASS 720.80t' 719.30 30.72 -1.07 714.98 709.86 2.10, 83.63 108.67 89.90 14.43 75.47 PASS 900.25 _ 897.01 55.68 _ I 111.89 110.62 123.39 15.38 108.01 PASS - i_- 884.13 876.24 12.84 920.80t 917.36 58.47 2.131 903.20 894.82 14.291- 115.90 110.52 128.04 15.47 112.57 PASS 1020.80 016.61 70.18 -5.57 994.35 983.02 22.19 <137.46 108.55 154.56 16.11 138:4` ` 1120.80$ 1115.94 78.73 -13.19r-1082.06 1066.80 31.24 161.78 105.18 187.84 16.82 171.02 PASS 1220.80t 1215.08 84.10 -24.97 1164.92 1144.87 40.81 187.84 101.50 228.24 17.54 210.70 PASS 1320.801.7_ 1313.77 86.29 -40.87 1242.60 1216.93 50.75 215.05 97.91 275.93 18.22 257.72 PASS 1 1420.80$ 1411.74 85.28 -60.86 1314.51 1282.63 60.75 242.53 94.62 330.63 18.89 311.74 PASS 1520.80$ 1508.71 81.08 84.87 1380.10 1341.61 70.51*269.51 91.71 391.94 19.48 372.46 PASS 1620.80t 1604.42 73.69 -112.84 1440.19 1394.83 79.96, 295.76 89.12 459.27 20.01 439.27 PASS 1720.80$, 1698.611 63.15 -144.70 1494.08, 1441.88 88.85 320.48 86.84 531.95 20.47 511.48 PASS 1820.80f, 1791.02' 49.47 -180.36 _ 1541.46'1 1482.66 97.16 343.13 84.80 609.43 20.86 588.57 PASS 1822.49 _ 1792.56 49.22 -180.99', 1542.21 1483.30 97.301- 343.49 84.76 610.77 20.88 589.90 PASS 1920.801. 1882.42;404.19 -217.9411111584411111111 1519.18 105.17' 364.42 83.05 690.02 21.13 668.89 PASS 2020.80t, 1973.821 18.91 -255.53] 1625.701 1553.73 113.067_ 385.45 81.64 772.14 21.39 750.75 PASS 2120.80t 2065.22! 3.62 -293.111 1664.70 1586.04 120.65'_ 405.92 80.50 855.55 21.65 833.90 PASS 2220.801. 2156.62 -11.66 -330.70'1- 1700.55 1615.40 127.74,E 425.24 79.55 940.10 21.88 918.22 PASS 368.291 2320.801. 2248.01 -26.94 - 1734.17 1642.59 134.54 443.80 78.75 1025.72 22.10 1003.62 PASS 242 2339.41 -42.23 -405.871OF1765.91 1667.96 141.08 461.73 78.07 1112.29 22.32 1089.97 PASS Ea ceB Clearance Report VA. Cook Inlet Ener NFU #24-26 Ver BAKER Energy Closest Approachh Page 10 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION 'Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan '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 1-=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 lftl [ft] lft] Iftl Iftl IN Bearing Clear Dist MASD Sep Status 1°1 IftI Iftl Iftl 2520.801- 2430.81 -57.511 -443.46` 1805.43 1699.26 149.33 484.40 77.43 1199.53 22.67 1176.86 PASS 2620.80t 2522.21 -72.80 -481.04 1844.31 1729.90 157.50 506.90 76.88 1287.18 23.02 1264.15 PASS 2720.801- 2613.61 -88.08 -518.63 1885.08 1761.87 166.12 530.67 76.38 1375.18 23.39 1351.79 PASS 2820.801 2705.01 -103.36 -556.22 1928.02 1795.47 175.23 555.81 75.94 1463.38 23.76 1439.62 PASS 920.801 2796.41 -118.65 -593.80 1969.45 1827.83 184.04 580.14 75.54 1551.74 23.91 1527.83 PASS ' 3020.80t 2887.80 -133.93 -631.39 2007.24 1857.24 192.21 602.42 75.19 1640.34 24.11 1616.23 PASS 3120.80[ 2979.20 -149.21 -668.97 2044.27 1885.94 200.39 624.35 74.87 1729.20 24.32 1704.87 PASS 3220.801- 3070.60 -164.50 -706.56 2084.91 1917.32 209.51 648.49 74.57 1818.27 24.60 1793.67 PASS 3320.801' 3162.00 -179.78 -744.14 2127.05 1949.83 219.00 673.58 74.29 1907.44 24.91 1882.54 PASS 3420.80f 3253.40; -195.06 -781.73 2168.48 1981.75 228.32 698.29 74.04 1996.70 25.22 1971.48, P l 3520.80t 3344.80 -210.35 -819.32 2208.94 2012.87 237.38 722.50 73.81 2086.06 25.53 2060.53 PASS 246.30 746.62 73.60 2175.53 25.86 2149.67 PASS 255.13 770.67 73.41 2265.10 26.20 2238.90PASS 3620.801 3436.20 -225.63 -856.90 2249.11 2043.73 3720.801 3527.60 -240.92 -894.49 2289.04 2074.37 , 3820.801 3618.99 -256.20 -932.07 2328.69 2104.73 263.86 794.62 73.24 2354.77 26.55 2328.22 PASS 3920.801 3710.39 -271.48 -969.66 2367.01 2134.04 272.29 817.83 7trar 2444.53 26.89 2417.64 PA 4020.801- 3801.79 -286.77 -1007.24 2404.45 2162.60 280.54 840.58 72.93 2534.41 27.25 2507.16 PASS 4120.80t 3893.19 -302.05 -1044.83 2447.41 2195.32 290.03 866.75 72.79 2624.40 27.66 2596.74 PASS r 4220.801 3984.59 -317.33 -1082.42 2540.68 2266.99 310.85 922.69 72.61 2713.89 28.59 2685.31 PASS 4320.80f 4075.99 -332.62 -1120.00 2581.94 2298.89 320.13 947.15 72.48 2803.08 29.01 2774.07 PASS i ilau26 ` 4167.39 -347.90 -1157.59 2622.97 2330.59 329.41 971.50 72.35 2892.34 29.45 2862.89 PASS 4520.801 4258.78 -363.18 -1195.17 2661.91 2360.62 338.22 994.66 72.24 2981.67 29.86 2951.81 PASS 4620.80f 4350.18 -378.47 -1232.76 2700.22 2390.13 346.89 1017.51 72.13 3071.10 30.28 3040.82 PASS ' 4720.80f 4441.58 -393.75 -1270.35 2739.03 2419.97 355.67 1040.72 72.03 3160.63 30.71, 3129.92 PASS 4820.801- 4532.98 -409.04 -1307.93 2779.12 2450.75 364.70 1064.76 71.94 3250.23 31.17- 3219.06 PASS 4920.801' 4624.38 -424.32 -1345.52 2819.01 2481.35 373.65 1088.73 71.85 3339.89 31.63308.26 PASS 5020.80t 4715.78 -439.60 -1383.10 2858.74 2511.80 382.57 1112.65 71.77 3429.61 32.10 3397.52, PASS 5120.80t 4807.18 -454.89 -1420.69 2898.26 2542.05 391.50 1136.45 71.69 3519.39 32.571 3486.821 PASS 5220.80t 4898.58 -470.17 -1458.27 2946.93 2579.30 402.53 1165.79 71.60 3609.20 33.141 3576.06 PASS 5320.80t 4989.97 -485.45 -1495.86 3004.77 2623.67 415.34 1200.60 71.53 3698.88 33.80 3665.08 PASS 5420.80t 5081.37 -500.74 -1533.45 3041.61 2651.97 423.36 1222.78 71.47 3788.50 34.27 3754.23 PASS Ea ceO Clearance Report Mil NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 11 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 'Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan 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 [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status Ii IftI [ft] [Hi 5520.801, 5172.77( 516.021 -1571.03 3104.341 2700.18 437.08 1260.49 71.40 3878.09 34.76 3843.33 PASS 5534.27 1 5185.09' -518.08 -1576.10 3113.35'r 2707.13 439.06 1265.88 71.39 3890.15 34.83 3855.31 PASS 5620.80t 5264.94 -530.63 -1606.95 3174.50 2754.36 452.54 1302.31 71.33 3966.53 35.227 3931.31 PASS 5720.80t 5358.99 -543.41 -1638.39 3209.62 2781.52 460.32 1323.17 71.28 4052.36 35.51 4016.85 PASS 5820.801 5454.69 -554.32 -1665.22 3241.56 2806.11; 467.39 1342.30 71.24 4135.71 35.78 4099.93 PASS 1 5920.801- 5551.78 -563.33 -1687.38 3275.44 2832.06 474.86 1362.75 71.20 4216.40 36.04 4180.36 PASS 6020.801- 5649.98 -570.42 -1704.80 3321.40 2867.12 485.02 1390.69 71.17 4294.22 36.35 4257.87 PASS 6120.801- 5749.03 -575.56 -1717.44 3370.33 2904.31 495.88 1420.56 71.15 4368.92 36.66 4332.26 PASS 6220.801- 5848.66 -578.74 -1725.26 3442.39 2959.011 512.02 1464.62 71.12 4440.18 37.06 4403.12 PASS 6320.801' 5948.60 -579.95 -1728.24 3526.84 3023.17 531.14 1516.09 71.10 4507.59 37.50 4470.09 PASS _ _ 6332.20 I 5960.00 -579.96 -1728.27 3537.16 3031.02 533.48 1522.36 71.09 4515.01 37.54' 4477.47 PASS 6420.801.1 6048.60 -579.96 -1728.27 3607.23 3084.37 549.45 1564.90 71.07 4572.44 37.84 4534.60 PASS 6520.801- 6148.60 -579.96 -1728.27 3682.36 3141.55 566.72 1610.471 71.05 4637.28 38.19 4599.10 PASS 6620.801- 6248.601 -579.96 -1728.27 3762.371 3202.451 585.20 1658.961 71.02 4702.12 38.57 4663.55 PASS 6720.801 6348.601 -579.96 -1728.2177K58.93'.173276.111 606.33 1717.63' 71.00 4766.70 39.0614727.64 PASS 6820.801- 6448.60 -579.96 -1728.27 3930.41 3330.78 621.73 1761.09 71.00 4831.19 39.45 4791.74 PASS 1 6920.801- 6548.60 -579.96 -1728.27 3999.351 3383.41 636.71 1803.02 70.99 4895.79 39.85 4855.93 PASS i 7020.801- 6648.601 -579.96 -1728.27 4077.05 3442.67 653.47 1850.39 70.98 4960.46 40.3114920.14 PASS [ 7120.801 6748.601 -579.96 -1728.27 4163.50 3508.70 672.28 1902.95 70.97 5025.02 40.84F 4984.17 PASS i . 7220.801- 6848.60 -579.96 -1728.27 4246.87 3572.47 690.51 1953.45 70.96 5089.42 41.37. ,; 048.05 PASS 7320.801- 6948.60 -579.96 -1728.27 4324.54 3631.90 707.70 2000.41 70.95 5153.79 41.89 5111.90 PASS 1 7420.801 7048.60 -579.96 -1728.27 4412.64 3699.39 727.35 2053.52 70.93 5218.06 42.48 5175.58 PASS 7520.801 7148.60 -579.96, -1728.27 4506.41 3771.39 748.15 2109.88 70.91 5282.12 43.13 5239.00 PASS 7620.801 7248.60 -579.96 1728.27 4600.66 3843.97 768.84 2166.34 70.90 5345.91 43.80 5302.12 PASS 7720.801 7348.60 -579.94 1728.27 4649.37 3881.44 779.55 2195.56 70.89 5409.80 44.22 5365.59 PASS 7820.801 7448.60 -579.91 -1728.27 8676.68 7509.02 1231.01 3435.48 70.67 5472.44 58.56 5413.88 PASS 7920.801- 7548.60 -579.96 -1728.27 8794.96 7627.29 1229.98 3434.35 70.68 5471.26 58.88 5412.38 PASS 8020.801- 7648.60_ -579.96 -1728.27 8908.69 7741.00 1228.73 3432.89 70.69 5469.69 59.20 5410.48 PASS 8120.801- 7748.60 -579.96 -1728.27 9014.44 7846.73 1227.24 3431.40 70.70 5467.89 59.54 5408.35 PASS 8220.801- 7848.60 -579.96 -1728.27 9095.40 7927.68 1226.36 3430.32 70.70 5466.27 59.89 5406.37 PASS Ea ceB Clearance Report Irak NFU#24-26 Ver#3 BAKER _ Cook Inlet Energy_ Closest Approach Page 12 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 'Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan [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 [ft] [ft' IRI [ft] [ft] [ft] Ift] [ft] Bearing Clear Dist MASD Sep Status _ _ 1°I IN [ft! [HI8320.801- 7948.60 -579.96 -1728.271 9173.16 8005.44 1225.87 3429.47 70.70 5465.02 60.26 5404.76 PASS 8420.80[, 8048.60 -579.96 -1728.27 9287.07 8119.33 1225.07 3428.37. 70.71 5463.89 60.62 5403.27 PASS 8520.801- 8148.60 -579.96 -1728.27 9358.16 8190.42 1224.28 3427.87 70.71 5462.86 61.00 5401.86 PASS 8620.801- 8248.60 -579.96 -1728.27 9445.91 8278.16 1223.15 3427.70 70.73 5462.25 61.39 5400.86 PASS 8720.801- 8348.60 -579.96 -1728.27 9555.63 8387.87 1221.46 3427.60 70.74 5461.66 61.78 5399.88 PASS 8820.801 8448.60 -579.96 -1728.27 9654.47 8486.70 1220.34 3427.23 70.75 5460.93 62.17 5398.76 PASS 8920.801-j 8548.60 -579.96 -1728.27 9755.22 8587.45 1219.98 3426.61 70.75 5460.23 62.57 5397.66 PASS 9020.80t 8648.60 -579.96 -1728.27 9879.73 8711.95 1219.31 3425.61 70.76 5459.29 62.96 5396.33 PASS 9120.80t 8748.60 -579.96 -1728.27 9991.06 8823.27 1218.30 3424.44 70.76 5457.99 63.36 5394.63 PASS 9220.80;, 8848.60 -579.96 -1728.27 10094.05 8926.25 1217.30 3423.27 70.77 5456.60 63.77 5392.83 PASS 9320.80t 8948.60 -579.96 -1728.27 10192.69 9024.88 1215.94 3422.24 70.78 5455.17 64.18 5390.99 PASS j 9420.80f 9048.60 -579.96 -1728.27 10286.41 9118.58 1214.22 3421.51 70.79 5453.83 64.60 5389.22 PASS 9520.801- 9148.60 -579.96 -1728.27 10381.22 9213.36 1212.22 3420.97 70.81 5452.60 65.03 5387.56 PASS 9620.801- 9248.60 -579.96 -1728.27 10472.14 9304.26 1210.22 3420.58 70.83 5451.47 65.47 5386.00 PASS 9720.801 9348.60 -579.96 -1728.27 10566.70 9398.79 1208.18 3420.37 70.85 5450.55 65.91 5384.64 PASS 9752.20 9380.00 -579.96 -1728.27 10601.43 9433.52 1207.35 3420.31 70.86 5450.25 66.05 5384.20 PASS 9820.80t1 9448.60 -579.96 -1728.27 10663.10 9495.16 1205.74 3420.25 70.87 5449.60 66.36 5383.24 PASS r 9920.80[(_ 9548.60 -579.96 -1728.27 10751.80 9583.83 1203.27 3420.44 70.90 5448.88 66.81 5382.08 PASS 10000.20 9628.00 -579.96 -1728.27 10785.00 9617.02 1202.33 3420.54 70.91 5448.57 67.15 5381.42 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft [Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft €a ceO Clearance Report FA. Cook Inlet Ener NFU #24-26 Ver BAKER — Energy Closest Approachh Page 13 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork 'Wellbore NFU#24-26 Wellplan !Facility North Fork Unit(NAD27) i 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] IN 1 [ft] Ift] ]ft] [ft] [ft] [ft] 16in Conductor 20.55 137.00 116.45 16.07 132.52 -0.28 36.19 -0.39 36.43 10.75in Casing Surface 20.55 3102.00 3081.45 16.07 2698.13 -0.28 36.19 132.93 401.87 WELLPATH COMPOSITION-Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> Start MD End MD 1 Positional Uncertainty Model Log Name/Comment Wellbore IN lftl 20.55 3045.00 NaviTrak(MagCorr) NaviTrak MWD<177-3045'> NFU#23-25 3045.00 10785.00 OnTrak(Standard) OnTrak MWD<3183-10785'> NFU#23-25 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#23-25 Offset Wellpath:NaviTrak MWD<177-3045'>OnTrak<3183-10785'> 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 ceB Clearance Report FM NFU #24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 14 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION _O- perator Cook Inlet Energy Slot North Fork#24-26 [Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 'Field 1North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NF#22-35 Offset Wellpath:NaviTrakMWD<I81-2945'>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 IftI Iftl IftI IN (ft] Ifti Iftl Iftl Bearing Clear Dist MASD Sep Status I°1 Iftl Iftl Iftl 20.80 20.80 0.00 0.00 20.55j 20.80 -60.54 -30.921 207.06 67.981 _ 12.74 55.241 PASS 120.80t 120.80 0.00 0.00 121.02 121.271 -60.07 -31.07 207.35 67.63r 13.01 54.62` PASS - 220.8300.2501' 300.20 0.00 5 0.00 0.00 300.37 300.60 -57.91 -32.23 209.10 66.271'13.07, 53.64 PASS _ � 208.22 66.71 13.17 53.10 PASS 320.80t 320.80 0.07 0.00 320.98 32 -57.68 -32.39 209.29 66.22'° 13.19 53.02 PASS 1 328.381328.38 0.14 0.00 328.58 328.80 -57.59 -32.45 209.34 66.22 13.21 53.01 PASS 420.8011 420.76 2.53 -0.09 421.08 421.30 _ -56.43 -33.06 209.21 67.56 13.39_ 54.17 PASS 520.801-1 520.58 8.48 -0.30 520.68 520.89` -55.25 -33.84 207.76 72.02 13.77 58.26 PASS 620.801'1 620.13 17.90 -0.63 618.77 618.97 -55.44 -34.22 204.61 80.68 14.18 66.50 PASS 700.25 ID 698.951127.86 -0.97 696.92 697.11 , -57.06 -34.04 201.28 91.15 14.51. 76.64 PASS 720.80t7 719.30, 30.72 -1.07 717.11 717.30 -57.52 -34.01 200.47 94.21 14.59 79.61 PASS 820.8011 818.33 44.63 -1.56 812.54 812.65 -60.54 -35.97 198.12 110.80 14.85 95.95 PASS 900.25 897.01 55.68 -1.94 888.07, 887.99 -64.15 -39.90 197.57 126.02 15.10 110.92 PASS - 920.8017 917.36 58.47 -2.13 907.53 907.37 -65.26 -41.14 197.50 130.12; 15.16 114.96 PASS 1020.801- 4016.61' 70.18 -5.57 a 999.27 998: -72.70 -47.71161196.43 150.0415.69 134.36 PASS 1120.801 _ 1115.94 78.73 -13.19 1087.84 1086.04' -84.06 -55.531 194.58 170.84,--- 6.6 12 154.21 PASS 1 1220.801__ 1215.08 84.10 -24.97 1177.90 1174.14 -99.57 -65.891 192.56 192.57 17.71 174.86 PASS 1 1320.801- _ 1313.77 86.29 -40.87 1268.521_ 1262.01 -118.06 -78.06r 190.32 214.06 18.54 195.52 PASS 1420.801` 1411.74 85.28 -60.86 1360.007 1350.06 -139.36 -90.831 187.60 234.87 19.31 215.57 PASS 1520.801. 1508.71 81.08 -84.87 1451.401 1437.30 -162.60 -105.03P 184.73 254.72 20.12 234.61 PASS 1620.801. 1604.42 73.69 -112.84 1543.181 1523.99 -187.72 -121.68 181.94 273.65 21.01 252.64 PASS 1 1720.801' 1698.61 63.15 -144.70 1634.627 1609.36 -214.38 -140.70 179.17 291.56 22.06 269.50 PASS '1 1820.80t1 1791.02 49.47 -180.36 1723.681_ 1691.48 -242.31 -160.83, _ 176.17 308.91 23.29 285.62 PASS 1822.49 { 1792.56 49.22 -180.99 1725.16' 1692.84, -242.80 -161.171 176.12 309.21 23.31 285.90 PASS 1920.80t11882.42 34.19 -217.94 I809.70 ' 1769.59 -271.86 -181.47,`,173.20 328.22 24.61 303.61 PASS ' 2020.801' 1973.82 18.91 -255.53 1896.231 1846.52_ -304.52 -203.86r 170.92 351.39 26.19 325.21 PASS 2120.801 2065.22 3.62 -293.11 1987.11 1925.641 -340. 79 -229.98 169.61 376.94 28.05 348.90 PASS 2220.801- 2156.62 -11.66 -330.70 2077.241_ 2002.84 -377.74 -258.21 168.80 403.62 29.98 373.64 PASS 2320.801- 2248.01 -26.94 -368.29 2160.16 2072.30 -413.75 -285.67 167.94 432.80 31.82 400.98 PASS r 2420.801- 2339.41 -42.23 -405.87 2242.16 2139.44 -451.59 -313.68 167.31 464.82 33.75 431.08 PA Ea ceB Clearance Report FA` Cook Inlet Ener NFU #24-26 Ver BAKER - Energy Closest Approachh Page 15 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 _ Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 ;Field North Fork Wellbore NFU#24-26 Wellplan ;Facility North Fork Unit(NAD27) `CLEARANCE DATA-Offset Wellbore:NF#22-35 Offset WellP ath: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 IftI IftI IftI [ft' [ft] [ft] IftI Iftl Bearing Clear Dist MASD Sep Status 1°1 IftI [ft] Iftl 2520.80t 2430.81 -57.51 -443.46 2331.26 2211.371 -494.19 -344.47 167.23 498.63 35.95 462.69 PASS 2620.80t 2522.21 -72.80 -481.04 2425.62 2287.24 -539.71 -377.29 167.47 532.90 38.31 494.58 PASS 2720.80t 2613.61 -88.08 -518.63 2520.78 2363.58 _ -585.48 -410.95 167.79 567.03 40.74 526.29 PASS 2820.80t 2705.01 -103.36 -556.22 2612.53 2437.051 -629.67 -443.60 167.92 601.24 43.08 558.16 PASS 1 2920.80t 2796.41 -118.65 -593.80 2707.31 2512.991 ; -675.44 -477.08 168.16 635.59 45.26 590.32 PASS 3020.80t 2887.80 -133.93 -631.39 2802.36 2589.031 -721.19 -511.14 168.43 669.78 47.49 622.29 PASS 3120.80t 2979.20 -149.21 -668.97 2891.80 2660.13 -764.38 -543.99 168.52 704.17 49.58 654.59 PASS 3220.80t 3070.60 -164.50 -706.56 2987.90 2736.18' -811.05 -579.67 168.90 738.90 51.80 687.09 PASS I • 3320.80t 3162.00 -179.78 -744.14 3090.09 2817.5 -859.98 -617.46 169.45 772.90 53.85 719.04 PASS 3420.80t 3253.40 -195.06 -781.73 3185.89, 2894.18 -905.27 -652.88 169.72 806.25 55.82 750.43 P 3520.801 3344.80 949.98 687.58 169.90 839.46 57.821 78164', PASS _ -210.35 819.32 3280.72 2970.26 I 3620.80t 3436.20 -225.63 -856.90 3359.84 3033.63 -987.91 -715.99 169.53 873.49 59.47 814.02' PASS 3720.80t 3527.60 -240.92 -894.49 3454.02 3108.80 -1033.90 -749.23 169.62 908.47 61.577 846.90' PASS 3820.80t 3618.99 -256.20 -932.07 3535.54 3173.86 -1073.93 -777.64 169.31 943.76 63.36 880.39 PASS 3920.80t 3710.39 -271.48 66 ":•' "` 3243.961111:-1118.22 -807.58 169.16 980.20 65.38 914.83 PASS' 4020.80t 3801.79 -286.77 -1007.24 3717.78 3318.99-1165.51 -839.01 169.16 1016.66 67.59 949.07 PASS 4120.80t 3893.19 -302.05 -1044.83 3813.01 3395.211 -1213.29 -870.24 169.15 1053.00 69.88 983.13 PASS 4220.80t 3984.59 -317.33 -1082.42 3907.46 3470.97 -1260.50 -901.08 169.12 1089.15 72.18 1016.97 PASS 4320.80t 4075.99 -332.62 -1120.00 4006.76 3550.00 -1309.94 -935.33 169.30 1125.13 74.59 1050.55 PASS 4420.80t 4167.39 -347.90; -1157.59 4105.45 3628.67 -1358.46 -969.91 169.48 1160.46 77.00 1083.46 PASS 4520.80[ 4258.78 -363.18_ -1195.17 4200.06 3704.48 -1404.84 -1002.37 169.51 1195.60 79.34 1116.27 PASS 4620.801 4350.18 -378.47_ -1232.76 4291.311 3777.64 -1449.59 -1033.51 169.46 1230.78 81.61 1149.17 PASS 4720.80[ 4441.58 -393.75 -1270.35 4387.35[ 3854.37 -1496.80 -1066.80 169.55 1266.09 84.02 1182.07 PASS 4820.80t 4532.98 -409.04 -1307.93 4483.351 3930.98 -1543.67 -1100.70 169.65 1301.05 86.43 1214.63 PASS 4920.80t 4624.38 -424.32 -1345.52 4580.76 4008.46 -1591.11 -1135.85 169.81 1335.93 88.87 1247.06 PASS 5020.80t 4715.78 -439.60 -1383.10 4675.57 4084.14 -1637.04 -1169.77 169.90 1370.53 91.26 1279.26 PASS 5120.80t 4807.18 -454.89 -1420.69 4771.29 4160.68 -1683.43 -1203.70 169.98 1405.12 93.70 1311.42 PASS 5220.80t 4898.58 -470.17 -1458.27 4861.73 4232.75 -1727.18 -1236.46 169.99 1439.65 96.00 1343.65 PASS 5320.80t 4989.97 -485.45 -1495.86 4946.33 4299.75 -1768.42 -1267.55 169.91 1474.63 98.14 1376.50 PASS f 5420.80t 5081.37 -500.74 -1533.45 5036.39 4370.91 -1812.82 -1300.36 169.93 1510.18 100.43 1409.75 PASS €a cell Clearance Report FA. NFU #24-26 Ver#3 ��E� Cook Inlet Energy_ Closest Approach Page 16 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan (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 Ift] IRI Iftl Iftl Iftl Iftl Ift1 Bearing Clear Dist MASD Sep Status 101 Iftl Iftl _ MI5520.801. 5172.77 -516.02 -1571.03 5133.96 4448.37. -1860.77 -1335.31, 170.06 1545.53 102.961 1442.57 PASS 5534.27 5185.09 -518.08 -1576.10 5146.69 4458.461 -1867.01 -1339.90' 170.07 1550.28 103.281 1447.00 PASS -1606.95 5245.24 4536.67 -1915.02 -1375.82 170.52 1581.25 105.701 5620.801- 5264.94 -530.63 ; 1475.55 PASS 5720.801 5358.99 -543.41 -1638.39 5337.35 4610.11 -1959.00 -1409.85 170.83 1617.70 107.61 1510.10 PASS 5820.801 5454.69 -554.32 -1665.22 5415.89 4672.25 -1997.00 -1439.22, ,,„, 171.10 1656.68 108.82 1547.86 PASS 1 5920.80t 5551.78 -563.33 -1687.38 5500.61 4738.96 -2038.42 -1471.041 171.66 1698.04 109.85 1588.19 PASS 6020.801 5649.98 -570.42 -1704.80 5594.55 4813.07 -2084.18 -1506.211172.53 1741.07 110.79 1630.28 PASS 6120.801 5749.03 -575.56 -1717.44 5686.80 4886.16 -2128.94 -1540.331_ 173.50 1785.75 111.37 1674.39 PASS 6220.801 5848.66 -578.74, -1725.26 5782.37 4962.39! -2174.82 -1575.231 _ 174.63 1831.80 111.72 1720.071 PASS 6320.80t 5948.60 -579.95 -1728.24 5861.04 5025.17 2212.37' -1604.17 175.65 1879.61 111.36 1768.25 PASS 6332.20 5960.00 -579.96 -1728.27 5867.75 5030.52 -2215.59 -1606.64 175.75 1885.21 111.25,, 1773.96 PASS 6420.801- 6048.60 -579.96 -1728.27I._ 5919.63 5071.78 -2240.74 -1625.52 176.46 1929.49 110.37'- 1819.12 PASS 6520.801- 6148.60 -579.96 -1728.27, 5998.39 5134.36 -2279.50 -1653.53 177.48 1980.58 109.901 1870.68 PASS 6620.801- 6248.60 -579.96 -1728.27 6076.63, 5196.83 -2317.86, -1680.87 178.44 2031.93 109.47 1922.47 PASS 6720.801 6348.60 -579.96 -1728.27 6145.49 5251.51 -2351.890-1705.22 179.26 2084.20 108.84 1975.36 PASS 6820.801- 6448.60 -579.96 -1728.27 6238.3715325.31 -2397.651_ -1738.18 180.31 2136.79 108.78 2028.01 PASS 6920.801 6548.60 -579.96 -1728.27 6321.74 5391.82 -2438.501 -1767.48 181.21 2189.49 108.53 2080.96 PASS 7020.801 6648.60 -579.96 -1728.27 6421.19 _5471.52 -2486.891 -1802.061 182.22 2242.18 108.65 2133.52 PASS 7120.801- 6748.60 -579.96 -1728.27 6478.69` 5517.54 -2514.851' 1822.24;- 182.78 2295.24 107.93 2187.31 PASS 7220.801 6848.60 -579.96 -1728.27 6545.43 5570.43 -2547.68 -1846.29 , ;183.43 2349.38 107.42 2241.96 PASS 7320.80t 6948.60 -579.96 -1728.27 6627.80 5635.69 -2588.16', -1876.09 184.21 2403.84 107.26 2296.58 PASS 1 7420.801 7048.60 -579.96 -1728.27 6697.40 5690.82 -2622.531-1901.05 184.84 2458.76 106.88 2351.88 PASS 7520.801- 7148.60 -579.96 -1728.27 6783.23 5758.87 -2665.11 i- -1931.43 185.57 2514.05 106.86 2407.19 PASS 7620.801- 7248.60 -579.96 -1728.27 6889.16 5843.35 -2717.211- -1968.44 186.41 2569.10 107.24 2461.85 PASS 7720.801 7348.60 -579.96 -1728.27 6996.91 5929.95 -2769.25 -, -2005.89 187.23 2623.48 107.66 2515.82 PASS 7820.801 7448.60 -579.96 -1728.27 7099.72 _ 6013.15 -2818.15 -2041.34 187.96 2677.32 107.99 2569.34 PASS 7920.801- 7548.60 -579.96 -1728.27 7208.371 6101.66 -2869.21 -2078.26 188.69 2730.71 108.42 2622.29 PASS 8020.801 7648.60 -579.96 -1728.27 8838.991 7626.99 -3269.47 -2355.83 193.13 2761.85 120.28 2641.56 PASS 8120.801 7748.60 -579.96 -1728.27 8943.41 -7731.41 -3270.19 -2355.97 193.13 2762.54 120.47 2642.07 PASS 8220.801, 784.60,,. -579.96;, -1728.27 „,__904,6,..511S7834.54 -3270.76; -2356.08, 193.13, 2763.11 120.67,. 2642,44 PASS Ea ce0 Clearance Report FA. NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 17 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 ;Field North Fork Wellbore NFU#24-26 Wellplan (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 IRI IftI Iftl Iftl IN IftI Bearing Clear Dist MASD Sep Status 11 Iftl Iftl Iftl 8320.80t 7948.60 -579.96 -1728.27 9149.17 7937.16 -3271.23' -2356.12 193.13r 2763.56 120.86 2642.70 PASS 8420.80t 8048.60 -579.96 -1728.27 9253.22 8041.21 -3271.66 -2355.98 193.13 2763.93 121.05 2642.88 PASS 8520.80t 8148.60 -579.96 -1728.27 9358.01 8146.01 -3271.90 -2355.66 193.12 2764.09 121.22 2642.86 PASS 8620.80t 8248.60 -579.96 -1728.27 9463.17 8251.16 -3272.02' -2355.22 193.11 2764.11 121.39 2642.72 PASS 8720.80f 8348.60 -579.96 -1728.27 9569.09 8357.08 -3271.96 -2354.54 193.10 2763.90 121.56 2642.35 PASS 8820.80t 8448.60 -579.96 -1728.27 9675.62 8463.61 -3271.71 -2353.63 193.08 2763.48 121.73 2641.75 PASS 8920.80t 8548.60 -579.96 -1728.27 9785.26 8573.24 -3271.17 -2352.49 193.06 2762.77 121.90 2640.88 PASS 9020.80t 8648.60, -579.96 -1728.27 9891.51 8679.48 -3270.29 -2351.13 193.04 2761.67 122.08 2639.59 PASS 9120.801 8748.60' -579.96 -1728.27 9967.491 8755.46 -3269.94 -2350.36 193.02) 2760.99 122.35 2638.64 PASS 9220.80t 8848.60 -579.96 -1728.27 10059.42 8847.38 -3270.02 -2349.73 193.012760.92 122.57 2638.34 PASS 9320.801 8948.60 -579.96 -1728.27 10144.28 8932.24 -3270.40 -2349.21 193.00 2761.21 122.83' 2638.38 PASS 9420.80t 9048.60 -579.96 -1728.27 10231.74 9019.69' -3271.22 -2348.90 192.99 2762.05 123.09 2638.96 PASS 9520.80t 9148.60 -579.96 -1728.27, 10323.93 9111.88 -3272.31 -2349.16 192.99 2763.26 123.36 2639.90 PASS 9620.80t 9248.60 -579.96 -1728.27 10424.73 9212.67 -3273.56 -2349.83 192.99 2764 62 123.60 2641.02 PASS 9720.80f 9348.60 -579. -1728.27 10541.36 9329.29 -3274.68 -2350.44 193.00 2765.68'723.83 2641.84;, 9752.20 9380.00 -579.96, -1728.27 10578.09 9366.02 -3274.86 -2350.61 193.00. 2765.86 123.91 2641.96 PASS 9820.80t 9448.60 -579.96 -1728.27 10655.50 9443.43 -3275.05 -2350.89 193.01 2766.08 124.07 2642.01 PASS 9920.80t 9548.60 -579.96 -1728.27 10700.00 9487.93 -3275.11 -2351.01 193.01 2766.82 124.42 2642.401 PASS J 10000.20 9628.00 -579.96 -1728.27 10700.00 9487.93 -3275.11 -2351.01 193.01 2769.70 124.69 2645.02 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 - €a cel3 Clearance Report MR Ver#3 Cook Inlet Energy NFU#24-26 Closest Apprroachoach BIKER Page 18 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION ;Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 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 Iftl Iftl Iftl [ft] Iftl Ifti 1 [ft] [ft] Iftl 10.75in Casing Surface 20.55 2992.00 2971.45 20.551 2739.19 -36.90 18.85 -266.26 -186.57 lin Casing Production 20.55 10673.00 10652.45 20.55 9460.68 -36.90 -18.85 -1016.69 -725.99 WELLPATH 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] [ft] _ 20.55 2945.00 NaviTrak(MagCorr) I 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 l(See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 20.55ft Ea oea Clearance Report FA. NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 19 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION !Operator Cook Inlet Energy Slot North Fork#24-26 _ Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan 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 IftI Iftl Iftl Iftl IftI IftI Iftl Iftl Bearing Clear Dist MASD Sep Status 1°1 Iftl Iftl IftI 20.80 20.80 0.00 0.00 15.18 20.78 0.60 -179.32 270.19 179.32 12.29 167.03 PASS 120.80l, _ 120.80 0.00 0.00 115.04 120.64 0.44 -179.37 270.14 179.37 12.93 166.44 PASS 220.80t 220.80 0.00 0.00 214.83 220.43 0.18 -179.51 270.06 179.51 12.97 166.54 PASS 300.25 300.25 0.00 0.00 293.99} 299.59 -0.26 -179.74 269.92 179.74 13.02 166.72 PASS 320.804 320.80 0.07 0.00 314.54T' 320.14 -0.43 -179.81 269.84 179.81 13.03 166.78 PASS 420.80t 420.76 2.53 -0.09 414.53 420.12 -1.29 -180.15 268.78 180.10 13.11 166.99 PASS 520.80t 520.58 8.48 -0.30 514.01 519.60 -2.33 -180.57 266.57 180.60 13.21 167.39 PASS 620.80t 620.13 17.90 -0.63 613.62 619.20 -3.52 -181.00 263.23 181.64 13.35 168.29 PASS 700.25 698.95 27.86 -0.97 692.59 698.16 -4.48 -181.24, 259.83 183.14 13.50 169.64 PASS ; 720.801 , 719.30 30.72 -1.07 712.86 718.43 -4.73 -181.2.E ;258.87 183.66 13.54 170.12 PASS 820.80t 818.33_ 44.63 -1.56 811.07 816.63 -6.30 -181.58 254.20 187.10 13.78 173.31 PASS 900.25 897.01 55.68` -1.94 888.81 894.34 -8.03 -181.97 250.51 190.98 14.00 176.98 PASS 920.801- 917.36 58.471 -2.13. 908.94 914.47 -8.54 -182.09 249.58 192.06 14.06 177.99 PASS 1020.801- 1016.61 70.18 -5.57 1007.33 1012.81 -11.33 -182.78 245.30 195.10 14.451 180.64 PASS 1 1120.801- .94 78.73 -13.1 1106.68 1112.12 -14.32 -183.44 241.34 194.06 15.11"r X8.95 PASS 1220.80t 1215.08_ 84.10 -24.97 1205.27 1210.66 -17.27 -184.17 237.51 188.79 15.82 172.97 PASS 1111 1320.80t 1313.77 86.29 -40.87 1303.63 1308.97 -20.34 -185.07 233.52 179.40 16.56 162.84 PASS 1420.801-1_ 1411.74r 85.28 -60.86 1401.93 1407.21 -23.47 -185.95 229.00 165.82 17.29 148.53 PASS 1520 801- 1508.71[ 81.08 -84.87 1498.67 1503.90 -26.61 -186.95 223.47 148.46 18.02 130.44 PASS 1620.80 '`1604.42 73.69 -112.84 1594.65 1599.82 -29.87 -188.18 216.03 128.14 18.75 109.40 PASS 1720.80t 1698.61 63.15 -144.70 1689.45 1694.56 -33.17 -189.54 204.96 106.32 19.42 86.89 PASS ' 1820.801; 1791.02 49.47 -180.36 1782.77 1787.80 -36.45 -191.01 187.07 86.64 19.80 66.84 PASS 1822.49 _ 1792.56 49.22 -180.99 1784.33 1789.36 -36.51 -191.04 186.68 86.37 19.81 66.56 PASS 1914.831- 1876.96 35.10 -215.70 1869.84 1874.81 -39.49 -192.46 162.70 78.16 19.33 58.83 PASS 1 1919.91111 1881.60 34.33 -217.61 1874.75 1879.71 -39.66 -192.54 161.29;-a 78.14 19.29 58.86 PASS 1920.801:- 1882.42 34.19 -217.94, 1875.38 1880.34 -39.68 -192.55 161.03 78.14 19.28 58.87 PASS 2020.80t 1973.82 18.91 -255.531 1968.02 1972.92 -42.75 -194.18 135.14 86.98 18.45 68.53 PASS 2120.80t1 2065.22 3.62 -293.11 2060.59 2065.42 -45.67 -195.83 116.87 109.06 18.21 90.84 PASS 2220.80t1 2156.62 -11.66 -330.70 2153.10 2157.88 -48.54 -197.51 105.48 138.21 18.43 119.78 PASS 2320.80 2248.01 -26.94 -368.29 2245.24 2249.97 -51.18 -199.07 98.15 170.95 18.79 152.16 PASS Fa aeB Clearance Report FA. Cook Inlet Ener NFU#24-26 Ver BAKER Energy Closest Approachh Page 20 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION ,Operator Cook Inlet Energy ;Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field 1North Fork Wellbore NFU#24-26 Wellplan 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 [ft] [ft] [ft] [ft] [ft] [ft] IftI IN Bearing Clear Dist MASD Sep Status PI IN [f] [ft] 2420.801 F2339.41 -42.23 -405.87 2336.82 2341.50 -53.57 -200.31 93.16 205.89 19.18 186.70 PASS 2520.801 2430.81 -57.51 -443.46 2428.53 2433.18 -55.88 -201.22 89.61 242.2& 19.59 222.67 PASS 2620.80t 2522.21 -72.80 -481.04 2520.88 2525.50 -58.08 -202.20 86.98 279.25 19.08 260.16 PASS 2720.80t 2613.61 -88.08 -518.63 2612.48 2617.08 -60.18 -203.05 84.95 316.82 20.40 296.42 PASS 7705.01 -103.36 -556.22 2704.60 2709.16 -62.26 -203.89 83.35 354.74 20.82 333.92 PASS 2920.80t 2796.41 -118.65 -593.80 2796.87 2801.40 -64.48 -204.74 82.07 392.85 20.81 372.03 PASS 3020.80t 2887.80 -133.93 -631.39 2890.10 2894.61 -66.50 -205.77 81.00 430.98 20.90 410.08 PASS 3120.80t 2979.20 -149.21 -668.97 2982.22 2986.70 -68.52 -206.94 80.09 469.09 21.02 448.07 PASS 3220.80t 3070.60 -164.50 -706.56 3074.65 3079.09 -70.63 -208.08 79.34 507.31 21.18 486.13 PASS I e.162.00 -179.78 -744.14 3167.80 3172.22 -72.54 -209.37 78.66 545.52, 21.36 524.16 PASS -195.06 -781.73[ 3260.43 3264.82F 3420.80t 3253.40I -74.35 -210.86 78.06 583.60 21.58 562.02 PASS 3520.80t 3344.80 -210.35 -819.32 3352.07 3356.43 -76.11 -212.25 77.53 621.84 21.82 600.02 PASS 3620.80t 3436.20 -225.63 -856.90 3444.19 3448.52 -77.71, -213.67 77.05 660.14! 22.09! 638.06 PASS 3720.80t7 3527.60 -240.92 -894.49 3536.04 3540.35 -79.35 -215.02 76.62 698.53 22.38 676.15, PASS 3820.801'' 3618.99 -256.20 -932.07 3628.14r 3632.43 -80.83 -216.39 76.23 736.98 22.70 714.28 SASS [ 3920.80t 3710.39 -271.48 -969.66 3720.54 3724.81 -82.28 -217.78 75.88 775.46 23.05_ 752.41 PASS 4020.80t 3801.79 -286.77 -1007.24 3812.67 3816.91 -83.75 -219.18 75.55 813 .93 23.411 790.52 PASS 4120.80t 3893.19 -302.05 -1044.83 3906.21 3910.42 -85.45 -220.67 75.28 852.32 23.81 r 828.51 PASS 4220.80t 3984.59 -317.33 -1082.42 3996.35 4000.54 -87.14 -221.99 75.02 890.83 24.22 866.62 PASS �.,__4320.80t4075.99 -332.62 -1120.00 4087.70 4091.87 -88.93 -223.13 74.80 929.52 24.69 904.88 PASS 4420.80t 4167.39 -347.90 -1157.59 4179.77 4183.91 -90.93 -224.30 74.61 968.16 25.10 943.06 PASS 4520.80t, _4258.78 -363.181 -1195.17 4264.77 4268.89 -92.84 -224.91 74.43 1007.27 25.54 981.73, PASS 4620.80t 4350.18 -378.47 -1232.76 4361.56 4365.64_ -95.17 -225.55 74.29 1046.41 26.05 1020.36 PASS I 4720.80t 4441.58 -393.75 -1270.35 4450.79 4454.85 -97.25 -226.20 74.15 1085.51 26.55 1058.96 PASS 4820.801 114532.98 -409.04 -1307.93 4542.16 4546. -99.22 -226.78 74.01 1124.74 27.07 1097.68 PASS 4920.80t 4624.31 -424.32 -1345.52 4633.08 4637.09 -101.22 -227.28 73.88 1164.05 27.60 1136.45 PASS 5020.801.1 47158 -439.60 -1383.10 4726.24 4730.231- -103.45 -227.74 73.78 1203.35 28.16 1175.20' PASS 5120.80i-74807.18 -454.89 -1420.69 4816.55 4820.51 -105.60 -228.19 73.68 1242.68 28.72 1213.96 PASS 5220.801- 4898.58 -470.17 -1458.27 4910.53 4914.46 -107.65 -228.75 73.57 1281.96 29.30 1252.65 PASS l 5320.801 4989.97 -485.45 -1495.86 5002.39 5006.29 -109.87 -229.19 73.48 1321.29 29.89 1291.39 PASS Ea ceb Clearance Report FA. NFU#24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 21 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION 'Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan 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 [ft] [ft[ IN IftI IN [ft] [ft] IN Bearing Clear Dist MASD Sep Status 1°1 IftI IftI IN 5420.80t 5081.37 -500.74 -1533.45 5098.56 5102.43 -112.341 -230.05 73.41 1360.19 30.51.. 1329.68 PASS 5520.80t 5172.77 -516.02 -1571.03 5187.49 5191.33} -114.65 -230.66 73.33 1399.30 31.11''_ 1368.19 PASS 5534.27 5185.09 -518.08 -1576.10 5199.68 5203.51 -114.96 -230.73 73.32 1404.58 31.19: 1373.39 PASS 5620.80t 5264.94 -530.63 -1606.95 5285.81 5289.62 -117.13 -231.40 73.27 1436.56 31.77 1404.79 PASS -' '5720.80t 5358.99 -543.41 -1638.39 5383.52 5387.28 -119.52 -232.59 73.22 1468.59 32.501436.09 PASS 5820.80t 5454.69 -554.32 -1665.22 5481.54 5485.27 -121.81 -233.92 73.19 1495.53 _33.241462.29 PASS 5920.80t 5551.78 -563.33 -1687.38 5577.37 5581.07 -124.02 -235.271_ 73.17 1517.40 33.95'_ 1483.45 PASS 6020.80t 5649.98 -570.42 -1704.80 5681.92 5685.57 -126.70 -236.74 73.18 1534.07 34.68 _ 1499.39 PASS 6120.80t 5749.03 -575.56 -1717.44 5775.11 5778.72 -129.34 -238.02 73.22 1545.54 35.32 1510.21 PASS 6220.80t 5848.66. -578.74 -1725.26; 5883.32 5886.87 -132.59, -239.53 73.29 1551.74 36.02 1515.72 PASS 6320.80t; 5948.60 -579.95 -1728.24 5979.94 5983.43 -135.47 -241.02_ 73.36 1552.60 36.63 1515.98 PASS 6332.20 5960.00 -579.96 -1728.27 5991.33 5994.81 -135.81 -241.19 73.37 1552.38 36.69 1515.691 PASS 6420.80t 6048.60 -579.96 -1728.27 6081.29 6084.73 -138.41 -242.52_ 73.45 1550.39 37.10' 1513.281 PASS 6520.80t 6148.60 -579.96 -1728.27 6185.40 6188.78 -141.32 -244.44 73.53 1547.83 37.59 1510.24 PASS '. 6620.80t 6248.60 -579.96 -1728.27 6280.74 6284.07 -144.02" -246.04E `;73.61 1545.41 38.04, 1507.37 PASS 6720.80t 6348.60 -579.96 -1728.27 6378.96 6382.23 -146.95 -247.48 73.70 1543.17 38.51 1504.66 PASS 6820.80t 6448.60 -579.96 -1728.27 6476.39 6479.62 -149.81 -248.77 73.79 1541.07 38.98 1502.09 PASS 6920.80t 6548.60 -579.96 -1728.27 6577.19 6580.35 -153.25 -249.84 73.90 1539.10 39.48 1499.62 PASS 7020.80t 6648.60 -579.96 -1728.27 6675.98 6679.07 -156.80 -251.02 74.02 1536.96 39.98 1496.99 PASS 7120.801 6748.60 -579.96 -1728.27 6775.94 6778.95 -160.57 -251.841r 74.14 1535.12 40.49 1494.63 PASS 7220.80t 6848.60 -579.96 -1728.27 6873.49 6876.41 -164.75 -252.857 74.28 1532.98 41.00 1491.98 PASS 7320.80t 6948.60 -579.96 -1728.27 6976.99 6979.81 -169.10 -253.64 74.43 1531.12 41.54 1489.57 PASS 7420.80t 7048.60 -579.96 -1728.27 7076.76 7079.48 -173.36 -254.61; 74.58 1529.04 42.08 1486.96 PASS 7520.80t 7148.60 -579.96 -1728.27 7175.84 7178.46 -177.76 -255.431 74.73 1527.06 42.61 1484.45 PASS 7620.80t 7248.60 -579.96 -1728.27 7275.34 7277.85 -182.42 -256.1474.89 1525.13 43.16 1481.96 PASS 111 7720.80t 7348.60 -579.96 -1728.27 7375.18 7377.57 -187.32 -256.81 75.06 1523.22 43.72 1479.50 PASS 7820.80t 7448.60 -579.96 -1728.27 7474.22 7476.48 -192.31 -257.39 75.24 1521.36 44.28 1477.08 PASS 7920.80t 7548.60 -579.96 -1728.27 7572.91 7575.05 -197.17 -258.00 75.41 1519.52 44.84 1474.67 PASS 8020.80t 7648.60 -579.96 -1728.27 7669.88 7671.91 -201.84 -258.47 75.57 1517.84 45.40 1472.44 PASS 8120.80t 7748.60 -579.96 -1728.27 7764.19 7766.12 -206.25 -258.59 75.73 1516.55 45.94 1470.61 PASS Ea cel3 Clearance Report FA` Cook Inlet Energy NFU #24-26 Ver#3 BAKER Closest Approach Page 22 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan ;Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#34-26 Offset Wellpath: PGMS GyroData<100-2500'>MWD(HAL)<2550-9021'> 1 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 Iftl IftI Iftl Iftl IRI Ift1 IN Bearing Clear Dist MASD Sep Status 101 IftI Iftl Iftl 8220.80t 7848.60_ -579.96 -1728.27 7861.77 7863.59 -210.76 -258.54 75.90 1515.46 46.51 1468.96 PASS 8320.80t 7948.60 -579.96 -1728.27 7954.42 7956.14 -214.98 -258.19 76.06 1514.73 47.05 1467.68 PASS 8420.80t 8048.60[ -579.96 -1728.27 8053.53 8055.15 -219.47 -257.56 76.23 1514.26 47.64 1466.62 PASS 8520.80t 8148.601 -579.96 -1728.27 8148.47 8149.99 -223.78 -256.76 76.39 1514.00 48.21 1465.79 PASS 8620.80f 8248.641-579.96 -1728.27 8239.45 8240.86 -227.94 -255.46 76.56 1514.32 48.76 1465.56 PASS 8720.80t 8348.60F-579.96 -1728.27 8336.41 8337.70 -232.53 -253.82 76.74 1514.87 49.36 1465.51 PASS 8820.80t 8448.601- -579.96 -1728.27 8429.76 8430.93 -237.03 -251.85 76.92 1515.83 49.94 1465.89 PASS 8920.80t 8548.60 579.961 -1728.27 8524.72 8525.74 -241.65 -249.47 77.11 1517.17 50.53 1466.64 PASS 9020.80t 8648.60 -579.96` -1728.27! 8619.461 8620.32 -246.40 -246.78 77.31 1518.84 51.14 1467.70 PASS 9120.80f 8748.60 -579.96 -1728.27 8711.11 8711.79 -251.16 -243.75 77.51 1520.95 51.731..1469.21 PASS 9220.80t 8848.601 -579.96, -1728.27( 8801.80 8802.31 -255.49 -240.23 77.70 1523.71 52.321 1471.39 PASS 9320.80t 8948.60` -579.96 -1728.271 8897.41 8897.73 -259.87 -236.13 77.89 1526.94 52.931 1474.00 PASS 9420.80t 9048.601' -579.96, -1728.27 8997.40 8997.52 -264.671 -231.69 78.10 1530.29 53.581 1476.70 PASS 9520.80t 9148.60 -579.96 -1728.27 9021.00 9021.06 -265.85 -230.641 78.15 1535.53 53.76r 1481.77 PASS 9620.80t 9248.6Q 579 --1728.27 9021.00 9021.06 -265.85 -230.641 '78.15 1547.04 53.781493.26 PASS 9720.80t 9348.60 -579.96 -1728.27 9021.00 9021.06 -265.85 -230.64 78.15 1564.88 53.81 1511.07 PASS j 9752.20 9380.00 -579.96( -1728.27 9021.00 9021.06 -265.85 -230.64 78.15 1571.75 53.82 1517.93 PASS 9820.80f 9448.60 -579.96 -1728.27 9021.00 9021.06 -265.85 -230.64 78.15 1588.82 53.86 1534.97 PASS 992080f 9548.60 -579.96 -1728.27 9021.00 9021.06 -265.85 -230.64 78.15 1618.60 53.92 1564.68 PASS ;, 100004.0„.1„,9N141111079.96, -1728.27 9021.00 9021.06 -265.85 -230.64 78.15 1646.19 53.99 1592.21 PASS r 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 ea ceO Clearance Report FA. NFU #24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 23 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator'Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 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 Iftl Iftl 0.00 2500.00 Gyrodata standard-Continuous gyro GyroData PGMS<100-2500'> NFU#34-26 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 WELLPATHDATUMon page 1 of this report) 'Ellipse Start MD 0.00ft — _— cea Clearance Report VAR Cook Inlet Ener NFU#24-26 BAKER Energy Closest Apprroachoach Page 24 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION [Operator 1Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#42-35 Offset Wellpath:NFU 42-35 Vers#7 Facility:North Fork Unit(NAD27) Slot:North Fork#42-35 Well:NFU#42-35 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] MI Bearing Clear Dist MASD Sep Status 1°1 [ft] Iftl Iftl 20.80 20.80 0.00 0.00 21.801_ 20.80 -61.02 89.14 124.39 108.021 12.961 95.06, PASS 119.00t 119.00 0.00 0.00 120.00._ 119.00 -61.02 89.14 124.39 108.02, 13.20 94.82 PASS 120.80t 120.80 0.00 0.00 121.80 _ 120.80 -61.02 89.14 124.39 108.02 12.93 95.09 PASS 220.80t 220.80 0.00 0.00 221.80. 220.80 -61.02 89.14 124.39 108.02 13.00 95.02 PASS 300.25 300.25 0.00 0.00 301.251: 300.25 -61.02 89.14 124.39 108.02 13.08 94.94 PASS 320.80t 320.80 0.07 0.00 321.80' 320.80 -61.02 89.14 124.42 108.06 13.10 94.96 PASS 420.80t 420.76 2.53 -0.09 421.761 420.76 -61.02 89.14 125.46 109.54 13.28 96.27 PASS 520.801- 520.58 8.48 -0.30 520.70 519.70 -61.13 89.15 127.89 113.35 13.56; 99.78; PASS 620.801- 620.13 17.90 -0.63 615.51 614.44 -64.48 89.62 132.39 122.32 14.00' 108.32 PASS 700.25 698.95 27.86 -0.97 689.34 688.03 -70.30 °90.43; 137.04 134.57 14.57 120.00 PASS.. 720.801- 719.30 30.72 -1.07 708.171 706.76 -72.24 90.70 138.29 138.49 14.72 123.77 PASS 820.801 818.33 44.63 -1.56 798.421 796.21 -84.06 92.34 143.88 160.83 15.42 145.41 PASS 900.25 897.01 55.68 -1.94 868.3511 865.07 -96.09 94.01 147.70 182.38 15.95 166.42 PASS ' 920.801- 917.36 58.47 -2.13 886.181_ 882.55 -99.56 94.49 148.56 188.47 16.09 172.38 PASS 1020.801- 1016.61 70.18 -5.57 971.72'p" 965.94 -118.43 97.11 151.43 220.64 16.71 203.93 PASS ` 1120.801- 1115.94 78.73 -13.19 1055.14 1046.35 -140.37 100.16 152.64 256.31 17.31 239.00 PASS 1220.801- 1215.08 84.10 -24.97 1136.27 1123.57 -165.03 103.59 152.71 294.90 17.86 277.04 PASS 1320.801 1313.77 86.29 -40.87 1215.02 1197.44 -192.05 107.34 151.96 336.12 18.39 317.73 PASS 1420.801- 1411.74 85.28 -60.86 1291.31 1267.86 -221.08 111.38 150.66 379.76 18.91 360.85 PASS 1520.801- 1508.71 81.08 -84.87 1365.09 1334.81 -251.78 115.65 148.94 425.73 19.49 406.24 PASS 1620.801- 1604.42 73.69 -112.84 1436.35 1398.29 -283.85 120.10 146.92 473.91 20.13 453.78 PASS 1720.801- 1698.61 63.15 -144.70 1505.10 1458.35 _ -316.99 124.71 144.67 524.23 20.86 503.37 PASS 1820.801- 1791.02 49.47 -180.36 1571.37 1515.05 -350.93 129.42 142.27 576.58 21.67 554.91 PASS 1822.49 1792.56 49.22 -180.99 1572.46 1515.98 -351.51 129.50 142.23 577.48 21.69 555.80 PASS 1920.801- 1882.42 34.19 -217.94 1635.31 1568.62 -385.52 134.23 140.00 631.39 22.65 608.73 PASS 2020.801- 1973.82 18.91 -255.53 1699.25 1620.99 -421.84 _139.27 138.15 688.92 23.76 665.17 PASS 2120.801- 2065.22 3.62 -293.11 1779.28 1685.98 -468.11 145.70 137.07 747.60 25.25 722.35 PASS 2220.801- 2156.62 -11.66 -330.70 1859.32 1750.97 -514.37 152.13 136.16 806.47 26.85 779.62 PASS 2320.801- 2248.01 -26.94 -368.29 1939.35 1815.96 -560.64 158.561 135.37 865.49 28.54 836.95 PASS 2420.801- 2339.41 -42.23 -405.87 2019.38 1880.95 -606.90 164.9j, 134.69 924.63 30.32 894.30 PASS Ek ab Clearance Report FAR NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 25 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION !Operator Cook Inlet Energy Slot 'North Fork#24-26 'Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 1 1 CLEARANCE DATA-Offset Wellbore:NFU#42-35 Offset Wellpath: NFU 42-35 Vers#7 Facility:North Fork Unit(NAD27) Slot:North Fork#42-35 Well:NFU#42-35 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] MI [ft] [ft] Ifti MI Ift] [ft] Bearing Clear Dist MASD Sep Status 11 IRI [ft] [ftI 2520.80t1 2430.81 -57.51 -443.46 2099.42 1945.94 -653.17; 171.421 134.09 983.86` 32.17 951.69 PASS 2620.80$ 2522.21 -72.80 -481.04 2179.45r 2010.92 -699.44 177.85 133.56 1043.18 34.08 1009.10 PASS 2720.80$ 2613.61 -88.08 -518.63 2259.48 2075.91 -745.70 184.28 133.09 1102.57 36.03 1066.54 PASS 2820.80.1 2705.01 -103.36 -556.22 2339.52 2140.90 -791.97 190.70 132.67 1162.02 38.02 1123.99 PASS 2920.801 2796.41 -118.65 -593.80 2419.55 2205.89 -838.23 197.13 132.30 1221.51 39.76 1181.75 PASS 3020.80t 2887.80 -133.93 -631.39 2499.58 2270.88 -884.50 203.56 131.95 1281.05 41.55 1239.50 PASS 3120.801 2979.20 -149.21 -668.97 2579.62 2335.87 -930.76 209.99 131.64 1340.63 43.39 1297.23 PASS 3220.80t 3070.60 -164.50 -706.56 2659.651 2400.86 -977.03 216.42 131.36 1400.23 45.28 1354.96 PASS 3320.801 3162.00 -179.78 -744.14 2739.68 2465.84 -1023.30E 222.851 131.10 1459.87 47.20 1412.671 PASS t = --- 3520.80 _229.28 130.86 1519.53 49.16 1470.38 PASS 3420.80 3253.E 20.35 -819.32 2899.75 2595.82 1065.83 ----- - 3520.80t 3344.80 235.70 130.64 1579.22 51.14 1528.08 PASS 3620.80$ 3436.20 -225.63 856.90 2979.78 2660.81 -1162.091 242.13 130.43 1638.92 53.15 1585.77 PASS 3720.80$ 3527.60 -240.92 -894.49 3059.82 2725.80 -1208.36' 248.56 130.241 1698.64 55.10 1643.54{PASS 3820.80$ 3618.99 -256.20 -932.07 3139.85 2790.79 -1254.62 254.99 130.07 1758.38 56.83 1701.55 PASS l 3920.80t 3710.39 -271.48 -969.66 3219.88 2855.78 -1300.89 261.42 129.90 1818.13 58.57 1759.57 PASS 4020.801 3801.79 -286.77 -1007.24 3299.92 2920.76 -1347.16 267.85 129.75 1877.90 60.34 1817.55 PASS 4120.801- 3893.19 -302.05 -1044.83 3379.95 2985.75 -1393.42 274.28 129.60 1937.67 62.15 1875.52 PASS 4220.801- 3984.59 -317.33 -1082.42 3459.99 3050.74 -1439.69 280.71 129.47 1997.46 63.99 1933.47 PASS 4320.801 4075.99 -332.62 -1120.00 3540.02 3115.73 -1485.95 287.13 129.34 2057.26 65.86 1991.40 PASS 4420.80t 4167.39 -347.90 -1157.59 3620.05 3180.72 -1532.22 293.56 129.22 2117.06 67.75 2049.32 PASS 4520.80t 4258.78 -363.18 -1195.17 3700.09 3245.71 -1578.48 299.99 129.11 2176.88 69.66 2107.21 PASS r 4620.801 4350.18 -378.47 -1232.76 3780.12 3310.69 -1624.75 306.42 129.00 2236.70 71.60 2165.10 PASS 4720.80t 4441.58 -393.75 -1270.35 3860.15 3375.68 -1671.01 312.85 128.90 2296.53 73.56 2222.97 PASS 4820.80$ 4532.98 -409.04 -1307.93 3940.19 3440.67 -1717.28 319.28 128.80 2356.36 75.54 2280.83 PASS 4920.80t 4624.38 -424.32 -1345.52 4020.22 3505.66 -1763.55 325.71 128.71 2416.21 77.53 2338.68 PASS 5020.80$ 4715.78 -439.60 -1383.10 4100.25 3570.65 -1809.81 332.13 128.62 2476.05 79.54 2396.51 PASS 5120.80$ 4807.18 -454.89 -1420.69 4180.29 3635.64 -1856.08 338.56 128.54 2535.90 81.56 2454.34 PASS 5220.801 4898.58 -470.17 -1458.27 4260.32 3700.63 -1902.34 344.99 128.46 2595.76 83.60 2512.16 PASS 5320.80t 4989.97 -485.45 -1495.86 4340.35 3765.61 -1948.61 351.42 128.38 2655.62 85.65 2569.97 PASS 5420.80t 5081.37 -500.74 -1533.45 4420.39 3830.60 -1994.87 357.85 128.31 2715.49 87.72 2627.77 PASS Ea ce0 Clearance Report FA` NFU #24-26 Ver#3 BAKER _ Cook Inlet Energy_ Closest Approach Page 26 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) CLEARANCE DATA-Offset Wellbore:NFU#42-35 Offset Wellpath: NFU 42-35 Vers#7 Facility:North Fork Unit(NAD27) Slot:North Fork#42-35 Well:NFU#42-35 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 [ft] IN IftI IftI IftI IftI IftI Bearing Clear Dist MASD Sep Status __ _ 1°I [ft] Iftl IftI 1 5520.801f 5172.77 -516.02 -1571.0314500.42 3895.59 -2041.14] 364.28 128.24 2775.36 89.79 2685.56 PASS 5534.27 1 5185.09 -518.08 -1576.10 4511.20 3904.35 -2047.37 365.14 128.23 2783.42 90.07 2693.35 PASS 5620.80$ 5264.94 -530.63 -1606.95 _ 4580.82 3960.88 -2087.62 370.74 128.21 2834.79 91.82 2742.97 PASS 5720.80$ 5358.99 -543.41 -1638.39, 4662.06 4026.84 -2134.58 377.26 128.29 2892.97 93.69 2799.28 PASS 5820.80$ 5454.69 -554.32 -1665.227 4743.92 4093.32 -2181.90''' 383.84 128.46 2949.75 95.40 2854.35 PASS 5920.80$ 5551.78 -563.33 -1687.38 4826.18 4160.12 -2229.46 390.44 128.73 3005.00 96.93 2908.07 PASS 6020.80$ 5649.98 -570.42 -1704.80 4908.62 4227.06 -2277.11 397.07 129.08 3058.66 98.29 2960.36 PASS 6120.80$ 5749.03 -575.56 -1717.44 4991.01 4293.96 -2324.74 403.68 129.51 3110.64 99.47 3011.17 PASS 6220.80t 5848.66 -578.74 -1725.26 5073.12 4360.64 -2372.21, 410.28 130.02 3160.90 100.45 3060.45 PASS 6320.80t, 5948.60 -579.95 -1728.24 ' 5154.734 4426.91 -2419.38 ; 416.84 130.61 3209.43 101.23 3108.20,PASS 7 4434.43 -2424.74[- 417.58 130.69 3214.85 101.30 3113.55 PASS -579.96 -1728.27 5235.941 6332.20 5960.00 -579.96 -1728.27 5163.99 6420.80t 6048.60 4492.85 -2466.33 423.36 131.24 3257.03 101.87' 3155.16 PASS 6520.801: 6148.60 579.96 1728.27_ 5317.14 4558.78 2513.27; 429.88 131.86 3304.97 102.501 3202.471PASS 6620.80$ 6248.60 -579.96 -1728.271 5398.34;_ 4624.72 -2560.21 436.40 132.45 3353.24 103.12 3250.12 PASS 6720.80$ 6348.60 -579.96 -1728.27*'7182.3365.93 -3128.62 '518.88 138.60 3398.85 123.79 3275.06 P _ 6820.80$ 6448.60 -579.96 -1728.271 7282.29 6365.86 -3131.19 519.64 138.62 3401.28 123.99 3277.30 PASS 6920.80$ 6548.60 -579.96 -1728.271 7382.25 6465.79 -3133.77 520.39 138.64 3403.72 124.18 3279.53 PASS 7020.80$ 6648.60 -579.96 -1728.27 7482.22 6565.71 -3136.341 521.15 138.66 3406.15 124.39 3281.76 PASS 7120.80$ 6748.60 -579.96 -1728.27 7582.18 6665.64 -3138.911 521.91 138.67 3408.58 124.59 3283.99 PASS 7220.80t 6848.60 -579.96 -1728.27 7682.15 6765.57 -3141.49II 522.66 138.69 3411.02 124.80 3286.21 PASS 7320.80$ 6948.60 -579.96 -1728.27 7782.11 6865.50 -3144.06; 523.42 138.71 3413.45 125.02 3288.44 PASS 7420.80$ 7048.601 -579.96 -1728.27, 7882.07 6965.43 -3146.64] 524.18 138.73 3415.89 125.23' 3290.65 PASS 7520.80$ 7148.60' -579.96 -1728.27; 7982.04 7065.35 -3149.211 524.94 138.75 3418.32 125.45 3292.87 PASS 7620.80$ 7248.60 -579.96 -1728.271 8082.00 7165.28 -3151.78' 525.69 138.77 3420.76 125.68 3295.08 PASS l 7720.80t 7348.60 -579.96 -1728.27 - 8181.97 7265.21 -3154.36 526.45 138.79 3423.19 125.91' 3297.28 PASS , 7820.80$ 7448.60 -579.96 -1728.27 8281.93 7365.14 -3156.93 527.21 138.81 3425.63 126.14 3299.49 PASS 7920.80t 7548.60 -579.96 -1728.27! 8381.89 7465.07 -3159.51 527.96 138.83 3428.07 126.38 3301.69 PASS 8020.80t 7648.60 -579.96 -1728.27 8481.86 7564.99 -3162.08 528.72 138.84 3430.50 126.62 3303.89 PASS 8120.80$ 7748.60 -579.96 -1728.27 8581.82 7664.92 -3164.65 529.48 138.86 3432.94 126.86 3306.08 PASS I 8220.80t 7848.60 -579.96 -1728.27 8681.79 7764.85 -3167.23 530.24 138.88 3435.38 127.11 3308.27 PA Ed ceB Clearance Report FA. NFU#24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 27 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION `Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 rField North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) I I CLEARANCE DATA-Offset Wellbore:NFU#42-35 Offset Wellpath: NFU 42-35 Vers#7 Facility:North Fork Unit(NAD27) Slot:North Fork#42-35 Well:NFU#42-35 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 IN Iftl Iftl Iftl Iftl Iftl Bearing Clear Dist MASD Sep Status ; 1°1 [ft] Iftl IN 8320.80$ 7948.60 -579.96 -1728.27 8781.75 7864.78 -3169.80 530.99 138.90 3437.82 127.36 3310.46 PASS 8420.80$ 8048.60 -579.96 -1728.27 8881.71 7964.71 -3172.38 531.75 138.92 3440.25 127.61 3312.64 PASS 8520.80$ 8148.60 -579.96 -1728.27 8981.68 8064.63 -3174.95 532.51 138.94 3442.69 127.87 3314.82 PASS 8620.80$ 8248.60 -579.96 -1728.27 9081.64 8164.56 -3177.52 533.26 138.96 3445.13 128.13 3317.00 PASS ,8720.801. 8348.60 -579.96 -1728.27 9181.61 8264.49 -3180.10 534.02 138.98 3447.57 128.39 3319.18 PASS 8820.801 8448.60 -579.96 -1728.27 9281.57 8364.42 -3182.67 534.78 138.99 3450.01 128.66 3321.35 PASS ' 8920.80$ 8548.60 -579.96 -1728.27 9381.53 8464.35 -3185.24 535.53 139.01 3452.45 128.93 3323.52 PASS 9020.80$ 8648.60 -579.96 -1728.27 9481.50 8564.27 -3187.82 536.29 139.03 3454.89 129.21 3325.68 PASS 9120.80$ 8748.60 -579.96 -1728.27 9581.46 8664.20 -3190.391 537.05 139.05 3457.33 129.49 3327.85 PASS 9220.80$ 8848.60 -579.96 -1728.27 9681.43 8764.13 -3192.9/ 537.81 139.07, 3459.77 129. 330.01 PASS , 9320.80t 8948.60 -579.96 -1728.27 9781.39i 8864.06 -3195.54 538.56 139.09 3462.22 130.06 3332.16 PASS 9420.80$ 9048.60 -579.96 -1728.27 9881.35 8963.99 -3198.11 539.32 139.10 3464.66 130.34 3334.32 PASS 9520.80$ 9148.60 -579.96 -1728.27 9981.32 9063.91 -3200.69 540.08 139.12 3467.10 130.64 3336.47 PASS 9620.801 9248.60 -579.96 -1728.27 10081.28 9163.84 -3203.26 540.83 139.14 3469.54 130.93' 3338.61 PASS 9720.80t 9348.60 -579.96 -1728.27 10181.25 9263.77 - 541.59 139.16 3471.99 131.23 3340.76 PASS 9752.20 9380.00 -579.96 -1728.27 10212.63 9295.14 -3206.64 541.83 139.17 3472.75 131.32 3341.43 PASS 9820.80$ 9448.60 -579.96 -1728.27 10281.21 9363.70 -3208.41 542.35 139.18 3474.43 131.53 3342.90 PASS 9920.80$ 9548.60 -579.96 -1728.27 10381.17 9463.62 -3210.98 543.11 139.20 3476.87 131.84 3345.04 PASS 10000.20 962_8.00 -579.96 -1728.27 10460.54 9542.97 -3213.03 543.71 139.21 3478.82 132.08 3346.73 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#42-35 Offset Wellpath:NFU 42-35 Vers#7 Slot Surface Uncertainty @1 SD Horizontal 12.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft €a ced Clearance Report TA. Cook Inlet Ener NFU#24-26 Ver BAKER - - Energy Closest Approachh Page 28 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION !Operator Cook Inlet Energy (Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) HOLE& CASING SECTIONS-Offset Wellbore:NFU#42-35 Offset Wellpath:NFU 42-35 Vers#7 1 IString/Diameter Start MD End MD Interval Start TVD End TVD Start N/SStart E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] 1 [ft] [ft] [hi 16in Conductor 025 121.00 120.75 -0351 120.00 -37.201 54.34' -37.20 54.34 j 12.25in Open Hole 20.80 3089.62 3068.82 19.80 2750.00 -37.20 54.34 -392.16 103.66 9.625in Casing Surface 20.80 3089.62 3068.82 19.80 2750.00 -37.20 54.34 -392.16 103.66 18.75in Open Hole 3089.62 20.80 -3068.82 2750.00 19.80 -392.16 103.66 -37.20 54.34 17in Casing Production 3089.62 20.80 -3068.82 2750.00 19.80 -392.16 103.66 -37.20 54.34 SURVEY PROGRAM-Offset Wellbore: NFU#42-35 Offset Wellpath:NFU 42-35 Vers#7 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore Iftl Iftl 20.80 3088.39 OnTrak(MagCorr) NFU#42-35 ff 3088.39 10554.61 OnTrak(Standard) - NFU#42-35 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:NFU#42-35 Offset Wellpath:NFU 42-35 Vers#7 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 Ea ceB Clearance Report Irak NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 29 of 38 HUGHES REFERENCE WELLPATII IDENTIFICATION [operator Cook Inlet Energy Slot North Fork#24-26 1Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [Field North Fork Wellbore NFU#24-26 Wellplan 'Facility North Fork Unit(NAD27) 1 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] Iftl Ift] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status 101 [ft] [ft' [ft] 20.80t 20.80 0.00 0.00 20.26 20.36 0.58 -119.53 270.28 119.54 13.22 106.32 PASS 120.80t 120.80 0.00 0.00 118.07 118.16 -0.191 -120.79 269.91 120.81 13.24 107.58 PASS 220.80t 220.80 0.00 0.00 216.20 216.23 -2.04 -123.79 269.06 123.89 13.32 110.56 PASS 300.25 300.25 0.00 0.00 295.45 295.40 -3.81 -126.72 268.28 126.87 13.54 113.34 PASS 320.80t 320.80 0.07 0.00 315.95,,;x;,, 315.88 ,,,!„,,,,,„,,,,,-4.24 -127.50, 268.06 127.66 13.56 114.10 PASS 420.80t 420.76 2.53 -0.09 416.031 415.85 -6.99 -131.13 265.84 131.48 13.73 117.74 PASS 520.80t 520.58 8.48 -0.30 514.681 514.34 -11.39 -134.65 261.59 135.96 13.95 122.01 PASS 620.80t 620.13 17.90 -0.63 611.02 610.32 -18.49 -138.68 255.23 143.11 14.25 128.86 PASS 700.25 698.95 27.861 -0.97 686.22 685.03 -26.26 -142.43 249.06 152.09 14.55 137.54 PASS 30.72- , _, 05.1 .53 -143.47 247.41` 155.00 14.64 140.36 PASS 720.80t 719.30 -1.07' 705.18 703.83 -28.53 820.80t 818.33 44.63 -1.56 797.21 794.69 -42.06 -148.88 239.53 172.57 15.06 157.50 PASS 900.25 897.01 55.68 -1.94 869.67 865.84 -55.06 -153.27 233.80 190.09 15.41 174.68 PASS 920.80t 917.36 58.47 -2.13 888.15 883.92 -58.72 -154.36 232.41 195.00 15.49 179.51 PASS_ 1020.80f 1016.61 70.18 -5.57 976.19 969.53 -78.62 -159.26 225.93 219.03 15.95 203.08 PASS 1120.80t 1115.94 78.73 -13.19 1061.31 1051.31 -101.73 -164.02 219.89 243.91 16.74 227.17 PASS 1220.80t 1215.08 84.10 -24.97 1144.39 1130.03 -127.70 -169.31 214.27 270.06 17.48 252.58 PASS 1320.80t 1313.77 86.29 -40.87 1227.01 1207.22 -156.57 -175.15 208.94 297.26 18.18 279.08 PASS 1420.80t 1411.74 85.28 -60.86 1307.59 1281.41 -187.35 -181.61 203.89 325.42 18.79' 306.62 PASS 1520.80t 1508.71 81.08 -84.87 1386.34 1352.71 -219.97 -188.88 199.06 354.66 19.37 335.29 PASS 1620.801 1604.42 73.69 -112.84 1463.10 1420.86 254.40 -196.67 194.33 385.18 19.95 365.23 PASS 1720.80t1 1698.61 63.15 -144.70 1538.55 1486.51 -290.707 -204.69 189.62 416.89 20.62 396.27, PASS 1820.80t 1791.02 49.47 -180.36 1610.89[ 1548.04 -327.91 -212.57 184.88 449.99 21.38 428.60 PASS 1822.49 1792.56 49.22 -180.99 1612.091 1549.057 -328.54 -212.71 184.80 450.56 21.39 429.17`PASS r 1920.80t 1882.42 34.19 -217.94 1684.52 1609.17 -368.011 -221.29 180.48 486.25 22.23 464,02 PASS 2020.801 1973.82 18.91 -255.53 1757.29 1668.31 -409.38830.62 176.67 526.67 23.26 503.41 PASS 2120.80t 2065.22 3.62 -293.11 1823.45 1720.73 -448.79 -239.30 173.22 571.18 24.32 546.86 PASS 2220.801 2156.62 -11.66 -330.70 1890.51 1772.39 -490.63 -248.13 170.22 619.56 25.57 593.99 PASS 2320.80t 2248.01 -26.94 -368.29 1969.26 1832.09 -540.88 -258.70 167.96 670.18 27.25 642.93 PASS 2420.80t 2339.41 -42.23 -405.87 2051.16 1893.92 -593.43 -269.80 166.13 721.67 29.09 692.58 PASS • 52080.11 243Q.81, -57.51, -443.46, 2132.17 1954.87 -645.62 -280.88. 164.55 773.84 31.00, 742.84 PASS EO ceB Clearance Report Irak Cook Inlet Ener NFU #24-26 Ver BAKER Energy Closest Approachh Page 30 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 ;Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 ;Field North Fork Wellbore NFU#24-26 Wel!plan Facility North Fork Unit(NAD27) 1. 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 IftI IftI IN IftI IftI IftI IftI IftI Bearing Clear Dist MASD Sep Status _ 1°1 Iftl IN IftI 2620.801 2522.21 -72.80 -481.04 2216.621 2018.33 -700.19 -292.17 163.25 826.55 33.08 793.48 PASS 2720.801- 2613.61 -88.08 -518.63 2310.561 2089.52 -760.28 -304.26 162.31 878.91 35.48 843.43 PASS 2820.801- 2705.01 -103.36 -556.22 2393.27;- 2152.57812.78 -314.69 161.20 931.02 37.62 893.39 PASS 2920.801- 2796.41 -118.65 -593.80 2476.15 2215.65 -865.53 -325.12 160.21 983.52 39.54 943.98 PASS lirmj020.801 2887.80 -133.93 -631.39 2558.961' 2278.41 918.39 336.26 159.38 1036.26 41.51 994.75 PASS 3120.801- 2979.20 -149.21 -668.97 2641.61 2340.81 -971.31 -347.91 158.67 1089.26 43.54 1045.72 PASS 3220.801- 3070.60 -164.50 -706.56 2724.94 2403.65 -1024.79 -359.49 158.03 1142.54 45.62 1096.91 PASS 3320.801- 3162.00 -179.78 -744.14 2828.89 2482.20 -1091.04 -375.20 157.96 1195.26 48.29 1146.96 PASS 3420.801 3253.40 -195.06 -781.73 2909.09 2542.94 -1141.81 -388.10 157.42 1247.41 50.37 1197.04 PASS 3520.80t 3344.80 -210.35 -819.32 2990.21, 2604.16 -1193.36 401.32 156.96 1299.84 52.49 1247.35 PASS 3620.801 3436.20 -225.63 -856.90 3070.03 2664.22 -1244.32 -414.25 156.51 1352.63 54.60 1298.03 PASS 3720.801 3527.60 -240.92 -894.491 3148.661 2723.19 -1294.75 -426.96 156.08 1405.78 56.71 1349.07 PASS 3820.801. 3618.99 -256.20 -932.07r 3237.37 2789.74 -1351.67 -441.07 155.86 1459.04 58.81 1400.23 PASS 3920.801- 3710.39 -271.48 -969.66 3329.65 2859.36 -1410.52 -455.46 155.70k 1511.97 60.97 1451.00 PASS 4020.801- 3801.79 -286.77 -1007.24 3400.12^. 2912.49 -1455.53 -466.25 is 1565.10 62.62 1502.48 PAA 4120.801- 3893.19 -302.05 -1044.83 2970.81 -1505.64 -477.94 154.78 1618.88 64.46 1554.42 PASS 4220.801- 3984.59 -317.33 -1082.42 3569.71 3039.87 -1564.62 -491.42 154.65 1672.57 66.66 1605.91 PASS 4320.801- 4075.99 -332.62 -1120.00 3664.151 3111.40 -1624.81 -504.90 154.55 1725.85 68.97 1656.88 PASS 4420.801- 4167.39 -347.90 -1157.59 3758.831 3183.59 -1684.62 -518.10 154.43 1778.66 71.30 1707.36 PASS 4520.801- 4258.78 -363.18 -1195.17 3840.97W 3246.33 -1736.36 -529.66 154.14 1831.28 73.38 1757.90 PASS 4620.801. 4350.18 -378.47 -1232.76 3935.671 3318.21 -1796.23 -544.37 154.10 1883.85 75.77 1808.08 PASS 4720.801- 4441.58 -393.75 -1270.35 4019.991 3382.31 -1849.33 -557.87 153.92 1936.08 77.94 1858.14 PASS 4820.801. 4532.98 -409.04 -1307.93 4100.52` 3442.96 -1900.43 -571.80 153.73 1988.54 80.03 1908.51 PASS 4920.801- 4624.38 -424.32 -1345.52 4211.43 3526.83 -1970.53 -590.61 153.98 2040.90 82.87 1958.03 PASS 5020.801- 4715.78 -439.60 -1383.10 4444.04`1 3712.15 -2107.44 -621.74 155.46 2090.12 88.50 2001.62 PASS 5120.801-, 4807.18 -454.89 -1420.69 5585.02' 4782.79 -2439.01 -692.10 159.84 2113.80 102.561_1_011.24 PASS 5220.80tr 4898.58 -470.17 -1458.27 5676.90 4874.66 -2440.41 -692.82 158.77 2113.84 105.13 08.71 PASS 5320.801 4989.97 -485.45 -1495.86 5763.52 4961.26 -2441.87 -693.50 157.70 2114.75 107.67 2007.07 PASS 5420.801- 5081.37 -500.74 -1533.45 5853.44 5051.16 -2443.57 -694.23 156.64 2116.55 110.16 2006.39 PASS 5520.801- 5172.77 -516.02 -1571.03 5949.61 5147.31 -2445.32 -695.01 155.58 2119.02 112.61 2006.41 PASS Ea ceB Clearance Report FA. NFU #24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 31 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION [Operator Cook Inlet Energy Slot !North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan jI_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] Iftl Iftl 5534.27 5185.09 -518.081, -1576.10 5964.70r- 5162.40 -2445.57 -695.16 155.44 2119.38 112.93 2006.45 PASS 5620.80t 5264.94 -530.63 -1606.95 6106.531 5304.21 -2445.54 -696.44 154.57 2120.72 114.84 2005.88 PASS 5720.80t 5358.99 -543.41 -1638.39 6205.247 5402.90 -2443.76 -697.21 153.65 2121.10 116.84 2004.26 PASS 5820.80t 5454.69 -554.32 -1665.22 6302.44 5500.08 -2441.91 -697.98 152.87 2121.47 118.54 2002.93 PASS 5920.80t 5551.78 ;1 -563.33 -1687.38 6396.62 5594.24 -2440.15 -698.93 152.23 2121.62 119.95 2001.68 PASS 6020.80t 5649.98 -570.42 -1704.80 6492.73 5690.33 -2438.53 -699.79 151.72 2121.68 121.06 2000.61 PASS 6120.80t 5749.03 -575.56 -1717.44 6590.24 5787.82 -2436.73 -700.41 151.35 2121.28 121.89 1999.40 PASS 6220.80t 5848.66 -578.74 -1725.26, 6669.07 5866.64 -2435.17 -699.93 151.09 2120.84 122.45 1998.39 PASS 6320.80f 5948.60 -579.95 -1728.24 6754.40 5951.95 -2434.12 -698.57 150.96 2120.90 122.72 1998.17 PASS 6332.20 5960.00 -579.96, -1728.27 6765.73 5963.28 -2433.99 -698.38 150.95 2120.88 122.73 1998.15 PASS, 6420.80t 6048.60 -579.96 -1728.271 6856.191 6053.71 -2432.83 -696.60 150.89 2120.73 122.80 1997.93 PASS 6520.80ti 6148.60 -579.96 -1728.271 6953.951 6151.44 -2431.49 -694.71 150.83 2120.47 122.89i 1997.59 PASS 6620.80t 6248.60 -579.96 -1728.271 7053.801 6251.27 -2430.20' -692.70 150.77 2120.33 122.97 1997.36 PASS 6720.80t 6348.60 -579.96 -1728.27 7152.887 6350.32 -2428.97 -690.71 150.70 2120.23 123.07 1997.16 PASS • 6820.80t 6448.60 -'196 -1728.27 7249.04'` 6446.46 -2428.08 -689.15 150.65 2120.21 123.17 164 PASS 6920.80t 6548.60 -579.96 -1728.27 7348.11 6545.53 -2428.47 -689.53 150.67 2120.38 123.29 1997.09 PASS 7020.80th 6648.60 -579.96 -1728.27 7455.54 6652.95 -2428.60 -689.77 150.67 2120.37 123.41 1996.97 PASS 7120.80t 6748.60 -579.96 -1728.27 7557.381 6754.80 -2428.42 -690.00 150.68 2120.11 123.53 1996.58 PASS 7220.80t 6848.60 -579.96 -1728.27 7649.36 6846.78 -2428.19 -689.88 150.67 2119.96 123.66 1996.30 PASS { 7320.80t 6948.60 -579.96 -1728.27 7758.15iii . 6955.56 -2427.76, ;. -689.34 150.65 2119.86 123.78 1996.07 PASS 7420.80t 7048.60 -579.96 -1728.27 7859.93 7057.34 -2427.07' -688.80 150.63 2119.53 123.91 1995.62 PASS 2426.08, -688.20 150.60 2118.96 124.04_ 1994.92 PASS 7520.80t 7148.60 -579.96 -1728.27 7962.03 7159.43 7620.80t 7248.60 -579.96 -1728.27 8062.451 7259.85 -2425.26 -687.76 150.58 2118.47 124.18 1994.29 PASS 7720.801 7348.60 -579.96 -1728.27_ 8160.141 7357.54 -2424.56 -687.49 150.571 2117.98 124.33 1993.66 PASS 7820.80t1 7448.60 -579.96 -1728.27 8267.59 ' ,-. .2i 1 7 7464.98 -2423.50 -686.91 150.54 17.39 124.47 1992.92 PASS 7920.80t 7548.60 -579.96 -1728.27 8367.581_ 7564.96 -2422.15 -686.29 150.51 2116.52 124.61 1991.91 PASS 8020.80t 7648.60 -579.96 -1728.27 8457.13[ 7654.50 -2421.56 -686.18 150.50 2116.00 124.77 1991.23 PASS 8120.80t 7748.60 -579.96 -1728.27 8553.76 7751.13 -2421.56 -686.58 150.51 2115.80 124.93 1990.86 PASS 8220.80t 7848.60 -579.96 -1728.27 8647.35 7844.73 -2421.66 -686.74 150.51 2115.81 125.10 1990.71 PASS 8320.80t 7948.60 -579.96 -1728.27 8739.68 7937.04 -2422.48 -687.43 150.54 2116.22 125.27 1990.95 PASS Ea ceb Clearance Report Fait NFU #24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 32 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot !North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 -----__ --_---------....__..---- Field North Fork Wellbore NFU#24-26 Wellplan 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 Iftl Iftl Iftl Iftl lftl lftl IN IN Bearing Clear Dist MASD Sep Status 1°1 IN Iftl Iftl 8420.80tr 8048.60 -579.96 -1728.27 8838.50 8035.85 -2423.53, -688.12 150.57 2116.79 125.441 1991.35 PASS 8520.80t 8148.60 -579.96 -1728.27 8939.66 8137.01 -2424.43 -688.63 150.59 2117.32 125.61 1991.71 PASS 8620.80t 8248.60 -579.96 -1728.27 9043.42 8240.77 -2425.12 -688.85 150.61 2117.80 125.79 1992.02 PASS 1 8720.80tj 8348.60 -579.96 -1728.27 9142.43 8339.78 -2425.65 -688.91 150.62 2118.23 125.96 1992.27 PASS 8820.801448.60 -579.96 -1728.27 9248.43 8445.78 -2426.04 -688.84 150.62 2118.59 126.14 1992.45 PASS j 8920.801T-8548.60 -579.96 -1728.27 9365.80 8563.14 -2425.93 -689.42 150.63 2118.26 126.30 1991.96 PASS 9020.801 8648.60 -579.96 -1728.27 9468.25 8665.58 -2425.93 -691.07 150.67 2117.47 126.53 1990.94 PASS 9120.801 8748.60 -579.96 -1728.27 9576.55 8773.87 -2425.56 -692.73 150.70 2116.42 126.72 1989.70 PASS I 9220.80t 8848.60 -579.96 -1728.27 9648.79 8846.11 -2425.46 -693.60 150.72 2115.75 126.93 1988.82 PASS 9320.80f 8948.60 -579.96 -1728.27 9746.62 8943.93 -2426.19 -694.39 150.75 2116.01 127.14 1988.87 P "• 9420.80t 9048.60 -579.96 -1728.27 9847.18 9044.49 -2426.74 -694.89 150.77 2116.24 127.34 1988.90 PASS 9520.80t 9148.60 -579.96 -1728.27 9946.20 9143.50 -2427.07 -695.11 150.78 2116.43 127.54 1988.88 PASS 9620.80t 9248.60 -579.96 -1728.27 10049.05 9246.36 -2427.30 -695.07 150.78 2116.64 127.75 1988.89 PASS 9720.80t 9348.60 -579.96 -1728.27 10149.43 9346.73 -2427.28 -694.87 150.78 2116.72 127.96 1988.76 PASS 9752.20 9380.00 -579.96 -1728.27 10179. ; 9376.98 2427.21 694. 71 150.77 2116.75 128.02 1988.73 P.r': 9820.80t 9448.60 -579.96 -1728.27 10247.79; 9445.09 -2427.17 -694.34 150.76 2116.89 128.17 1988.72 PASS 9920.80t 9548.60 -579.96 -1728.27 10346.14 9543.42 -2427.99 -695.53 150.80 2117.02 128.41 1988.62 PASS 10000.20 9628.00 -579.96 -1728.27 10432.46 9629.741 -2428.74 -696.66 150.84 2117.12 128.60 1988.52 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NFU#32-35 Offset Wellpath:OnTrak MWD<196- 12070'> Slot Surface Uncertainty @1 SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @ISD Horizontal 20.000ft Vertical 3.000ft Ea ceb Clearance Report Ira. Cook Inlet Energy NFU#24-26 Ver#3 BAKER Closest Approach Page 33 of 38 HUGHES REFERENCE WELLPATII IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) HOLE& CASING SECTIONS-Offset Wellbore:NFU#32-35 Offset Welipath:OnTrak MWD<196- 12070'> (String/Diameter Start MD End MD I Interval I Start TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] Ift] I VII IN [ft] [ft] 16in Conductor 0.00 178.00 178.00 -20.70 157.26 0.37 -72.84 -0.18 -73.74 9.625in Casing Surface 0.00 3212.00 3212.00 -20.70 2749.88 0.37 -72.84 -406.85 -169.64 lin Casing Intermediate 0.00 5570.00 5570.00 -20.701 4746.97 0.37 -72.84 -743.15 -247.34 1 4.5in Casing Production 0.00 11635.00 11635.00 -20.70 10811.31 0.37 -72.84 -738.25 -252.95 WELLPATH COMPOSITION -Offset Wellbore:NFU#32-35 Offset Welipath:OnTrak MWD<196-12070'> I Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore IN Iftl I 0.00 3159.00 OnTrak(Standard) OnTrak MWD<196-3159'> NFU#32-35 I' 3159.00 5754.00 OnTrak(Standard) OnTrak MWD<3266-57545 NFU#32-35 5754.00 12070.00,OnTrak(Standard) OnTrak MWD<5822-120705 NFU#32-35 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 Welipath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD O.00ft Ea cea Clearance Report FA` Cook Inlet Ener NFU #24-26 Ver BAKER - Energy Closest Approachh Page 34 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 [field North Fork Wellbore NFU#24-26 Wellplan ;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 [ft] IftI IftI IftI IftI [ft] [ft] Ift] Bearing Clear Dist MASD Sep Status I°I IftI [ft] IftI 20.80 20.801 0.00 0.00 125.73 24.33 -1327.99 886.98 146.26 1596.97 121.72 1475.25 PASS ' 120.801.1_ 120.80 0.00 0.00 226.34 124.93 -1327.83 886.79 146.26 1596.73 121.94 1474.79 PASS 220.801. 2• 20.80 0.00 0.00 326.68 225.27 -1327.70 886.49 146.27 1596.45 121.67 1474.78 PASS 300.25 ' 300.25 0.00 0.00 405.51 304.11 -1327.65 886.19 146.28 1596.25 121.68 1474.57 PASS 308.571.'. 3• 08.57 0.01 0.00 413.79 312.39 -1327.64 886.16 146.28 1596.24 121.68 1474.56 PASS 311.04t 311.04 0.02 0.00 417.50 316.10 -1327.64 886.15 146.28 1596.24 121.68 1474.56 PASS 320.80t 320.80 0.07 0.00 425.98 324.58 -1327.64 886.11 146.28 1596.26 121.68, 1474.58 PASS 420.80t 420.76 2.53 -0.09 525.10 423.69 -1327.63 885.73 146.34 1598.13 121.69'; 1476.44 PASS 520.801.1 520.58 8.48 -0.30 620.56 519.16 -1327.74 885.40 146.46 1603.10 121.721_ 1481.38 PASS 620.80)"pir 620.13 17.90 -0.63 709.17 607.77 -1328.25 885.33 146.65 1611.59 121.75 489.84 PASS 700.25 698.95 27.86 -0.97 783.481 682.07 -1328.98 885.46 146.84 1620.82' 121.77 1499.05 PASS 720.80t, 719.30 30.72 -1.07 802.80 701.39; -1329.19 885.51 146.90 1623.49 121.78 1501.71 PASS 820.80t'I 818.33` 44.63 -1.56; 901.16 799.74' -1330.34 885.77 147.16 1636.53 121.79 1514.74 PASS 900.25 1 8• 97.01 55.68 -1.94 981.61 880.19 -1331.29 885.89 147.38 1646.88 121.811 1525.07j PASS • .801. 9• 17.36 58.47 -2.13 1002.42 901.00 -1331.54 885.89 147.43 1649.54 121.82 _ PASS-* r 1020.80t 1016.61 70.18 -5.57 1103.59 1002.16 -1332.71 885.80 147.57 1662.18 121.841540.34' PASS 1120.801. 1115.94 78.73 -13.19 1206.83 1105.39 -1333.81 885.50 147.53 1674.22 121.871 1552.35 PASS 1220.80t 1215.08 84.10 -24.97 1304.90 1203.45 -1334.82 885.12 147.32 1685.75 121.90 1563.85 PASS 1320.801. 1313.77 86.29 -40.87 1406.16 1304.71 -1335.75 884.83 146.94 1696.82 121.93 1574.89 PASS 1420.80t 1411.74 85.28 -60.86 1504.75 1403.30 -1336.52 884.57 146.38 1707.46 121.96 1585.50 PASS 1520.801. 1508.71 81.08 -84.87 1600.46 1499.00 -1337.27 884.37 145.65 1717.91 122.00 1595.92 PASS 1620.801.1 1604.42 73.69 -112.84 1695.26 1593.80 -1337.96 884.35 144.76 1728.38 122.05 1606.33 PASS 1720.801.1 1698.61 _ 63.15 -144.70 1794.32 1692.86 -1338.52 884.39 143.71 1738.89 122.12;_ 1616.77 PASS 1820.80.1.1 _.1791.02 49.47 -180.36 1891.07 1789.61 -1338.73 884.44 142.51 1749.54 122.22 1627.32 PASS 1822.49 :1792.56 49.22 -180.99 1892.69 1791.23 -1338.73 884.44 142.49 1749.73 122.221627.50 PASS 1920.80ti 1882.42 34.19 -217.94 1982.53 1881.07 -1338.76 884.50 141.24 1760.79 122.35rr 1638.43 PASS 2020.80t 1973.82 18.91 -255.53 2072.98 1971.52 -1338.86 884.52 139.98 1772.92 122.36 1650.56 PASS 2120.80t1 2065.22 3.62 _ -293.11 2162.55 2061.09 -1338.92 884.69 138.74 1785.96 122.54 1663.42 PASS ( 2220.80t1 2156.62 -11.66 -330.70 2253.51 2152.05 -1339.02 884.93 137.52 1799.91 122.75 1677.16 PASS 2320.801.1"°'1'2248.01 -26.941; ,, -368.29 2346.77 2245.31 -1339.16 885.08 136.31 1814.62 122.98 1691.64 PASS Ea ceB Clearance Report FA. NFU#24-26 Ver#3 BAKER Inlet Energy_ Closest Approach Page 35 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION ;Operator Cook Inlet Energy !Slot (North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 'Field North Fork Wellbore NFU#24-26 WelIplan 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 lftl MI Iftl Iftl lftI Iftl lftl IN Bearing Clear Dist MASD Sep Status 101 IftI IN _ lft1 2420.801 2339.41 -42.237 -405.87 2438.48 2337.02 -1339.22 885.15 135.13 1830.01 123.23 1706.78 PASS 2520.801 2430.81 -57.51 -443.46 2528.91 2427.45 -1339.27 885.35 133.97 1846.25 123.50 1722.75 PASS 2620.801- 2522.21 -72.80 -481.04 2624.76 2523.30 -1339.30 885.42 132.83 1863.13 123.79P 1739.33 PASS 2720.801 2613.61 -88.08 -518.63 2720.09 2618.63 -1339.14 885.30 131.71 1880.48 124.10 1756.38 PASS ( 2820.801; ,3,2705.01 -103.36 -556.22 2809.74 2708.28 -1338.98 885.19 130.60 1898.53 124.42 1774.11 PASS 2920.8012796.41 -118.65 -593.80 2901.71 2800.25 -1338.78 885.14 129.52 1917.29 124.54 1792.75 PASS 3020.80112887.80 -133.93 -631.39 2995.95 2894.48 -1338.42 885.10 128.46 1936.64 124.76 1811.88 PASS 3120.801- 2979.20 -149.21 -668.97 3079.91 2978.45 -1338.05 885.21 127.41 1956.73 124.99 1831.74 PASS 3220.801 3070.60 -164.50 -706.56 3167.45 3065.99 -1337.75 885.61 126.39 1977.76 125.24 1852.5_3 PASS 3320.801 3162.00 -179.78 -744.14 3255.50 3154.03 -1337.41 886.20 125.38 1999.54 125.49 1874.05 PASS 3420.801 3253.40 -195.06 -781.73 3345.00 3243.53 -1336.94 887.04 124.38 2022.07 125.75 1896.31 PASS 3520.801- 3344.80 -210.35 -819.32 3438.12_ 3336.65 1336.58 887.79, 123.41 2045.16 126.03 1919.14 PASS 3620.801 3436.20 -225.63 -856.90 3534.24 3432.77 -1336.37 888.27; 122.48 2068.66 126.31 1942.35 PASS 3720.801 3527.60 -240.92 -894.49 3630.25 3528.77 -1335.85 888.631 121.55 2092.46 126.59 1965.87 PASS 3820.80t 3618.99 -256.20 -932.07 3721.69 3b' `21 -1335.34 888.8411 20.65 i. 116.67 126.88 1989.78 PASS 3920.801- 3710.39 -271.48 -969.66 3808.29 3706.81 -1335.02 889.107.119.78 _2141.51 127.18 2014.34 PASS 4020.801 3801.79 -286.77 -1007.24 3898.44 3796.96 -1334.76 889.441 118.92 2166.96 127.48 2039.49 PASS 4120.801 3893.19 -302.051 -1044.83 3990.40 3888.92 -1334.66 889.727 118.09 2192.89 127.78 2065.11 PASS 4220.801 3984.59 -317.33 -1082.42 4078.69 3977.21 -1334.64 889.98' 117.28 2219.30 128.09 2091.22 PASS 4320.801* 4075.99 -332.62 -1120.00 4171.48 4069.99 -1334.61 890.34 116.49 2246.22 128.40 2117.82 PASS 4420.80t 4167.39 -347.90 -1157.59 4271.73 4170.25 -1334.94 890.29 115.73 2273.34 128.72 2144.62 PASS 4520.801 4258.78 -363.18 -1195.17 4363.15 4261.66 -1335.09 890.03 114.99 2300.58 129.03 2171.55 PASS 4620.801 4350.18 -378.47 -1232.76 4448.55 4347.06 -1335.73 889.72 114.28 2328.36 129.35 2199.02 PASS 4720.801- 4441.58 -393.75 -1270.35 4532.38 4430.89 -1336.17 889.791' 113.57 2356.79 129.66 2227.13 PASS 4820.801- 4532.98 -409.04 -1307.93 4617.09 4515.59 -1336.43 890.24 112.88 2385.86 129.98 2255.89 PASS 4920.801- 4624.38 -424.32 -1345.52 4706.20 4604.71 -1336.43 891.00 112.19 2415.44 130.29._2285.15 PASS 5020.801 4715.78 -439.60 -1383.10 4804.83 4703.33 -1336.15 891.81 111.51 2445.23 130.61 2314.63 PASS 5120.801 4807.18 -454.89 -1420.69 4898.08 4796.58 -1335.81 892.41 110.85 2475.19 130.92 2344.27 PASS 5220.801- 4898.58 -470.17 -1458.27 4988.86 4887.36 -1335.68 892.88 110.21 2505.43 131.24' 2374.19 PASS 5320.801 4989.97 -485.45 -1495.86 5078.40 4976.90 -1335.80 893.29 109.59 2536.00 131.55 2404.45 PASS Ea ceI3 Clearance Report FA. Cook Inlet Energy NFU#24-26 Ver BAKER Closest Approach NFU Page 36 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator 1Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 1Field LNorth Fork 1Wellbore NFU#24-26 Wellplan 1Facility 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 ).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 [ft] [ft] [ft] [ft] [ft] Iftl [ft] Bearing Clear Dist MASD Sep Status lftl Iftl 5420.80+ 5081.37 -500.74 -1533.45 5169.66 5068.16 -1335.85 893.78 108.99 2566.91 131.87 2435.04 PASS 5520.80+ 5172.77 -516.02 -1571.03 5261.23 5159.72 -1335.84 894.28 108.39 2598.08 132.18 2465.90 PASS 5534.27 5185.09 -518.08 -1576.10 5273.54 5172.03 -1335.82 894.35 108.32 2602.30 132.22-2470.08 PASS 5620.80+ 5264.94 -530.63 -1606.95 5360.60 5259.09 -1335.62 894.78 107.84 2628.06 132.49r 2495.57 PASS 5720.801 5358.99 -543.41 -1638.39 5457.93 5356.42 -1335.37 894.96 107.36 2654.25 132.78 ;2521.47 PASS 5820.80+ 5454.69 -554.32 -1665.22 5554.65 5453.14 -1335.16 895.13 106.96 2676.77 133.041 2543.74 PASS 5920.80+ 5551.78 -563.33 -1687.38 5658.61 5557.10 -1334.71 895.21 106.63 2695.34 133.27 2562.07 PASS 6020.801 5649.98 -570.42 -1704.80 5761.40 5659.89 -1333.73 895.171 106.36 2709.721 133.47 2576.26 PASS 6120.80t 5749.03 -575.56 -1717.44 5858.88 5757.35 -1332.23 895.24 106.15 2720.06 133.63 2586.44 PASS 6220.80t 5848.66 -578.74 -1725.26 5955.89 5854.35 -1330.83 895.39 106.01 2726.44 133.76;_ 2592.69, PASS 6320.80+1 _5948.60 -579.95 -1728.24 6054.11 5952.57_ -1329.73 895.531 105.95 2728.80 133.86 2594.94 PASS 1 6332.20 5960.00 -579.96 -1728.27 6065.34 5963.79 -1329.64 895.54 105.95 2728.81 133.87 2594.94, PASS 6420.80t 6048.60 -579.96, -1728.27 6156.55 6055.01, -1329.09 895.54 105.94 2728.67 133.92 2594.75 PASS 6520.80+ 6148.60 -579.96 -1728.27 6248.71 6147.17 -1328.66[ 895.47[ 105.93 2728.47 133.98 2594.49 PASS 6620.80t 6248.60 -579.96 -1728.27 6333.36 6231.81 -1328.425.8611605.92 2728.83 134.04 " `2594.79 PA 6720.80+ 6348.60 -579.96 -1728.27 6427.28 6325.72 -1328.00 896.77'105.91 2729.64 134.10 2595.54 PASS 6820.80+ 6448.60 -579.96 -1728.27 6534.77 6433.21 -1327.08 897.76 105.88 2730.28 134.17 2596.11 PASS 6920.80+ 6548.60 -579.96 -1728.27 6673.20 6571.64 -1326.42 898.251 105.87 2730.631 134.26 2596.37 PASS 7020.80t 6648.60 -579.96 -1728.27 6791.01 6689.43 -1325.54 896.83L_105.86 2729.23' 134.33 2594.91 PASS 7120.80t 6748.60 -579.96 -1728.27 6876.82 6775.23 -1324.64 895.9M105.84 2727.97 134.40 2593.57 PASS 7220.80+ 6848.60 -579.96 -1728.27 6971.46 6869.87 -1324.02 895.327 105.83 2727.14 134.47 2592.67 PASS 7320.80+ 6948.60 -579.96 -1728.27 7072.74 6971.14 -1323.80 894.55 105.83 2726.36 134.56_ 2591.80 PASS 7420.80+ 7048.60 -579.96 -1728.27 7173.26 7071.66 -1323.59 893.73 105.83 2725.51 134.64 2590.87 PASS 7520.80+ 7148.60 -579.96 -1728.27 7271.45 7169.85 -1323.28 892.98 105.83 2724.69 134.72 2589.97 PASS 7620.80t 7248.60 -579.96 -1728.27 7370.20 7268.60 -1323.27 892.21 105.84 2723.94 134.81 2589.13 PASS 7720.801 7348.60 -579.96 -1728.27 7474.59 7372.98 -1323.60 891.27 105.85 2723.15 134.90 2588.25 PASS 7820.80+ 7448.60 -579.96 -1728.27 7574.63 7473.01 -1323.81 890.24 105.86 2722.23 134.99 2587.23 PASS 7920.80+ 7548.60 -579.96 -1728.27 7671.87 7570.25 -1324.27 889.251 105.87 2721.38 135.09 2586.29 PASS 8020.80+ 7648.60 -579.96 -1728.27 7776.34 7674.71 -1324.81 888.19[ 105.89 2720.54 135.19 2585.35 PASS 8120.80+ 7748.60 -579.96 -1728.27 7877.97 7776.33 -1325.23 887.0(W:105.91 2719.53 135.29 2584.24 PASS Ea ceB Clearance Report Irak NFU #24-26 Ver#3 BAKER Cook Inlet Energy_ Closest Approach Page 37 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION IO erator'Cook Inlet Energy Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 ;Field North Fork Wellbore NFU#24-26 Wellplan ;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 IftI [ft] Ift] Iftl IftI IftI Ift] Ift] Bearing Clear Dist MASD Sep Status I01 [ft] IftI [ft] 8220.80t 7848.60 -579.96 -1728.27 7971.89 7870.25 -1325.49 886.01 105.92 2718.59 135.39 2583.20 PASS 8320.80t 7948.60 -579.96 -1728.27 8064.27 7962.63 -1325.66 885.33 105.92 2717.94 135.49 2582.45 PASS 8420.80t 8048.60 -579.96 -1728.27 8160.30 8058.65 -1325.79 884.88 105.93 2717.52 135.59 2581.93 PASS 8520.80t 8148.60 -579.96 -1728.27 8252.16 8150.51 -1326.11 884.53 105.94 2717.25 135.69 2581.56 PASS 8620.801 8248.60 -579.96 -1728.27 8348.36 8246.71 -1326.32 884.56 105.94 2717.34 135.79 2581.55 PASS 8720.80t 8348.60 -579.96 -1728.27 8451.71 8350.07 -1326.38 884.52 105.94 2717.32 135.79 2581.53 PASS 8820.801 8448.60 -579.96 -1728.27 8558.18 8456.53 -1326.35 884.40 105.94 2717.20 135.90 2581.30 PASS 8920.80t 8548.60 -579.96 -1728.27 8662.01 8560.36 -1326.33 883.95 105.95 2716.78 136.00 2580.78 PASS 9020.80t 8648.60 -579.96 -1728.27 8762.83 8661.18 -1326.20 883.53 105.95 2716.35 136.11 2580.23 PASS 9120.801 8748.60 -579.96 -1728.27 8862.75 8761.10 -1326.02 883.09 105.95 2715.87 136.22 2579.65 PASS 9220.801 8848.60 -579.96 -1728.27 8956.96 _8855.31 -1325.82 882.77 105.94 2715.49 136.33 2579.15 PASS 9320.801 8948.60 -579.96 -1728.27 9058.08 _8956.42 -1325.93 882.54 105.95 2715.30 136.45 2578.85 PASS 9420.801 9048.60 -579.96 -1728.27 9163.40 9061.75; -1325.99 882.07 105.95 2714.88 136.57 2578.32 PASS 9520.80t 9148.60 -579.96 -1728.27 9261.60 9159.94 -1326.28 881.49 105.96 2714.40 136.69 2577.72 PASS 9620.801 9248.60 -579.96 -1728.27 9366.05 9264.391's, '11327.01 880.81 105.98 2713.97 136.81 2577.16 PASS 9720.80t 9348.60 -579.96 -1728.27 9472.17 9370.49 -1328.45 879.61 106.01 2713.25 136.95 2576.31 PASS 9752.20 9380.00 -579.96 -1728.27 9505.08 9403.39 -1328.97 879.17 106.03 2712.99 136.99 2576.00 PASS 9820.80t 9448.60 -579.96 -1728.27 9579.17 9477.47 -1330.30 878.05 106.06 2712.33 137.09 2575.24, PASS 9920.80t 9548.60 -579.96 -1728.27 9683.14 9581.40 -1332.41 876.19 106.11 2711.18 137.23 2573.95 PASS „1(1000 20 _ 9628.00, -579.96, -1728.27; 9763.40; 9661.62, -1334.11 874.67 106.16 2710.20 137.34„ 2572.86 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft cea Clearance Report Irak NFU #24-26 Ver#3 BAKERCook Inlet Energy_ Closest Approach Page 38 of 38 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy !Slot North Fork#24-26 Area Cook Inlet,Alaska(Kenai Peninsula) Well NFU#24-26 Field North Fork Wellbore NFU#24-26 Wellplan Facility North Fork Unit(NAD27) 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 Iftl Iftl Iftl Iftl Iftl [ft] Iftl [ft] [ft] 20in Conductor 0.00 246.00 246.00 -122.20 123.80 -809.60 540.79 -809.50 540.69 13.375in Casing Surface 0.00 2000.00 2000.00 -122.20 1877.74 -809.60 540.79 -812.85 540.01 9.625in Casing Intermediate 0.00 8451.00 8451.00 -122.20 8328.55 -809.60 540.79 -809.07 540.01 7in Liner 8330.00 109851.00 101521.00 8207.55 NA -809.051 540.02 NA NA WELLPATH COMPOSITION- Offset Wellbore:NF#41-35 Offset Wellpath:GyroData PGMS<100-9932'>Inclination ONLY<10070-12334'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore - Iftl Iftl 0.00 9932.00 Gyrodata standard-Continuous gyro I GyroData PGMS<100-9932'> NF#41-35 9932.00 12334.00 Custom Drift Indicator(7°Maximum Inclination) Inclination ONLY<246-12334'> NF#41-35 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 0.00ft Ea Cook Inlet Energy_ DRILLING OPERATIONS SUMMARY Cook Inlet Energy 0 North Fork Unit #24-26 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Start Depth Seat Depth Casing Interval Hole Size MD ND MD TVD Size Wt(Ib/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 2870 2750 9.625 40 N/L 80 SP DRFTBTC 5750 3090 916 Prod 8.75 0 0 10000 9628 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 +/- 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 1/4", 2M flange. 4. Nipple up 21 'h4", 2M diverter, 16" diverter valve and 16" diverter line. 5. Function test diverter and diverter valve. (AOGCC 24 hr notice) 6. Build spud mud. 7. Inspect bha equipment. 8. 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. Z ( �P , tr/9 • 3. Continue to drill a 1..3 hole to 2870' 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. ND Diverter. 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 universiality 14. NU adapter spool. NU 13 5/8" 5M Shaffer LWS BOPs. Test BOPs and choke manifold to 250/3000 psi, 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 ±10000'MD / ±9628'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. h 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 ±6000' 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. ® GE Oil & Gas F 47.7" 0 (c'u )) I rn ur,' r" o 1 30.2" `�' 1` fr MI 2-916"5M 5'5b N.ur. `i 24/16"9.4 ,L,' ..- - 7 l . . 11.4" �`1 T 2-9,16'5M ifri#2-9/16'SM �®Io I: 11111101.1•1161 OWL 45 N' iiii1 2-9/16'5MillO®�O 12 IIIK /t 11"5M L i-- i _ t 28.5'toC.I lc 00' 0 T Wiz 1 5M i-,� ' IN_ •� 2-1/16'5M 5... DI I I l • '.' 28.5"to C. 1I= L 1 :1' ti 12I 31.7' lir, - O k 1 li 0 i 101 r' Y' Y fir- G //I) Ir 2-1/16'5M l 26"O.D.Base Plate 1- 9-5/8'Casing _ 7'Casing 2-7/8'Tubing .__F11/4"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 ENERGY 24-36 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 711 x 2-7/8" 5M SH2 Wellhead Assembly, DRAWN CR 19DEC13 With T-M40-CCL Tubing Hanger and Adapter Flange APP RF KN 19DEC13 FOR REFERENCE ONLY DRAWING NO. 1001107-A Glacier 1 Choke Manifold To Gas Buster To Blooey Line Bleed off Line to Shakers R . 1 X X ®_ I, 1 I, II I, I 00 0 , 0 uoe8 l it I — � �] l� �1 It 11 l' i % I `I I `I r1©MIME I immoi hmia mai l VP MMI �1WIF NI u OMEN 10111100 ri 0 10 1111 I 3"5M Valves0 f 2 9/16" 10M Swaco ` ` 3 1/8" 5M Manually Hydraulically Operated Adjustable Choke Choke Gauge Block 14 Choke Hose to HCR � � (from BOP Stack) 0-6,000 psi Choke Control Pressure Gauge Pressure Sensor Glacier 1 Diverter Flow line 21 1/4"2M Diverter NIIIIIIV 16"Automatic Knife Valve • Diverter Spool ______ II 1111II \ • - 16" Diverter Line Cook Inlet Energy_ Rig 37 Formerly Glacier 1 BOP Stack Floe:Nipple ____ ROA Line t � 2 7/8"x 5"variable 13 5/8"5M Annular Preventer Blind <Nomimmo' I � 13 5/8"SM Double -7/ A S Ram Preventer Pipe Ram ■ 2 1/16"5M . 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E-. . m 7 L CO 'V a) (B a) c n o c O)-o c (v () _ L O o O ,C c 3 c ca c O a) 3 0 ..... E U (13 a) O L 30 CD W o O U 0 O) a) a L -0 O o- V O N L O O- N >' a) O N N IQ c> > c N c O o otS "CD �+ O T 23 O m c N d (0 to c 42 C� N J E N •.0 a c a) O) a) E N Y a) C.) C.) 0 - 0 _o .D a) Y -c (U .0 o_L L 'LA, }M� 't > (f' 7 aoi W)_ 0 p ° .0 0 c`a co E �V/ Q L m N a) Q- m a) Y (13 .� a) /1/ > 7 LWL c 7 0 a) L co O to' 3 a)) �_ co coV a5 aL) (L._ c a) Q) (n c c > o < 2 3 L 1- a c C Q V Q Q Uci criv ui6r� cOOi W Me SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program DRILLING FLUIDS PROPOSAL Cook Inlet Energy, LLC North Forelands Unit 24-26 Fluids Program Cook Inlet Energy_ NAME SIGNATURE DATE Prepared: Francis/Hanson 09124/2014 Reviewed by:Mark Fairbanks Customer Approval: Version:1.0 NOTE:This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity Ver. 1.0 CONFIDENTIAL Page 1 of 17 Mg SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Proposal Summary North Forelands Unit 24-26 is a deviated grassroots exploration well that will be drilled utilizing Miller rig#37. It is proposed that a M-I GEL Spud Mud system be utilized for the 12.25"surface hole section to 2,750' MD. In order to minimize the need of having large quantities of product on hand and also reduce the amount of cuttings that need to be hauled away, it is suggested that a highly inhibitive KLA-SHIELD system be used to drill the 8.75" production interval to 9,746' MD. The KLA-SHIELD system will be comprised of 3-6% KCL and sized Calcium Carbonate. Contingency products will be on hand to cover events such as mud weight increases and to combat any lost circulation problems that may occur. • Footage Depth Mud Weight Casing Size Hole Size Casing Intervals Depth MD TVD of Hole Mud System Drilled �pP9) 16" NIA • 80' 80' Driven N/A NIA 12.25" 9.625" 8.835"ICD D 0.1458 ,y 2,750' 2,750' 2,750' Gel Spud Mud 8.8-9.2 bbls/ft •. �. IN ,, 8.75" 7"GD 0.0744 : 6.276"ID :} 9,746' 9,375' 4,648' Kla Shield 9.0-9.6 bbls/ft i� Pat Ver. 1.0 CONFIDENTIAL Page 2 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Fluid and Drilling Concerns • Hole Instability—While drilling through shale take notice of the cuttings size and shape to ensure that there are no hole instability issues or indications of break out i.e. large angled cuttings. • Lost Circulation—Monitor fluid volumes to detect any early signs of lost circulation, if lost circulation is encountered treat appropriately by following the LCM decision tree. • High ECD's—Ensure that the fluid properties are maintained to provide the best possible hole cleaning properties. Maintain mud weights as per program guidelines and or hole conditions and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. • Coal— In the Cook Inlet, area drilling through large coal seams have proven problematic in the past. Increasing the density of the drilling fluid has proven to be effective when any signs of hole instability due to coal are seen. Refer to the"Drilling Coal"section of the program. • Surge and Swab—Surge and Swab can increase the potential for wellbore instability, use proper drilling and tripping practices to mitigate this risk. • Logistics—Due to the limited amount of room for product and the effort it takes for the product to get to the drill rig, proactive measures need to be taken for logistics. Mud Engineers will take daily inventory and order product ahead of time. • pH—Keep pH in the range of 9.0-10.0 as this is essential in mitigating corrosion. • Tripping Pipe—Stage into the open hole in several increments breaking circulation each time and circulating for a period of time to ensure adequate fluid movement. Idle pumps when beginning circulation to minimize surge pressures. Work pipe and rotate while circulating to help break up gel strengths. Hole Cleaning Recommendations • Rheology and Hydraulics calculations will be run daily and the mud properties will be adjusted as needed to maximize hole cleaning. • Use the highest possible annular velocity to maintain good hole cleaning. Annular velocity provides the upward impact force necessary for good cuttings transport. • Control drill to manage difficult hole cleaning situations. Penetration rates determine the annular cuttings load. Use the PWD data (if available)to determine when it is necessary to stop drilling and circulate the hole. • Keep cuttings concentration less than 5% (by volume) in order to minimize drilling problems. • Virtual Hydraulics will be run through each hole section to optimize the fluid for maximum hole cleaning efficiency. Ver. 1.0 CONFIDENTIAL Page 3 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Sweep Recommendations • Don't recommend the use of sweeps unless hole conditions dictate. • Hi-Vis sweeps are recommended to use if needed. The volume should be enough to cover at least 200- 300' annular volume of the open hole. The recommended rheology of the sweep would have the Yield Point in the 35-40 range and the 6 RPM readings in the 15-20 range. • Weighted sweeps are another option, but Hi-Vis sweeps are preferred. • The need to pump LCM sweeps will be dictated by hole conditions. Bit/BHA Balling Recommendations • Reactive clay formations can absorb high volumes of water and can be extremely sticky and problematic regardless of the degree of inhibition. • The drilling rate should be controlled to keep the concentration of cuttings in the annulus below 5%. • Short trips should be made as necessary to minimize buildup of cuttings in areas of hole washout. • During trips, the BHA can accumulate cuttings that will potentially ball it. Recommend circulating for a short period to circulate up any formation that may have adhered to the BHA or bit during the trip. Ver. 1.0 CONFIDENTIAL Page 4 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program 12.25" Interval Summary SURFACE INTERVAL Drilling Fluid System M-I GEL Spud Mud Key Products M-I GEL, GELEX Bentonite Extender,POLYPAC SUPREME UL&Soda Ash Solids Control Shakers,Centrifuge Potential Problems Hole Stability Shallow Gas Washout Swelling Clays INTERVAL MUD PROPERTIES Depth MD Mud Wt. Funnel Plastic Yield Point API Fluid Loss LGS (ft) (ppg) Viscosity Viscosity (Ib1100ft2) (m1130min) (%) 0'-2,750' 8.8-9.2 • i 85-125 20-40 25-45 <9 <13% NOTE:This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Surface Interval Overview Lithology through this zone is a composite of sand and small pea gravel in the upper intervals with a grading downward to predominately sand and some siltstone in the lower zones of this interval. Based upon work done on previous wells in this area, an M-I GEL Spud Mud is recommended for the surface interval. Initial Fluid Makeup for M-I GEL Spud Mud (Use fresh water): M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 lb/bbl or as needed GELEX As needed (do not add until drilling out conductor) M-I GEL Spud Mud Additions: M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 lb/bbl or as needed Caustic Soda As needed for a pH of 9.0—9.5 GELEX As needed for viscosity POLYPAC SUPREME UL 0.25 lb/bbl or as needed to control fluid loss Ver.1.0 CONFIDENTIAL Page 5 of 17 Mi BWAC__� . Cook Inlet Energy,LLC NFU 2426 Fluids Program Surface Interval Drilling Discussion • Lithology—Lithology through this zone is a composite of sand and small pea gravel in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Lithology through the bottom of the interval should consist of mostly sand and some siltstone. M-I GEL Spud Mud is to be used for the surface interval. • Bit Balling— If there is any indication of bit balling, pump bit balling pill with: o 15 ppb PECAN NUT PLUG MEDIUM (do not add SAPP) • RheologylGel Strengths—2 lbs. of GELEX per 3,500 lbs. of M-I GEL EXPORT should be used to maintain viscosity when needed. Do not depend on GELEX additions to provide needed gel strengths; be sure to have a sufficient MBT. • Hole Cleaning—Gravel sizes that are larger than normal can contribute to poor hole cleaning. If encountered, increase viscosity to provide good hole cleaning. • Washing Out Conductor Shoe—Maintain low flow rates for the initial 200' of drilling to reduce the risk of washing out the conductor shoe. • Conditioning Mud for Cement—Conditioning mud per cement contractor's specifications, AFTER casing is landed. Before cementing the surface casing into place, check that the YP is sufficient per cementers. Utilize CF Desco II, SAPP and Citric Acid to treat any cement contaminated mud if necessary. Surface Interval Fluids Operations • Read all MSDS's on products that will be used throughout the conductor interval. • Start mixing spud mud with fresh water by adding .25- .50 ppb of Soda Ash (depending on hardness)to the makeup water before any other product to treat any possible calcium in the makeup water and raise the pH to an acceptable level so the gel can yield properly. • After drilling out conductor, add GELEX Bentonite Extender to the M-I GEL Spud Mud per Mud Engineers instruction to increase the viscosity to 100-150 sec/qt. GELEX concentration should be 1- 2#bag per 70sx of M-I GEL. • After drilling out the conductor, open the active system to all available pits. • Maintain funnel viscosity at 85-150 sec/qt while drilling and running casing. If mostly sand and clay are encountered this can be lowered if needed. • Watch pit volumes closely for any increase in volume or flow from the well. • Utilize POLY PAC SUPREME UL to maintain API fluid loss < 9 in lower section of the hole. • If bit balling is an issue while drilling through any clay, pump sweeps with 15 ppb PECAN NUT PLUG MEDIUM. Do not use SAPP as decreased mud viscosity will occur. • Maintain MBT no greater than 30 Ib/bbl and add GELEX Bentonite Extender as needed for increased viscosity. Ver.1.0 CONFIDENTIAL Page 6 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program • Keep drill solids as low as possible by running available surface equipment equipped with the recommended screen sizes at the end of this program. Dump and dilute if gel strengths become highly progressive. • Upon reaching TD, watch the bottoms-up cuttings closely. If the well does not readily clean up or if there are any excess of torque, drag, pick-up or slack-off weights, pump a high viscosity/weighted sweep and observe bottoms up again. Mud Engineers to note the results in the One-Trax daily report. • After running casing, break circulation and adjust yield point as necessary per cementers. Lower the yield point with additions of water and CF Desco II. • After YP is lowered and the rig is ready to cement, have CF Desco II, SAPP, and Sodium Bicarbonate along with cement retarder ready for cement returns to surface. Isolate on the suction pit and pre-treat spud mud with SAPP and Citric or Sodium Bicarbonate, but not both as aeration can occur, in preparation to bump the plug. Ensure there is enough fluid volume to bump the plug when preparations are being made. • Keep enough treated Spud Mud to drill out the shoe track and 20' +/-of hole. Surface Interval Hole Cleaning • Extra time should be spent on circulation prior to connections and trips. • Adjust rheology when needed to help with hole cleaning. • Make wiper trips every 500'or as hole conditions dictate. • High viscosity sweeps may help but should not be used as a primary cleaning strategy. • Maximized RPM while drilling and circulating will greatly aid with hole cleaning. • Monitor wellbore for hole instability. 8.75" Interval Summary PRODUCTION INTERVAL Drilling Fluid System KLA-SHIELD Key Products POLYPAC SUPREME UL,DUO-VIS, KCL, KLA-STOP,Busan 1060,DEFOAM-X,ASPHASOL SUPREME, LOTORQ,DRILLZONE, SAFE CARB-20, SAFE CARB-40, M-I WATE,SACK BLACK,CONQOR 404WH, PolyPlus RD,&RESINEX Solids Control Shakers&Centrifuge Potential Problems Hole cleaning Loss circulation/Differential sticking Hole stability Running coals INTERVAL MUD PROPERTIES Depth MD(ft) Mud Wt. PV Yield Point API Fluid Loss Cl- LGS (ppg) (Ib/100ft2) (Ib/100ft2) (m1130min) (mg/I) (%) • 2,750-9,746' /9.0-9.6 ) 10-20 15-25 <5 14,000-33,000 <6% Ver.1.0 CONFIDENTIAL Page 7 of 17 Mg SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program NOTE: This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Production Interval Overview The production interval will be drilled to a depth of 9,746' MD using an 8.75" bit with the highly inhibitive KLA- SHIELD system at 9.0-9.6ppg containing 3-6% KCL. Wellbore stability is crucial to the interval as several coal seams will be drilled. A well maintained mud system supplemented with good solids control equipment for maximum solids removal will minimize fluid invasion. Proper drilling practices and properly engineered fluid will minimize wellbore instability. Any new fluid that is required should be built to the below specs. KLA-SHIELD Initial Drilling Fluid Formulation: Fresh Water 0.88 bbls DUO-VIS 1.0 ppb(as needed for Rheology) POLYPAC SUPREME UL 1.5—3.0 ppb 6% KCI 21.8 ppb(in base brine) KLA-STOP 8.0- 12 ppb/2.0—3.0%v/v DRILZONE 0%-2.0%As needed Busan 1060 0.49 ppb PolyPlus RD 0.5-1.0 ppb SafeCarb 20 8.5 ppb SafeCarb 40 8.5 ppb Resinex 1 ppb* Sack Black 1 ppb* Before drilling though reactive shales, additions are recommended as follows: ASPHASOL SUPREME 4—6 ppb RESINEX 2—4 ppb SACK BLACK 1 —4 ppb Production Interval Drilling Discussion • Lithology for this interval is expected to consist of sand, shale, siltstones, and coal. • Ensure that the fluid properties are maintained to provide the best possible hole cleaning. Maintain mud weights as per program guidelines and or hole conditions and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Monitor for any fluid losses and flow back closely. • If additional mud weight increases are required outside of plan, control the ROP and flow rates as needed to avoid inducing a breakdown of any formations while drilling in the lower portion of this interval. Reduce pump rates immediately if packing off occurs. Run back to bottom and establish circulation. Pump high viscosity sweeps and ream carefully to clean the hole before proceeding with Ver.1.0 CONFIDENTIAL Page 8 of 17 Mg BWACD Cook Inlet Energy,LLC NFU 2426 Fluids Program further drilling. • Adjust rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Use good drilling and tripping practices. Break circulation slowly — Reduce pump speed 15 to 20% while reaming down. Back reaming should not be utilized if possible to minimize the risk of coal seam instability. • Upon reaching casing point, watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a high viscosity /weighted sweep and observe bottoms up again. • Minimize dilution rates as much as possible by utilizing the rigs solids control equipment. Monitor screen condition closely. Ensure centrifuge is running properly and that all de-sander/de-silter cones are "Spraying"and not"Roping". Interval pore pressures may vary. Shale stability and pore pressures could require a higher or lower mud weight. Any fluid weight adjustments should be performed in 0.1 — 0.2 ppg increments using Safe Carb-40 as a weighted "spike"fluid. Production Interval Fluid Operations: • Ensure all MSDS sheets are available for the rig crews and have been reviewed. • Run corrosion ring in the drill string per M-I SWACO's corrosion mitigation program. • When building the KLA-SHIELD drilling fluids system, follow the fluid recipe and make changes as necessary to target a yield point of 15-28(Ib/100ft2). • The initial makeup will consist of 1 ppb of RESINEX and 1 ppb SACK BLACK. This will be increased while drilling ahead for hole stability and fluid loss. • Use only Busan 1060 for bacteria control. Ju Nu i use Myacide GA25 (Glutaraidenyde). • Always be aware of the condition of the cuttings as they go over the shaker. If cuttings become soft or mushy, these are signs of insufficient inhibition. Test the KLA-STOP and KCI concentrations in the system and adjust accordingly. • Maintain 2%v/v KLA-STOP in the system; monitor the concentration using the titration method. Add additional KLA-STOP as needed to maintain the proper concentration needed for inhibition. • CONQOR 404 WH additions should be made daily when drilling with KLA-SHIELD drilling fluid system in order to prevent any oxygen corrosion. Maintain a CONQOR 404 WH concentration of+/-2000 ppm or 0.15 gal/bbl. • Monitor the HTHP(@165°F) and keep below 8.0 cc/30 min (using paper). Also run a modified HTHP using a 5 micron alloxite disc, keeping fluid loss below 10.0 cc and spurt loss below 2.0 cc. • Maintain a low API fluid loss of< 5 m1/30 min. Make the necessary additions of RESINEX, Calcium Carbonate, SACK BLACK and POLYPAC SUPREME UL. • Keep MBT values below 10 ppb. • If any high torque is seen and suspected to be initiated from the formation, add LOTOTQ. Note—Be careful not to let addition of lubes mask hole cleaning problems. Also ensure that the amount being added complies with any compliance regulations. Ver. 1.0 CONFIDENTIAL Page 9 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program • If the mud weight needs to be increased past 11.5 ppg, barite sag could become an issue. (Barite sag is a reduction in the MW out due to the dynamic and static settling of barite) If the mud density is weighed up past 11.5 ppg, avoid low pump rates and low drill string rotation. Make sure and run the VSST barite sag test. • Upon reaching TD, watch the bottoms-up cuttings closely. If the well does not readily clean up after 3 — 4 bottoms up, or if there are any excess of torque, drag, pick-up or slack-off weights, pump a high viscosity I weighted sweep and observe bottoms up again. Continue pumping while rotating and reciprocating until the wellbore is clean. • Run casing to TD and do not alter the YP. After casing is landed, isolate on one pit and condition fluid in preparation for cementing per the cementing program with additions of water and CF Desco II. Be sure to isolate on one pit so only the necessary amount of fluid is being treated. • Keep track of water and whole mud additions and record daily in One-Trax. Ver.1.0 CONFIDENTIAL Page 10 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Drilling Coals: Introduction Coal is commonly encountered in gas-bearing Carboniferous. The associated drilling problems include tight hole, wash outs, stuck pipe, lost circulation, sloughing and pack off and gas influxes. Most of the problems occur when the coal is encountered at depth (i.e., is present as primarily anthracite rather than lignite). Coal formations have low density and are typically brittle, with low compressive strength, and often highly fractured. They can collapse into the borehole in areas of high tectonic stress resulting to stuck pipe. Other drilling problems in the Carboniferous include slow ROP, high torque, drag and BHA shock severity (especially if using water-based fluids) and stick-slip. These are due to the hard, abrasive nature of the sands. In some areas, both the inter- bedded shales and sands can be fractured, leading to lost circulation. Recommendations for Drilling Coal The use of Oil Based Mud (OBM) is generally preferred although water-based fluids have been used. In both cases the addition of wellbore plastering agents such as Gilsonite/ Soltex/ Asphasol Supreme/ Resinex is recommended. The fluid rheology should also be considered. It is essential to maintain adequate hole cleaning especially in high-angle wells. If the hole is not being properly cleaned, the larger coal particles may have a tendency to pack off. Coal has a low density (range 1.1-1.5 with pure anthracite = 1.5) and weighted sweeps may be very effective due to the buoyancy effect. Mud Weight Adequate mud weight should be maintained to ensure stability of the formation. The coals in the Cook Inlet area have a very "Plastic" characteristic and coal stability can be enhanced by increasing the drilling fluid weight. Care must be taken when using high mud weights to avoid exceeding the fracture gradient. Most importantly, good drilling practices should be employed together with the suggested drilling fluid solutions to achieve optimum results. The first sign of coal is normally a significant drilling break. If this occurs, the driller must pull off bottom with the pumps on and perform a flow check. Swab and surge pressures should be minimized as should the amount of time the drill string is kept static. Coal seams are notorious for washing out and this can lead to ledges developing. Care is required when tripping to avoid kicking off a new hole from the ledges. If a pack-off does occur, running back into the hole and circulating will normally clear it. Operations As with any unstable formation, it will be beneficial to minimize trips, reaming and back reaming if possible. Drilling with low WOB and high RPM and with the minimum number of stabilizers may help. Control the drilling rate to prevent overloading of the annulus if the coal is tending to break out. In extreme cases, it may be necessary to drill the coal seam in short intervals, reaming each new hole section before progressing. Experience shows that it is best to avoid sliding through coal seams and also best to maximize the angle at which the wellbore penetrates the coal seam. However the solubility of lignite is much reduced in saline fluids and no problems are seen in KCI/polymer of salt/polymer systems. Ver. 1.0 CONFIDENTIAL Page 11 of 17 Me SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Minimum Time to Circulate Prior To POOH This model simply predicts the minimum flow rate required for adequate cuttings transport. No predictions are available for the rate at which cuttings are removed. Because the cuttings move more slowly than the circulating mud, it is essential that sufficient bottoms-up are circulated prior to tripping. A SINGLE BOTTOMS-UP IS NEVER ENOUGH! The minimum on bottom circulation time prior to tripping will be influenced by hole size, inclination and flow history (i.e. mud properties and flow rate). These factors will affect the height of any residual cuttings beds. Recent work by Exxon has indicated that the volume of cuttings left behind during normal drilling operations can be considerable. They recommend selection of bits/BHAs with large bypass areas to facilitate tripping out of the hole. Before tripping, monitor the shakers to ensure the cuttings return rate is reduced to an acceptable background level. The figures in the table below are guidelines based on simple slip velocity considerations and field experience: WELL INCLINATION SECTION LENGTH FACTOR RANGE 17-112 inch HOLE 12-1/4 inch HOLE 8-1/2 inch HOLE 0°- 100 1.5 1.3 1.3 100- 300 1.7 1.4 1.4 300-600 2.5 1.8 1.6 600+ 3.0 2.0 1.7 Procedure 1. Effective length = Section length x section length factor. 2. Circulation time = Effective Length x B/U Measured depth at Bit Example Since in practice not all of the section back to surface will be deviated at the same angle, the overall minimum circulation time prior to tripping should be apportioned in direct relation to the relative lengths of section at each angle. Ver.1.0 CONFIDENTIAL Page 12 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Solids Removal Equipment Recommendations The recommended SCE for this well are: Mongoose Shakers and Variable Speed Centrifuge. Recommended shaker screens sizes are as follows: Interval Recommended Screen Sizes 200'—2,750' (Surface) 110- 165 mesh 2,750'—9,746' (Production) 200—230 mesh • Run all solids control equipment when drilling ahead. • Monitor LGS and sand content closely. • Screen up as much as possible. • Monitor screens for holes and wear. Replace screens if holes occur. Lost Circulation I Seepage Action plan • Have sufficient sized LCM on rig to begin loss interval. It takes 40 ppb of sized calcium carbonate to make a filter cake with this plugging material. Use in combination with 5 ppb SACK BLACK and MIX II at 5 ppb. • Recommend hourly addition of LCM to keep a concentration in the system at all times. The addition of SAFE-CARB (40,250,500), MIX II (cellulosic fiber), SACK BLACK (treated Gilsonite) and G-SEAL (sized graphite) can be adjusted as needed to combat losses. • The particle size of the LCM is important. If the expected loss zone particulars are known, then plan to have LCM to offer a particle size distribution so the majority of the LCM has a D50 to cover 1/3 the expected pore throat size and a D90 of cover the pore throat size. The D90 material should make up 10% of the total LCM ppb pumped. • Coordinate spotting and wait time for LCM pills if losses are over 60 bph. • The majority of losses can happen when running casing, circulating before cementing and while cementing which should be monitored closely. The use of Virtual Hydraulics Surge Calculations is recommended to establish safe casing running speeds. The use of open-float and M-I SWACO WELL COMMANDER should be considered to help minimize surge pressures to formation. • OPTIBRIDGE Software will be run while on location to develop the specific particle size distribution for the LCM materials to be used for any formations with the known tendencies for lost circulation. Ver. 1.0 CONFIDENTIAL Page 13 of 17 Mi sWACD Cook Inlet Energy,LLC NFU 2426 Fluids Program Lost Circulation Recommendations The following proactive lost circulation decision tree can be modified to include any contingencies that Cook Inlet Energy requires. The flowchart allows for planning of lost circulation material needs. Losing fluid while drilling Measure rate of loss 1 1 Seepage losses Partial losses Severe losses 5 -20 bbl/hr 20 -60 bbl/hr 60—200 bbl/hr or Total loss of returns If fault related drill across fault If fault related drill across fault If fault related drill across fault 1-1.5 times the length of the 1-1.5 times the length of the 1-1.5 times the length of the throw before treating losses throw before treating losses throw before treating losses Spot 50 ppb pill*: Spot 80 ppb pill*: G-SEAL Plus 15 ppb Contact Drilling/Asset G-SEAL Plus 10 ppb M-1-X II Med 10 ppb M-I-X II Med 10 ppb SAFE CARB 40 15 ppb Engineer for approval SAFE CARB 40 10 ppb No SAFECARB 250 25 ppb No SAFECARB 250 15 ppb success SAFECARB 500 15 ppb success SAFECARB 500 5 ppb Pump thru Well 7 Pump thru BHA Commander or BHA Spot 100 ppb pill*: M-I-XII-C 10 ppb G-SEAL Plus 15 ppb M-I-X II Med 10 ppb SAFE CARB 40 15 ppb SAFECARB 250 30 ppb SAFECARB 500 30 ppb Pump thru Well Commander 1 Squeeze high-fluid-loss pill*: FORM-A-BLOCK 35 ppb Pump thru Well Commander or BHA * Indicates that the particle sizing of these products are smaller than NUT PLUG MEDIUM Ver. 1.0 CONFIDENTIAL Page 14 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program HSE Concerns Health and Safety • Drilling crews should be instructed in the proper procedures for handling fluid products. • Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. • PPE must be in good working order and be utilized as recommended by the PPE charts. • Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. • Ensure all MSDS sheets are up to date and readily available for workers to access for information. Environmental • Ensure that all products stored outside are protected from the weather. • Do not store partial units (sacks)outside if possible. • When transferring fluids and/or cuttings from the rig to tanks, ensure all hoses are properly secured. Perform a transfer checklist as needed in order to avoid spills. Ver. 1.0 CONFIDENTIAL Page 15 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program Product Health and Safety Reference HMIS HAZARD RATINGS Product Function Health , Flammability Reactivity PPE ASPHASOL SUPREME Inhibitor 1 1 0 E Busan 1060 Biocide 3 1 1 X Caustic Soda pH Modifier 3 0 1 X CF Desco II Thinner 1 1 0 E Citric Acid pH Modifier 1 0 0 E CONQOR 404 Corrosion Control 1 1 0 J DEFOAM-X Defoamer 1 1 0 J DRILZONE Surfactant 1 1 0 E EMI-2009 Inhibitor 3 1 0 X Flowzan Viscosifier 1 1 0 E FORM-A-BLOK Lost Circulation Material 1 1 0 E GELEX Viscosifier 1* 1 0 E G-SEAL Lost Circulation Material 1 1 0 E KLA-STOP Inhibitor 3 1 0 X LOTORQ Lubricant 1 1 0 J LUBE 776 Lubricant 1 1 0 J M-I GEL Viscosifier 1* 0 0 E M-I WATE Weighting Agent 1* 0 0 E PECAN NUT PLUG Lost Circulation Material 1* 1 0 E POLYPAC SUPREME UL Fluid Loss Additive 1 1 0 E POLYPLUS RD Cuttings encapsulation 1 _ 1 0 E Potassium Chloride Inhibitor 1 0 0 E RESINEX Fluid Loss Control 2* 1 0 E SACK BLACK Filtration Control 2 1 0 E SAFECARB Bridging Agent 1* 1 0 E SAPP Thinner 1 0 0 E Soda Ash Alkalinity Control 0 0 0 E Sodium Chloride Inhibitor 0 0 0 E (HMIS)HAZARD RATING HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX 4-Severe hazard A-Safety Glasses 3-Serious hazard B-Safety Glasses,Gloves 2-Moderate Hazard C-Safety Glasses,Gloves,Synthetic Apron 1-Slight Hazard D-Face Shield,Gloves,Synthetic Apron 0-Minimal Hazard E-Safety Glasses,Gloves,Dust Respirator F-Safety Glasses,Gloves,Synthetic Apron,Dust Respirator *An asterisk next to the health rating indicates that a chronic G-Safety Glasses,Gloves,Vapor Respirator hazard is associated with the material. H-Splash Goggles,Gloves,Synthetic Apron,Vapor Respirator I-Safety Glasses,Gloves, Dust and Vapor Respirator J-Splash Goggles,Gloves,Synthetic Apron,Dust and Vapor Respirator K-Air Line Hood or Mask,Gloves,Full Suit,Boots X-Consult your supervisor for special handling directions. Ver.1.0 CONFIDENTIAL Page 16 of 17 Mi SWACO Cook Inlet Energy,LLC NFU 2426 Fluids Program t'1 0 4 0 Responsibilities • M-I Project Engineer and will coordinate daily between operator's office, rig, warehouse, and the M-1 SWACO field engineers. • Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. • Field Engineers will monitor and supervise product inventory to include re-palletizing any products for shipment to other locations at the end of the well. • Field Engineers will communicate with office personnel (Operator& M-1 SWACO)for approval of any changes in the mud program (including introduction of new products). • Field Engineers will produce a recap per hole section and at the end of the well based on daily activities. Recap should include any lessons learned that may be used to provide better service on future wells. Lessons learned can include changes in procedures, product additions, equipment usage, and/or utilization of any third party service. Ver. 1.0 CONFIDENTIAL Page 17 of 17 NFU 24-26 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 Td /1\ J Y o-, :q.r ,' _ Vl_.j,r fi SI 1 a - III°IMIIIIIIIIIIIIIIhgg2"—viwiFXW- 7,.71:: :: 1 L l r-- , fib y f I I � 1VIII_A I . ,,,,,,,, B S 01 4 , 1 Zt. II 1 e s iik SSL iiimri BOS TANK SYSTEM IV DESCRIPTION SHIPPING DIMENSIONS WORKING DIMENSIONS SHIPPING LXWXH LXWXH WEIGHT Patented Fluids Management Process 2 - 20 bbl(3.2 m3) Polymer Injection Tanks 42'3"x 12'6"x 9'4" 47'3"x 12'6"x 17'11" 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 r, www.bos-solutions.com Equipment 1.877.267.3434 Specifications Cook Inlet Energy_ RECEIVED' OCT 2 1 2014 October 20,2014 AOGCC Alaska Oil and Gas Conservation Commission Ms. Cathy Foerster, Chair 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Re: Application for Permit to Drill—Cook Inlet Energy,LLC—NFU#24-26 Ms. Foerster: Cook Inlet Energy, LLC("CIE")recently applied for a Permit to Drill an onshore gas production well, the NFU#24-26. CIE also recently submitted a request for a spacing exception for NFU #24-26 in accordance with 20 AAC 25.055(a)(4). In the past, CIE has made application for the drilling of a well that requires an exception to the spacing requirements in 20 AAC 25.055, and a Permit to Drill was approved that allowed CIE to drill the well while the public process for the spacing exception request was ongoing. This drilling was done with the understanding that CIE would not be allowed to complete or test the well until the spacing exception was granted,and there was a risk that an exception would not be granted and the well would have to be abandoned. CIE has recently been informed this practice is no longer standard and a Permit to Drill will not normally be approved until a spacing exception has been granted, if one is required. CIE understands the reasoning for this policy in areas where there is high potential for waste or correlative rights issues. However,The NFU#24-26 well is much farther from a property line where ownership or landownership changes than the 1,500 feet required by 20 AAC 25.055(a)(2). This fact makes correlative rights issues very unlikely. In addition,there are several target zones CIE intends to drill through with this well,including several that may not be in communication with any other wells completed within Section 26 or wells within 3,000 feet per 20 AAC 25.055(a)(4). This fact,coupled with other geological features of the North Fork structure,makes waste of the resource very unlikely. Longer term, CIE intends to make application to the AOGCC for pool rules in accordance with 20 AAC 25.520 to modify the standard spacing requirements in 20 AAC 25.055. This application will allow the AOGCC to fully consider all issues related to preventing waste,protecting freshwater, protecting correlative rights,and ensuring a greater ultimate recovery of oil and gas. If established by the Commission,pool rules will mostly eliminate further spacing exception requests at North Fork and allow for the efficient and timely development of the field. 601 W 5th Ave.,Suite 310,Anchorage,AK 99501 ORIGINAL For the reasons stated above, CIE respectfully requests that the Commission approve the Permit to Drill for NFU#24-26 and allow us to drill and complete,but not flow the well prior to receiving a spacing exception. If you have any questions,or need any additional information to help in your decision regarding this request,please do not hesitate to contact me. We appreciate your consideration. Sincerely, • /J David Hall CEO Date Modified:10/17/14 Date Prepared:10/16/14 Macintosh HD:users:duan:Library:caches.Temporaryltems:OutIook Temp:20141016 Letter to Foerster Re NFU 24- 26.docx Notice of Public Hearing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Re: Docket # C'0-14-026. The application of Cook Inlet Energy (CIE) for an exception to the spacing requirements of 20 AAC 25.055(a)(4) to drill and complete a development gas well in a governmental section containing wells that are, or may be capable of,producing from the same pool. CIE, by letter received October 7, 2014, requests the Alaska Oil and Gas Conservation Commission (AOGCC) issue an order under 20 AAC 25.055(d) allowing drilling and completion of onshore development gas well NFU #24-26 in the North Fork Unit within a governmental section containing wells that are, or may be capable of, producing from the same pool ' NFU #24-26 Surface Location: 648' from the south line and 1542. from the east line of Section 26, T4S, R14W, Seward Meridian (S.M.) Bottom-hole Location: 75' from the south line and 2018' from the west line of Section 26. T4S, R14W, S.M. The AOGCC has tentatively scheduled a public hearing on this application for November 18, 2014, at 9:00 a.m. at 333 W. 711 Ave., Ste 100, Anchorage, Alaska 99501. To request that the tentatively scheduled hearing be held, a written request must be filed with the AOGCC no later than 4:30 p.m. on October 23, 2014. ' If a request for a hearing is not timely filed, the AOGCC may consider the issuance of an order without a hearing. To learn if the AOGCC will hold the hearing,call 793-1221 after November 1,2014. in addition, written comments regarding this application may be submitted to the AOGCC, at 333 W. 7°1 Ave., Ste 100, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on November 12, 2014, except that, if a hearing is held, comments must be received no later than the conclusion of the November 18, 2014 hearing. lf, because of a disability, special accommodations may be needed to comment or attend the hearing, contact the AOGCC's Special Assistant,Jody Colombie, at 793-1221,no later than November 13, 2014. IllIP AACathy P. Foerster Chair, Commissioner ),' c )..._ R I .._ . V, 0U) > - ,, m & i -t ( o ,, v4 , \ a on .. X— ' ' ( i ‘L) ,° __ _ S \ '-tN a ` \'•t. ' .-4 r 0 R tM ,_ kk-------- --.... - I 0 0 -„,' ,T ) , < `1 . ., ' M N 7 1 4 fr 0 ' '''2 t: 4-: !'?N N Q J � v J ti )� a Schwartz, Guy L (DOA) From: Stephen Hennigan <shennigan@peiinc.com> Sent: Tuesday, October 21, 2014 4:17 AM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: North Fork 24-26 (PTD 214-166) Attachments: 11 143135 24-26 - RIG 37.pdf;4 CIE NFU 24-26 DrIg Opns Oct 1 2014.doc 1. No 11 is the rig layout that shows the diverter—I did not label it though—want me to? 2. In the prog it states "a minimum of 12.5 is acceptable". Should I put that anywhere else? 3. For cement,the summary and the 10-401 are correct for now. I did not send CIE any detail. 4. Do not know why you did not get it the prog. It is No3 attached. 5. Totally agree with the sundry before complete and test. 6. 7 day cycle is understandable ?4aal pa air'4aaz a Arad dap/ Stephen F. Hennigan Project Engineer/Manager 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 'a: 337-984-2603 w: 337-849-5345 (mobile) :;=:;• Petroleum .S5t. SIERRA oz.- 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. From: Schwartz, Guy L(DOA) [nailto:guy.schwartz@alaska.gov] Sent: Monday, October 20, 2014 7:32 PM To: Stephen Hennigan Cc: Davies, Stephen F(DOA) Subject: North Fork 24-26 (PTD 214-166) Steve, ,Coup of things came up in my revs, of Permit : 1. I need a map of the diverter layout on the pad. 2. What is your min LOT for drillout of the surface casing. 3. Which cement plan are you using for the surface casing(9 5/8")? The front page on the 10-401 matches page 25 summary page but not the detail provided. 4. I also do not see a drilling procedure detail anywhere... did I miss seeing it? 5. Will require a sundry to complete the well ( Run tubing and perforate) ..this PTD covered drilling and casing only. 6. Rig will be on 7 day BOP test cycle for first well at least until it has been evaluated sufficiently. 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). 2 Schwartz, Guy L (DOA) I I MI 11111111111M1 From: Schwartz, Guy L(DOA) Sent: Monday, October 20, 2014 4:32 PM To: Stephen Hennigan Cc: 'Davies, Stephen F(DOA) (steve.davies@alaska.gov)' Subject North Fork 24-26 (PTD 214-166) Steve, Couple of things came up in my review of Permit: 1. I need a map of the diverter layout on the pad. 2. What is your min LOT for drillout of the surface casing. 3. Which cement plan are you using for the surface casing(9 5/8")? The front page on the 10-401 matches page 25 summary page but not the detail provided. 4. I also do not see a drilling procedure detail anywhere...did I miss seeing it? 5. Will require a sundry to complete the well ( Run tubing and perforate) ..this PTD covered drilling and casing only. 6. Rig will be on 7 day BOP test cycle for first well at least until it has been evaluated sufficiently. 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). 1 Davies, Stephen F (DOA) From: Stephen Hennigan <shennigan@peiinc.com> Sent: Thursday, October 16, 2014 5:03 AM To: Davies, Stephen F (DOA) Subject: RE: North Fork Unit 24-26 (PTD #214-166): Comments Yessir the as-staked is correct—I mistyped it in the 401. The directional in the plan uses the x,y's from the as-staked for the surface values. And with regard to the mw,yes it is most probably we will end up with 9.2 for the surface, even though I think we can do it with 9.0 ppg. Tvri pa and kw a greed day, Stephen F. Hennigan Project Engineer/Manager 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 w: 337-984-2603 ': 337-849-5345 (mobile) 4fr 'et a a!1 SEER , r E irleers 44-4.. 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. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, October 15, 2014 7:36 PM To: Stephen Hennigan <shennigan@peiinc.com> (shennigan@peiinc.com) Subject: North Fork Unit 24-26 (PTD #214-166): Comments Collecting my comments to date regarding CIE's Permit to Drill application: 1. The surface location for the North Fork Unit 24-26 well is given on the Permit to Drill application as 650 FSL and 1750 FEL of Section 26, but on the As-Staked plat from McLane Consulting surveyors,the location is shown as 648 FSL, 1542 FEL of Section 16. I assume that the As-Staked plat is correct. 1 2. The mud program shown in the yellow-colored box under the heading Mud Program in the"Program Details with Calculations"section of the application indicates that the surface interval will be drilled with 8.8 to 9.0 ppg mud. But the Drilling Fluids Program Summary and Specifications section on page 24, displays a mud weight of 8.8 to 9.2 ppg for the interval from 0 to 2750'TVD. I assume that 8.8 to 9.2 ppg is correct for the surface hole. Please let me know if you have any questions or if I can help further. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 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. TRANSMITTAL LETTER CHECKLIST WELL NAME: A/.> 6--6-7 Ic-- !2, - 24-7 -zz PTD: . I 4" /42 / Development Service Exploratory Stratigraphic Test Non Conventional FIELD: 7J--4 I-0-) L POOL: A/6-7'�� t'7 C�'Z1 C� Th/°t''z 4 ec.. 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 is contingent upon issuance of a Spacing Exception conservation order a proving a spacing exception. (Company Name) Operator assumes th liability of an rotest to the spacin exception 70 16.2.(t- that may occur. / 7( .k c -e-74' C�" All dryditch sample sets submitted to the AOGCC must e in no reate � pg i Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 1-11 1 ToN 0) O N u) -• 3 ' is C y0' • o ( 0 co E O , u , t , , E' ' ' ' • , , CO , �. ' y, ' ' -0, O) E. (6' , O) -d ' 0 t y, c L E co t N CO 0, O. 0' O. E. a) 0) c, , v co. ; 3. ; o, 4 , c_, , , , . . F-, (/), is , c, v, ' u! N g, , a ate), , 3 °, aa ,O, ° 3, a, y '' , . vc , CO a o, a 0 , v a � vN - 0. o � Z N' (/)' . w , • N cm m' , y; v E i ' ° oNm 01 C' ° , U aEyc o , ' •N °• 0 , o ' ° ' CO ° a ' I • M' , , , >, w, co , E' 3 •; E' • o, cn, a , E' , a W N, C Z. 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North Fork Unit 24-26 Kenai Peninsula Borough, Alaska November 26, 2014 to December 18, 2014 Provided by: Approved by: Greg Kirkland Compiled by: Ralph Winkelman C r a i g S i l v a Distribution Date: January 9, 2015 NFU 24-26 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........................................................................................................................16 4 DRILLING DATA..................................................................................................................................17 4.1 Daily Activity Summary.................................................................................................................17 4.2 Surveys.........................................................................................................................................23 4.3 Bit Record.....................................................................................................................................27 4.4 Mud Record ..................................................................................................................................28 4.5 Drilling Progress Chart..................................................................................................................29 5 SHOW REPORTS ...............................................................................................................................30 6 DAILY REPORTS ................................................................................................................................31 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 24-26 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 Craig Silva 37 29 James Foradas 7 19 Ralph Winkelman 23 24 Frank Thrailkill 4 15 Dickey Hudgins 6 2 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. NFU 24-26 3 2 GENERAL WELL DETAILS 2.1 Well Objectives The objective of NFU 24-26 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 #24-26 Field: North Fork Field County: Kenai Borough State: Alaska Company Representatives: Al Lunda, Rod Maniaci, Stephen Ratcliff, Monie Sainz Location: Surface Coordinates 648 FSL 1542 FEL, Sec 26 T4S R14W SM, X = 199870 Y = 2121192 Ground Elevation 657.80’ AMSL Rotary Table Elevation 678.38’ AMSL Classification: Development Gas, Multiple Zone API #: 50 – 231 – 20045 – 00 – 00 Permit #: 214 – 166 Activity Code: AFE # 146003 Rig Name / Type: Miller #37 / Land / Telescopic Double Spud Date November 26, 2014 Total Depth Date: December 18, 2014 Total Depth 9750’ Primary Targets 4900 SD, 5600 SD, 6000 SD, 7800 SD, 8100 SD, Primary Target Depths MD/ TVD 5196’/ 4898’, 5910’/ 5577’, 6312’/ 5968’, 8280’/ 7935’, 8493’/ 8148’ 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, Craig Silva CANRIG Sample Catchers: Frank Thrailkill, James Foradas 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 16 138 137.99 12 ¼ 2946 2820.57 Beluga 9.4 24.37 9 ⅝ 2938 2813.29 13.62 8 ¾ 9750 9504.53 Tyonek 9.4 1.90 7 9725 9379.81 NFU 24-26 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 1400 1389.71 711.33 Tyonek 5000 4714.21 4035.83 4900' Sd 5196 4898.09 4219.71 Base ZOI 5230 4930.10 4251.72 4900' "B" Sd 5254 4952.71 4274.33 4900' "B" LKG 5286 4982.87 4304.49 5300' Sd 5604 5284.05 4605.67 5300' LKG 5626 5305.04 4626.69 5450' Sd 5676 5352.81 4674.43 5450' LKG 5689 5365.25 4686.87 Zone of Interest 4 5765 5437.97 4759.59 Base ZOI 5800 5471.48 4793.10 5600' Sd 5910 5576.93 4898.55 Poss LKG 5940 5605.73 4927.35 5600' "B" Sd 5988 5651.85 4973.47 5600' "B" LKG 6006 5669.16 4990.78 6000' Sd 6312 5968.60 5290.22 Poss LKG 6338 5994.35 5315.97 6100' Sd 6390 6045.99 5367.61 Poss LKG 6414 6069.84 5391.46 Zone of Interest 6 6433 6088.74 5410.36 Base ZOI 6452 6107.64 5429.26 6700' Sd 7084 6738.91 6060.53 6800' Sd 7176 6830.91 6152.53 Zone of Interest 7406 7060.90 6382.52 Base ZOI 7428 7082.90 6404.52 7200' Sd 7570 7224.89 6546.51 Mid Tyonek 7904 7558.89 6880.51 7800' Sd 8280 7934.87 7256.49 7950 Sd 8345 7999.86 7321.48 Base ZOI 8360 8014.86 7336.48 8100' Sd 8493 8147.84 7469.46 Poss LKG 8529 8183.83 7505.45 Tyonek Blue 8754 8408.77 7730.39 8500' Sd 8884 8538.74 7860.36 Top ZOI 8909 8563.74 7885.36 Poss LKG 8922 8576.74 7898.36 Base ZOI 8938 8592.74 7914.36 9000' Sd 8968 8622.73 7944.35 Base ZOI 9018 8672.73 7994.35 9100' Sd 9152 8806.72 8128.34 Base ZOI 9188 8842.72 8164.34 NFU 24-26 5 3.2 Lithology Review Tuffaceous Claystone/Tuffaceous Siltstone (2950'-3020') = medium light to light gray with light brownish gray secondary hues; soft to slightly firm; irregular shaped cuttings; silty to clayey texture; dull to earthy luster; sticky at times; moderately soluble and expansive; non calcareous. Tuffaceous Claystone/Tuffaceous Tuffaceous Siltstone (3020'-3200') = medium gray to (dominant) medium dark gray to dark gray; clays with higher ash and/or sand content range to medium light gray to light gray; common faint to locally strong brownish gray to olive gray secondary hues; brownish gray coloration often associated with higher organic/carbonaceous content; dominant soft to slightly brittle or slightly firm; very minor fraction of moderately firm/brittle to marginally hard pieces; clayey to silty to spotty ashy textures; many examples of mixed or mottled clay- silt-ash combinations; gritty textures when common to abundant floating sand grains or when grading to tuffaceous sandstone; most changes in color and texture are minor, and overall appearance is generally homogenous; most clay-silt has minor fraction of discernible glass shards; spotty pieces with abundant shards; very common pieces with black to brownish black micro-laminations and particles of coal/carbonaceous material; softer clay cuttings are often massive blebs or lumps lacking in discernible structure; firmer/more brittle claystone/siltstone is irregular to sub blocky to blocky cuttings habit with mix of "cleaner", sharper, roughly more angular edges and more rounded "edge-less" pieces; except for spotty "sandier" siltstone, nearly all non-calcareous. Coal/Carbonaceous Material/Very Carbonaceous Tuffaceous Siltstone (2950'-3350') = less abundant than the dominant tuffaceous clay/silt; often thin discreet beds within massive sections; dark gray to grayish black to brownish black to black; brittle to firm, but mostly fragile; trace coal appears marginally tough; coal textures range from smooth to very dense matte; carbonaceous mud rocks have mixed textures, but almost all display closely spaced alternating micro layers of clay-silt and coaly laminations; coal micro beds appear continuous throughout large cuttings pieces, but the other, flakier, more organic- looking carbonaceous particles are often discontinuous; note many carbonaceous micro-particles appear to be floating in a random distribution within the clay-silt; concentrations of carbonaceous particles impart a strong grayish black to brownish black color. Tuffaceous Claystone/Tuffaceous Siltstone (3200'-3600') = medium gray to dominant medium dark gray to dark gray; higher ash/shard content rocks range to medium light and light gray; common faint to spotty strong brownish gray to olive gray secondary hues; brownish and blackish colorations are associated with higher organic/carbonaceous content; dominant soft to slightly brittle or slightly firm; lesser fractions of moderately firm/brittle to marginally hard pieces; clayey to silty to spotty ashy textures; many examples of mixed or mottled clay- silt-ash combinations; gritty textures when common to abundant floating sand grains or when grading to tuffaceous sandstone; changes in colors and textures are minor, so overall appears fairly homogenous; nearly all clay/silt has minor fraction of discernible glass shards; spotty pieces with abundant shards; very common pieces with black to brownish black micro-laminations and particles of coal/carbonaceous material; softer clay cuttings are often massive blebs or lumps lacking in discernible structure; firmer, more brittle claystone-siltstone has irregular to sub blocky to blocky cuttings habit that occasionally displays "cleaner, sharper”, roughly more angular edges and more rounded "smoothed" pieces; except for very minor sandier siltstone, nearly all claystone-siltstone is non- calcareous. NFU 24-26 6 Tuffaceous Sandstone/Non-Differentiated Sandstone/Sand (3400'-3800') = the abundant tuffaceous sandstone is a more winnowed variation of the same lithology as the very sandy tuffaceous claystone; trace to spotty sandstone is much more winnowed and has very little inter-grain ash; note that there is no significant color difference between the tuffaceous sandstone and the tuffaceous claystone-siltstone; medium gray to dominant medium dark gray to dark gray with strong brownish gray and olive gray secondary hues; a large fraction of the sandstones with less inter-grain clay and ash have colorless to very pale gray quartz and glass grains supported by a generally dark gray matrix with distinctive faint mixed colorations; some sandstone, is supported by grayish brown tuffaceous silt, and its matrix includes distinctive pale yellowish gray lithic grains of devitrified ash; very abundant tuffaceous sandstone has a grain size that ranges from coarse silt (40 microns) to fine lower (140 microns), and within this very fine mode is a spotty-second mode of larger floating grains to medium lower; mostly well sorted, but many individual cuttings fragments display significant mixing of silt, clay and a range of sand sizes; angular to subrounded; discoidal to subspherical; grain dimension is very dominantly equant to slightly elongate; mostly non-calcareous; individual sandstone pieces are moderately calcareous; rare individual cuttings pieces of grain-supported non-tuffaceous sandstone with calcite cementation; some lithic devitrified ash grains are calcite and silica replaced; very clayey-silty-ashy sublithic arenite; estimate 70-85% quartz and volcanic glass, tr-10% feldspar, 10-20% lithics (especially meta-lithics) and mafic minerals. Tuffaceous Claystone/Tuffaceous Siltstone (3600'-3900') = medium gray to dominant medium dark gray to dark gray; higher ash/shard content rocks range to medium light and light gray; common faint to spotty strong brownish gray to olive gray secondary hues; brownish and blackish colors are associated with higher organic/carbonaceous content; dominant soft to slightly brittle or slightly firm; minor fractions of moderately firm/brittle to marginally hard; clayey to silty to spotty ashy textures; soft clays commonly have soft matte texture; many cuttings pieces display mixed or mottled clay-silt-ash combinations, and gritty textures are common when the concentration of floating sand grains increases; some carbonaceous siltstone is locally slightly micro-micaceous in part. Sandstone (3860'-3920') = present in trace to minor amounts in dominantly tuffaceous claystone/siltstone formation; medium dark gray with greenish gray secondary hue, weak salt and pepper appearance, individual grains dominantly dark gray to greenish gray to black, trace clear quartz; very fine upper to fine upper; angular to subangular; moderately well sorted; spotty moderately to very calcareous marginally hard (crunchy) cementation. Tuffaceous Claystone/Tuffaceous Siltstone (3910'-4000') = medium gray with medium dark gray and brownish gray secondary hues; soft to firm; irregular shaped cuttings; silty to clayey texture dull luster; hydrophilic; moderately soluble and expansive; poor cohesiveness fair adhesiveness; trace dark brown to black micro-thin carbonaceous laminations and inclusions/particles; non calcareous Sand (3970'-4040') = medium gray to medium dark gray overall; individual grains dominantly medium to dark gray, black, greenish gray and clear to translucent quartz and volcanic glass; very fine up- per to trace medium upper, dominantly fine; angular to subangular; moderately well sorted; disaggregated; apparent clay supported very sandy fraction within massive clay-silt rocks. Tuffaceous Claystone/Tuffaceous Siltstone (4030'-4120') = medium gray to medium dark gray; soft to slightly firm; irregular to shapeless cuttings; mushy; silty to clayey texture; dull luster; hydrophilic; poor cohesiveness; fair to good adhesiveness; non calcareous. NFU 24-26 7 Tuffaceous Sandstone/Non-Differentiated Sandstone/Sand (4040'-4400') = > 90% of tuffaceous sandstone is grainier, more winnowed gradation of very sandy tuffaceous claystone; trace to spotty sandstone may have undergone longer phases of winnowing, since only patchy amount of intergrain ash is present; very clayey tuffaceous sandstone has many of the same soft-rock characteristics as the tuffaceous claystone/siltstone; medium gray to dominant medium dark gray to dark gray with strong brownish gray and olive gray secondary hues; a distinctive variation of the winnowed sandstones is colorless to very pale gray quartz and glass grains supported by a dark gray matrix with trace flecks of other colors; trace sandstone supported by grayish brown tuffaceous silt, and displays distinctive pale yellowish gray lithic grains of devitrified ash; dominant range from coarse silt (50 microns) to fine lower (160 microns); minor fractions of larger floating grains to medium lower; mostly well sorted; many individual cuttings fragments display significant mixing of silt/clay and sand; angular to subrounded; discoidal to subspherical; dominant equant grain dimensions, but common quartz grains slightly elongate; mostly non-calcareous, but individual sandstone pieces are moderately calcareous; trace individual pieces of grain-supported non-tuffaceous sandstone with calcite cementation; lithic devitrified ash grains are often calcite and silica replaced; very clayey-silty-ashy sublithic arenite; estimate 70-80% quartz and volcanic glass, 5-10% feldspar, 15-20% lithics and mafic minerals; lithics fraction is dominated by medium to dark gray phyllite and argillite rock fragments; coal lithics are discernible in many sandstone cuttings pieces. Tuffaceous Claystone/Tuffaceous Tuffaceous Siltstone (4120'-4600') = medium gray to (dominant) medium dark gray to dark gray; higher ash content clays range to medium light gray and light gray; increasingly common clay-silt with strong olive gray to brownish gray, and sometimes bluish gray secondary hues (suggesting subtle overall changes in lithology); note that diffuse brownish gray to brownish black colorations in all rocks are progressively becoming more defined (suggesting gradual changes in depositional environment); also note that more of the clay-silt has a slightly stronger reaction to HCl; soft to slightly brittle or slightly firm; very minor fraction is moderately firm/brittle to marginally hard; clayey to silty to spotty ashy textures; many examples of mixed or mottled clay-silt-ash combinations; gritty textures when common to abundant floating sand grains or when grading to tuffaceous sandstone; most changes in color and texture are minor, and overall appears fairly homogenous; variable fractions of discernible glass shards in the clay-silt; spotty pieces with abundant shards; very common pieces with black to brownish black micro-laminations and particles of coal/carbonaceous material; softer clay cuttings are commonly massive blebs or lumps without discernible structure; firmer/ more brittle claystone/siltstone cuttings have an irregular to sub blocky to blocky habit; cuttings are further characterized as a mix of pieces with "cleaner", sharper, roughly more angular edges and pieces which are more rounded and "edge-less"; local "sandier" slightly calcareous siltstone has a moderate effervescence in HCL; note that and increasing amount of claystone also is slightly calcareous. Coal/Carbonaceous Shale/Carbonaceous Material/Very Carbonaceous Tuffaceous Claystone (4100'-4700') = all carbonaceous rocks, especially the non-differentiated carbonaceous material previously described as a blackish brownish claystones, are becoming a more distinctly separate lithology; Coal: black to brownish black; brittle and fragile to brittle and tough to marginally hard; smooth to very dense matte texture; dominantly platy to irregular cuttings habit; diverse range of coal fracture types; the dominant type is irregular, slightly platy and slightly hackly; minor variations include: splintery-sub splintery, sub conchoidal to trace conchoidal, various blocky forms and spotty birdeye fracture; abundant fragments have alternate micro thin laminae of different coal grades, and/or softer carbonaceous material and/or volcanic ash; common floating sand grains in softer carbonaceous material; some of the brown very carbonaceous claystones appear more "compacted", especially if adjacent to coals. Sand (4740'-4800') = medium to medium dark gray with dark greenish gray secondary hues overall, individual grains dominantly medium to dark gray, black, greenish gray and clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; fair to good sorting; disaggregated; non calcareous. NFU 24-26 8 Tuffaceous Claystone/Tuffaceous Siltstone (4800'-4860') = medium gray to medium dark gray with light to medium brownish gray and olive gray secondary hues; irregular cuttings habit; silty to clayey texture; dull to earthy luster; hydrophilic, poor cohesiveness, fair adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and particles; trace thin coal/carbonaceous shale beds throughout. Coal/Carbonaceous Shale (4860'-4920') = black with dark brownish black secondary hues; firm to hard and brittle; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth texture; resinous to earthy luster; weak trace outgassing bubbles from large fragments; occurs as thin beds within dominantly tuffaceous claystone/siltstone formation that also has interbedded sands. Sand/Sandstone (4920'-4980') = medium dark gray overall with individual grains dominantly medium to dark gray, black and trace clear to translucent quartz and volcanic glass; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well sorted; dominantly disaggregated with trace dark gray to black sandstone; hard; fine to medium lower; very calcareous cement. Tuffaceous Claystone/Tuffaceous Siltstone (4980'-5050') = medium to medium dark gray with medium light gray and light olive secondary hues; soft to firm to mushy at times; irregular shaped cuttings; silty to clayey texture; dull, earthy to slightly greasy luster; hydrophilic; poor cohesiveness, fair adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and particles; trace light gray to light olive gray siltstone grades between silty sandstone and sandy siltstone; trace thin coal beds. Tuffaceous Sandstone/Sand (5050'-5110') = medium light gray with light yellowish gray secondary hues overall with individual grains dominantly light to medium gray, dark gray, black and clear to translucent; pulverulent; fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; very loosely consolidated with ashy matrix. Very Calcareous Tuffaceous Claystone/Tuffaceous Siltstone (5110'-5200') = medium to medium dark gray with light to medium brownish gray and olive gray secondary hues; irregular shaped cuttings; silty to clayey texture; dull to greasy to waxy luster; hydrophilic; moderately soluble and expansive; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Tuffaceous Sandstone/Sand (5170'-5230') = medium light gray with light brownish gray secondary hues; dominant individual grains clear to translucent quartz and volcanic glass, light to dark gray, black and greenish gray; irregular habit; fragile; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; very loose ashy matrix support; non to slightly calcareous. Tuffaceous Sandstone/Sandstone/Sand (5230'-5490') = dominantly medium gray with very strong olive gray to light olive gray, strong pale yellowish brown and faint pale yellowish gray secondary hues; localized shifts in lightness value to light medium gray and occasionally medium dark gray; locally olive gray to light olive gray is dominant over other gray colors; note uneven distribution of matrix volcanic ash often creates a mottled, "chunky" mix of light and dark colors; very dominant moderately well to locally well sorted near fine upper-medium lower boundary; consistent minor fraction of fine lower to very fine glass shards are present as both disaggregated loose grains fluvially winnowed from re-distributed volcanic ash and also as a major intergrain constituent of the ash matrix itself; trace to spotty large floating grains up to granule size in finer sand; sand grains dominantly equant dimensions, subangular, and subspherical to subdiscoidal, but wide range of grain characteristics (especially higher angularity) in lesser amounts; very abundant volcanic ash matrix support, spotty to locally abundant grain supported with calcite cementation, and also abundant sandstone with complex inter-grain make-up that includes: ash-clay-silt matrix, calcite-silica and siderite cementation, devitrified ash, calcareous devitrified ash, siderite, carbonaceous material, various replacement and weathering minerals and distinctive marginally- altered traces of ignimbrite; overall very ashy sublithic to near lithic arenite; note distinctive lithic rock fragments include: argillite-phyllite, grayish yellow-orange lithic calc tuff and trace variegated greenstones. NFU 24-26 9 Coal/Carbonaceous Shale (5490'-5570') = black with dark brownish black secondary hues; firm to hard and brittle; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth texture; resinous to earthy luster; weak trace outgassing bubbles from large fragments; coal commonly grades to a dark brown carbonaceous shale. Tuffaceous Claystone/Tuffaceous Siltstone (5570'-5640') = medium to medium light gray with brownish gray and light yellowish gray secondary hues; soft to slightly firm; irregular with trace pdc bit action shaped cuttings; silty to clayey; dull to earthy luster; hydrophilic; moderately soluble and expansive; poor to fair cohesiveness and adhesiveness; non calcareous; siltstone commonly grades between sandy siltstone and silty sandstone; medium light to light gray; fragile to pulverulent; non to slightly calcareous. Sand (5640'-5700') = medium gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, trace dark gray and black; very fine lower to fine upper, dominantly fine; angular to subangular; moderately well sorted; dominantly disaggregated with trace light greenish gray sandstone with a salt and pepper appearance; hard; fine; angular to subangular; very calcareous cement; trace thin coal beds. Sand/Sandstone/Tuffaceous Sandstone (5700'-5780') = medium to medium light gray with light brownish gray and light yellowish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and light green to greenish gray; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; very loosely consolidated with ashy matrix; very fragile and pulverulent; non calcareous for crunchy, fragile fragments; calcareous cement for harder pieces. Tuffaceous Claystone/Tuffaceous Siltstone (5780'-5830') = medium gray with light brownish gray and light olive gray secondary hues; firm; irregular to wedge-like; silty to clayey texture; dull to earthy luster; poor adhesiveness; fair to good cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Tuffaceous Claystone/Tuffaceous Siltstone (5830'-5890') = medium gray with light gray, brownish gray and light yellowish gray secondary hues; soft to slightly firm; irregular shaped cuttings; silty to clayey; dull to earthy luster; fair to good cohesiveness, poor adhesiveness; non-calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace thin coal beds. Sand/Sandstone/Tuffaceous Sandstone (5890'-5960') = medium to medium light gray with light brownish gray and light yellowish gray secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and light green to greenish gray; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; very loosely consolidated with ashy matrix; very fragile and pulverulent; dominantly non calcareous with trace very calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (5960'-6010') = medium gray with light brownish gray and light olive gray secondary hues; firm; irregular with trace bit action shaped cuttings; silty to clayey to slightly gritty texture; dull to earthy luster; poor adhesiveness fair to good cohesiveness; dominantly non- calcareous; trace dark brown to black carbonaceous laminations and inclusions. NFU 24-26 10 Tuffaceous Sandstone/Sandstone/Sand (5960'-6300') = medium gray with very strong pale yellowish brown and strong to faint olive gray to light olive gray secondary hues; moderately well sorted at fine upper to medium lower; range from very fine lower to medium upper with trace to spotty larger clasts to granule size; very fine fraction mostly glass shards winnowed from volcanic ash; grains are equant to very slightly prismoidal; angular to rounded; very dominantly subangular to subrounded; discoidal to rounded, dominant subdiscoidal to slightly subspherical; consistent traces of sharp angular clear quartz; consolidated sandstones are weak and fragile and easily disaggregate to loose sand; both matrix and grain supported; spotty "clean-looking" non-differentiated sandstone with both powdery and microcrystalline calcite cementation; all other sandstone, though dominated by volcanic ash, has complex intergrain make-up that includes: ash-clay-silt, major calcite-minor silica cementation, siderite cementation, devitrified ash, calcareous devitrified ash, carbonaceous material, weathering and replacement minerals, powdery calcite, winnowed microshards and altered trace remnants of ignimbrite; overall very clayey-ashy sublithic arenite to marginal lithic arenite; estimate 60-70% quartz and minor fraction of volcanic glass, 10- 15% various (chalcedony, chert) cryptosilica and other non-differentiate silica, trace-10% feldspar, 15-20 lithics and mafic minerals; dominant lithics are dark gray to grayish black phyllite and argillite rock fragments, distinctive trace to spotty greenstone fragments and minerals, trace various micas and distinctive trace of very pale yellowish orangish brown devitrified ash. Coal/Carbonaceous Shale (5600'-6400') = black to brownish black; brittle and fragile to brittle and tough; spotty marginally hard; smooth to very dense matte texture; dominantly platy to irregular cuttings habit and diverse fracture; fracture is dominantly irregular, slightly platy and slightly hackly; note lesser examples of splintery-sub splintery, sub conchoidal to conchoidal, common birdeye and various forms of blocky fracture; many examples of alternate layering of different coal grades and micro-thin laminae of other lithologies, especially volcanic ash; some of the more massive coal has floating sand grains; note some coal fragments displayed faint iridescent sheen on broad surfaces; only traces of visible outgassing from larger coal pieces. Tuffaceous Claystone/Tuffaceous Siltstone (6400'-6450') = medium gray with light gray, brownish gray and light yellowish gray secondary hues; soft to slightly firm; irregular cuttings; silty to clayey; dull to earthy luster; fair to good cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations. Sand/Sandstone/Tuffaceous Sandstone (6450'-6520') = medium to medium light gray with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, greenish gray and black; very fine lower to fine upper; angular to subangular; moderately well sorted; sandstone hard to brittle; consolidated with very calcareous cement; tuffaceous sandstone is fragile with yellowish gray and greenish gray ash supporting matrix; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (6520'-6580') = medium to medium light gray with light brownish gray and light olive gray secondary hues; irregular, wedge-like cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; poor adhesiveness, fair cohesiveness; soft to very firm, spotty hard and brittle; trace dark brown to black micro-thin carbonaceous laminations and particles. Sand/Sandstone/Tuffaceous Sandstone (6580'-6650') = medium to medium light gray with light brownish gray and light yellowish gray secondary hues; individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and light green to greenish gray; very fine upper to medium upper, dominantly fine; angular to subangular; moderately well sorted; very loosely consolidated ashy matrix. Tuffaceous Claystone/Tuffaceous Siltstone (6650'-6710') = medium to medium light gray with brownish gray and light olive gray secondary hues; soft and fragile to moderately firm; irregular shaped cuttings common; silty to clayey to slightly gritty; dull earthy to waxy luster; non calcareous; light gray siltstone commonly grades between silty sandstone and sandy siltstone; trace grayish white tuff; very fragile; very calcareous. NFU 24-26 11 Tuffaceous Sandstone (6710'-6800') = medium light gray to light gray with strong to faint light yellowish gray, light olive gray, light brownish gray hues; abundantly appears mottled with higher lightness value very light gray to grayish white ash and spotty medium gray to greenish gray altered ash; also has "dirty" salt and pepper appearance; moderately well sorted at fine upper to medium lower; equant, more subrounded than subangular, roughly equal fractions of subspherical and subdiscoidal; abundant volcanic ash matrix support and lesser grain support; 90% is very calcareous; matrix material has clayey consistency; many cuttings pieces are compacted, tightly crenulated bit-metamorphosed shapes; ashy sublithic arenite; lithics fraction includes clastic coal micro-fragments. Tuffaceous Sandstone/Sandstone/Sand (6800'-7100') = medium gray with very strong pale yellowish brown and strong to faint olive gray to light olive gray secondary hues; moderately well sorted at fine upper to medium lower; range from very fine lower to medium upper with distinctive traces of larger clasts to granule size; very fine grains largely glass shards winnowed from vitric ash; grains are dominantly equant to very slightly prismoidal; angular to rounded; very dominantly subangular to subrounded; discoidal to rounded; dominant subdiscoidal to slightly subspherical; well scattered trace of sharp angular clear quartz; consolidated sandstones are weak and fragile and easily disaggregate to loose sand; both matrix and grain supported; spotty "cleaner-looking" non-differentiated sandstone displays both powdery and microcrystalline calcite cementation; all other sandstone, though designated as tuffaceous, has complex inter-grain make-up that includes: ash-clay-silt, major calcite-minor silica cementation, siderite cementation, devitrified ash, calcareous devitrified ash, carbonaceous material, weathering and replacement minerals, powdery calcite, winnowed micro-shards and altered trace remnant ignimbrite; overall very clayey-ashy sublithic arenite to marginal lithic arenite; estimate 60-70% quartz and minor fraction of volcanic glass, 10-15% various (chalcedony, chert) crypto-silica and other non-differentiated silica, trace-10% feldspar, 15-20 lithics and mafic minerals; dominant lithics are dark gray to grayish black phyllite and argillite rock fragments, distinctive trace to spotty greenstone fragments and minerals, trace various micas and distinctive trace of very pale yellowish orangish brown devitrified ash. Coal/Carbonaceous Shale (6400'-7200') = black to brownish black; brittle and fragile to brittle and tough; spotty marginally hard; smooth to very dense matte texture; dominantly platy to irregular cuttings habit; diverse fracture is dominantly irregular, slightly platy and slightly hackly, with lesser amounts of splintery- sub splintery, sub conchoidal to conchoidal, common birdeye and various blocky forms; very abundant fraction of coal displays alternate layering of different coal grades and/or micro thin laminae of adjacent lithologies; appears that nearly all coal margins are very thinly interbedded with volcanic ash; many coal fragments have floating sand grains, and trace pieces have very distinctive floating grains of lithic devitrified ash, siderite fragments, and other lithics; traces coal pieces with slow visible outgassing. Tuffaceous Claystone/Tuffaceous Siltstone (7220'-7300') = medium light to light gray with light brownish gray and light olive gray secondary hues; firm and brittle to soft and fragile; irregular to wedge like cuttings; silty to clayey to slightly gritty texture; dull to earthy luster; poor adhesiveness, fair to good cohesiveness; non calcareous; trace to common dark brown to black micro thin laminations and inclusions; light brownish gray siltstone commonly grades between sandy siltstone and silty sandstone; abundant thin coals throughout. Sand/Sandstone/Tuffaceous Sandstone (7300'-7380') = medium to medium light gray with a moderate salt and pepper appearance; individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, greenish gray and black; very fine lower to fine upper; angular to subangular; moderately well sorted; sandstone hard to brittle; well consolidated with very calcareous cement; tuffaceous sandstone is fragile with yellowish gray and greenish gray ash supporting matrix; non calcareous; abundant coal beds throughout interval. NFU 24-26 12 Tuffaceous Claystone/Tuffaceous Siltstone (7380'-7460') = medium to medium light gray with brownish gray and light olive gray secondary hues; soft and fragile to moderately firm; irregular shaped cuttings common; silty to clayey to slightly gritty; dull earthy to waxy luster; poor adhesiveness fair to good cohesiveness; non calcareous; trace dark brown to black micro- thin carbonaceous laminations and inclusions; light yellowish gray siltstone grades between sandy siltstone and silty sandstone; firm to fragile; non calcareous; trace thin coal beds. Coal/Carbonaceous Shale (7460'-7520') = black with dark brownish black secondary hues; firm to hard and brittle; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth texture; resinous to earthy luster no outgassing observed; present as thin (2'-5') beds throughout interval; coal occasionally grades to a dark brown carbonaceous shale/siltstone. Tuffaceous Claystone/Tuffaceous Siltstone (7520'-7580') = medium to medium light gray to brownish gray with light olive gray and light yellowish gray secondary hues; soft and fragile to moderately firm to hard; brittle at times; irregular to wedge like; silty to clayey; dull to earthy luster; poor adhesiveness fair to good cohesiveness; trace dark brown to black micro thin carbonaceous laminations and inclusions; non calcareous; light brownish gray siltstone grades to silty sandstone. Tuffaceous Siltstone/Tuffaceous Claystone (7580'-7780') = brownish gray to medium dark; many local close variations of grayish and brownish secondary hues, many subtle variations in lightness value; range from soft to moderately firm or brittle; most is very slightly firm/brittle; wide variations overall mixing and gradations of silt-clay-ash content; nearly all derived from varying degrees of re-deposition and re-working over time of original vitric air-fall volcanic ash; soft clays are at least soluble in part; when hydrated have mostly moderate cohesiveness and poor to moderate adhesiveness; firmer, more brittle cuttings have mostly irregular to sub blocky cuttings habit, but can be platy and slightly splintery; silty to clayey to various soft matte textures and some may display a rock fabric that suggest remnant vitriclastic texture; occasional gritty texture when transitional to tuffaceous sandstone; dominantly earthy luster, but some of ashier rocks have soft "glassy' look; many examples of floating grains and particles and carbonaceous material; very common to abundant micro-thin carbonaceous laminations. Coal/Carbonaceous Shale (7780'-7840') = black with dark brownish black secondary hues; firm to hard and brittle; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth texture; resinous to earthy luster no outgassing observed; coal commonly grades to a dark brown carbonaceous shale/siltstone. Tuffaceous Sandstone (7840'-7900') = very light gray to light grayish white with light yellowish gray and light greenish gray secondary hues and strong salt and pepper appearance; fragile and pulverulent; irregular shaped cuttings common; non- to moderately calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and greenish gray; very fine lower to fine upper; angular to subangular; well sorted; supported in fragile ash matrix; sparkly luster from glass shards. Tuffaceous Claystone/Tuffaceous Siltstone (7900'-7970') = medium to medium light gray to medium brownish gray with light brown and light olive gray secondary hues; irregular to wedge like; silty to clayey texture; earthy luster; poor adhesiveness; fair to good cohesiveness; trace dark brown to black micro thin carbonaceous laminations and inclusions; non calcareous. Tuffaceous Sandstone/Sandstone/Sand (7970'-8030') = multicolored, dominantly very light gray to light grayish white with light yellowish gray and light greenish gray secondary hues and strong salt and pepper appearance; fragile and pulverulent; common irregular shaped cuttings caused by PDC bit shearing action; ashy matrix dominantly non calcareous; trace very calcareously cemented sandstone; hard to brittle; fine grain; angular to subangular. NFU 24-26 13 Coal/Carbonaceous Shale (8030'-8090') = black with dark brownish black secondary hues; firm to hard and brittle; blocky to platy; massive; planar fracture dominant with trace conchoidal and birdeye; smooth texture; resinous to earthy luster; no outgassing observed; coal commonly grades to a dark brown carbonaceous shale/siltstone; silty; soft to firm; irregular shaped. Tuffaceous Claystone/Tuffaceous Siltstone (8090'-8150') = medium light gray to light brownish gray and light olive gray; irregular shaped cuttings; silty to clayey texture; dull to earthy to slightly waxy luster; moderately hard and brittle to soft and pulverulent; poor adhesiveness; fair to good cohesiveness; non calcareous; light yellowish gray siltstone; firm to fragile; commonly grades between silty sandstone and sandy siltstone; trace dark brown to black micro-thin laminations and inclusions. Tuffaceous Claystone/Tuffaceous Siltstone (8150'-8210') = medium to medium light gray to medium brownish gray with light brown and light olive gray secondary hues; irregular to wedge like cuttings caused by PDC bit shearing action; silty to clayey texture; earthy luster; poor adhesiveness; fair to good cohesiveness; trace dark brown to black micro-thin carbonaceous laminations and inclusions; non calcareous; trace light yellowish gray siltstone grades to silty sandstone Tuffaceous Sandstone (8210'-8320') = very light gray to light grayish white with light brownish gray and very light greenish gray secondary hues and strong salt and pepper appearance; fragile and pulverulent; irregular shaped cuttings common; moderate to very calcareous; individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black and greenish gray; very fine lower. Coal/Carbonaceous Shale (8320'-8380') = black with trace brownish black secondary hues; very firm to hard; brittle at times; platy to flaky; planar fracture dominant with trace conchoidal and birdeye present; vitreous to occasionally earthy luster; smooth to rarely silty texture; bituminous; very well developed trace weak outgassing bubbles observed; coal grades to a dark brown, carbonaceous shale; silty; firm to fragile. Sandstone/Tuffaceous Sandstone/Non-Differentiated Sandstone/Sand (8380'-8490') = tuffaceous sandstone characteristics are consistent with descriptions up-section; sandstone: medium light gray to light gray, faint light olive gray to very faint orangish gray secondary hues; dominantly moderately well sorted at fine upper to medium lower; equant grains, subangular to subrounded, subspherical to subdiscoidal; despite overall general increase in roundedness, there is a persistent mode of angular to very angular quartz; note very faint orangish gray coloration on many grains may be iron oxide staining; "crunchier" than soft ash-clay sandstone; calcite mineral cementation and other soft powdery inter-grain calcite are easily discernible; note increase in "clean" grain-supported sandstones that lack inter-grain ash. Sand (8490'-8550') = 95% disaggregated loose grains; light gray to very light gray with white specks; very faint light olive gray secondary hue; moderately well sorted overall within fine lower to medium lower; appears subtle fining upward through interval; range from angular to rounded, and discoidal to spherical; slightly dominant are grains with equant dimensions that are subrounded to subspherical; overall, there is spotty calcite, and ashy material is only present as specks; between sublithic arenite and lithic quartz arenite; note increased ratio of quartz to glass shards; trace lithics fraction displays increased diversity, there is a wider range of minerals overall, greenstone rock fragments are more distinctive, and there are well-distributed traces of red to reddish orange jasper and greenish yellow epidote. NFU 24-26 14 Tuffaceous Siltstone/Tuffaceous Claystone (8150'-8750') = brownish gray to medium dark; many local close variations of grayish and brownish secondary hues and many slight variations in lightness value; very abundant slight to moderately firm or brittle; ranges from soft to trace marginally hard; diverse sediment mixing and gradations are evident; these tuffaceous rocks represent varying degrees of re- deposition, re-working and re-composition after an origin as vitric air-fall volcanic ash; soft clays are at least partially soluble; hydrated clays have moderate cohesiveness and poor to moderate adhesiveness; firmer, more brittle cuttings have mostly irregular to sub blocky cuttings habit, but can be platy and slightly splintery; silty to clayey to various soft matte textures and occasionally remnant secondary vitriclastic textures not entirely destroyed during re-deposition; occasional gritty texture if transitional to tuffaceous sandstone; dominantly earthy luster, but some of ashier rocks have soft "glassy' look; many examples of floating grains and particles, especially of carbonaceous material; very common to abundant micro-thin carbonaceous laminations. Coal/Carbonaceous shale (8750'-8830') = black with trace brownish black secondary hues; very firm to hard; brittle at times; platy to flaky; planar fracture dominant with trace conchoidal and birdeye present; vitreous to occasionally earthy luster; smooth to rarely silty texture; bituminous; energetic trace of weak outgassing bubbles observed; coal grades to a dark brown, carbonaceous shale; silty; firm to fragile. Tuffaceous Sandstone/Sandstone/Sand (8830'-8890') = multicolored, dominantly very light gray to light grayish white with light yellowish gray and light brownish gray secondary hues and strong salt and pepper appearance; fragile and pulverulent; irregular with cuttings; ashy matrix dominantly non calcareous; trace very calcareous cemented sandstone; hard to brittle; fine grain; angular to subangular. Conglomerate/Conglomeratic Sand/Sand/Tuffaceous Sandstone/Sandstone (8885'-9015') = bulk color is light gray to very light gray with many light brown secondary hues and abundant white blebs from fragile; local salt and pepper appearance, very loosely supporting pulverulent ashy matrix; medium light gray (sand) to light gray (tuffaceous sandstone) and abundant variegated gray (conglomerate); note prominent specks of other colors and differences in transparency; larger individual grains include colorless to very pale gray translucent to transparent quartz, trace "mega-shards" of volcanic glass, light to medium gray translucent to opaque crypto-silica, variegated light greenish gray meta-lithic greenstones and distinctive trace to rare dusky red (jasper), orange (meta-volcanics), greenish yellow (epidote) and sparkly clear micro-shards; poorly sorted overall from very fine upper to very coarse upper with spotty to locally abundant granule-pebble fragments to 4mm; inter-layered, inter-zoned sandstone and massive sand are dominantly fine upper to medium lower and moderately well sorted; all modes of roundedness and shape are noted in either major, minor, or trace percentages; sand continues to be dominantly angular to subangular, and subdiscoidal to subspherical; roughly equal fractions of very calcareous (from both mineral cementation and matrix powder) and non-calcareous rocks; note traces of hard sandstone; there are both abundant very sharp bit-broken conglomerate fragments and very common unbroken well rounded and smooth conglomerate granules-pebbles; rare consolidated conglomerate has siliceous hard lithic sandstone clasts. Coal (9050'-9160') = black with brownish black secondary hues; hard to brittle platy to flaky; planar fracture dominant with trace conchoidal and birdeye fracture present; vitreous to occasionally earthy luster; smooth to rarely silty texture; bituminous; very well developed no to very weak trace outgassing bubbles observed. Tuffaceous Sandstone/Sand/Tuff (9160'-9220') = very light gray to white with a moderate to strong salt and pepper appearance; irregular shaped cuttings; silty to gritty; sparkly luster; very fragile to pulverulent; non calcareous; ash acts as supporting matrix for loosely supported sands; light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray; very fine lower to coarse upper, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting. NFU 24-26 15 Tuffaceous Siltstone/Tuffaceous Claystone (9220'-9280') = medium light to light brownish gray to brownish gray with brown secondary hues; soft to slightly firm; irregular to tabular cuttings; silty to clayey texture; dull, earthy to waxy luster; fair cohesiveness, poor adhesiveness; non calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions. Coal/Carbonaceous Shale (9280'-9340') = black with trace brownish black secondary hues; very firm to hard; brittle at times; platy to flaky; planar fracture dominant with trace conchoidal and bird- eye present; vitreous to occasionally earthy luster; smooth to rarely silty texture; sub-bituminous; no outgassing observed. Tuffaceous Sandstone/Sand (9220'-9360') = very light gray to white with salt and pepper appearance and light brownish gray, light olive secondary hues; silty to gritty; sparkly luster; very fragile to pulverulent; non to moderately calcareous; ash matrix supporting structure; loose disaggregated sand is light gray to medium gray; individual grains dominantly clear to translucent quartz and volcanic glass; very fine lower to coarse upper, dominantly fine lower to medium lower; angular to subangular; poor to moderate sorting Tuffaceous Siltstone/Tuffaceous Claystone (9280'-9750') = no significant changes in characteristics for last 1300' of hole; medium gray to medium dark gray with many subtle variations of grayish and brownish secondary hues, and many slight variations in lightness value; dominantly slight to moderately firm or brittle; range from soft to trace marginally hard; very diverse mixing of volcanic ash derived sediments and many gradations of lithology types; soft tuffaceous claystones are at least partially soluble; hydrated clays display moderate cohesiveness and poor to moderate adhesiveness; firmer and more brittle silt-clay cuttings are mostly irregular to sub blocky, but also common platy and slightly splintery; silty to clayey to various soft matte textures, and trace remnant vitriclastic texture; often gritty in part when transitional to tuffaceous sandstone; pervasive earthy luster; ashier rocks often have soft "glassy" appearance; micro- laminations and floating grains and particles, especially of carbonaceous material, are generally abundant. Tuffaceous Sandstone/Sandstone/Sand (9360'-9750') = note slight distinctive change in coloration: from very light gray and light gray to light medium gray and medium gray; continued light olive gray and pale yellowish brown secondary hues; overall more "grayish" and less white and black (salt and pepper) contrast; moderately well sorted at fine upper to medium lower; range: very fine to medium upper, and very minor grains/clasts to granule; very fine fraction is mostly winnowed glass shards; wide range of shape and roundedness; dominant grain modality is: equant to slightly prismoidal; subangular to subrounded, subspherical to subdiscoidal; overall pervasive volcanic ash matrix supported sandstone with lesser grain supported; note that this interval appears significantly less calcareous than previous, but continued complex intergrain make-up that includes ash- clay-silt, silica-calcite cementation, major calcite- minor silica cementation, siderite particles, devitrified ash, carbonaceous material, micro shards, and various weathering-replacement minerals; large sandstone cuttings pieces in this interval occasionally have easily discernible micro bedding or layering, that contrasts the overall massive appearance; ashy sublithic arenite to marginal lithic quartz arenite; est. 65-75% quartz, volcanic glass,5-15% cryptosilica, trace to 10% fspr, 15-20% lithics and mafic minerals. NFU 24-26 16 3.3 Sampling Program SAMPLE MANIFEST: Cook Inlet Energy NFU 24-26: Washed and Dried Samples TOTAL: Ten (10) Vial Cases Two (2) SETs of 5 Vial Cases each Operator: Cook Inlet Energy Well Name: North Fork Unit #24-26 Field: North Fork Field County: Kenai Borough State: Alaska Company Representatives: Al Lunda, Rod Maniaci, Stephen Ratcliff, Monie Sainz Location: 648 FSL 1542 FEL, Sec 26 T4S R14W SM, X = 199870 Y = 2121192 Ground Elevation 657.80’ AMSL Rotary Table Elevation 678.38’ AMSL Classification: Development Gas, Multiple Zone API #: 50 – 231 – 20045 – 00 – 00 Permit #: 214 – 166 Activity Code: AFE # 146003 Rig Name / Type: Miller #37 / Land / Telescopic Double Total Depth 9750’ Total Depth Formation: Tyonek Total Depth Date: December 18, 2014 CANRIG Logging Geologists: Craig Silva, Ralph Winkelman CANRIG Sample Catchers: James Foradas, Frank Thrailkill Set Type and Purpose Interval Frequency Distribution A Washed and Dried 2950’ – 9750’ 30’ Cook Inlet Energy 601 West 5th Street, Suite 310 Anchorage, AK 99501 Attn: Barb Kruk (907) 952 1151 B Washed and Dried 2950’ – 9750’ 30’ AOGCC 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Attn: Howard Okland (907) 793 1235 Vial Case Intervals: 2950’–4450’, 4450’–5950’, 5950’–7450’, 7450’–8950’, 8950’–9570’ TD NFU 24-26 17 4 DRILLING DATA 4.1 Daily Activity Summary 11/26/2014: Set annular in place. Install pitcher nipple and tie into flow line. Hook up accumulator control lines. Function test diverter. Hook up tie-downs for trip tank return and fill up line. Rig up for picking up drill pipe. Perform AOGCC-observed test of diverter system. Clean triplex pump suction strainer to improve pump rate performance. Test gas sensors. Start AOGCC-observed testing of Pason PVT system and immediately observe some false tank levels. Troubleshoot trip tank sensor and re-calibrate all tanks. AOGCC representative would also not accept the second phase of testing when some of the tank readings appeared unsteady and occasionally jumped to false levels. Pick up HWDP while troubleshooting and correcting PVT system. Finish picking up HWDP. Perform acceptable test of PVT system for AOGCC representative to complete all the state requirements. Pick up 8” Extreme™ mudmotor with 1.2° bend. Make up Bit #1RR. Hold pre-spud/pre-job meeting with all personnel on location to discuss safety and environmental issues, CIE’s expectations for the project and review well control procedures for the diverter. Pick up one stand of HWDP and make up cross-over to mudmotor. Fill hole with drilling fluid and check for leaks on all equipment. Tighten flange on pitcher nipple. Wash in and tag bottom of conductor at 140’. Spud well and drill 12 ¼” hole from 140’ to 156’. 11/27/2014: Drill from 156’ to 219’. Circulate two bottoms ups. Pull out of hole to mudmotor. Pick up MWD. Scribe PWD. Pick up NMFC. Plug into MWD and program tools. Pick up and make up one joint of drill pipe. Run in and shallow test MWD tools. Break and lay down joint of drill pipe. Pick up, make up and run in second NMFC and jars. Drill from 219’ to 243’. Observe overload of cuttings in BOS system. Clear trough and system. Troubleshoot and reset crown-o-matic. Repair air-cooling hose on carrier motor. Drill from 243’ to 431’. BOS equipment plugging off with rock cuttings. Shut down and clean all equipment. Note trough is full and spilling into half-tank. Clean half-tank and clear rocks from pump. Build trough extensions to allow excess cuttings to move into half-tank. Use vac truck to remove cuttings. While breaking out of a stand, the dies slipped on a saver sub quill clamp for the top drive. Remove and replace dies. Re-torque saver sub quill clamp. 11/28/2014: Finish tightening saver sub clamp. Adjust gripper height. Drill from 431’ to 741’. Pick up, monitor well and check for flow. Drill from 741’ to 1295’. 11/29/2014: Drill from 1295’ to 1621’. Circulate two bottoms up. Monitor well. Synchronize rig generator. Pull out of hole wet on wiper trip from 1621’ to 1371’. Monitor well. Blow down topdrive. Fill trip tank. Continue pulling out of hole on wiper trip from 1371’ to top of HWDP at 806’. Monitor well. Run back in hole (SLM) from 806’ to 1558’. Kelly up topdrive. Wash down from 1558’ to bottom at 1621’ and continue drilling ahead. Drill from 1621’ to 2157’. 11/30/2014: Continue drilling ahead from 2157’ to 2320’. Lose function of rig pump #3. Break and lay down last in-string stand in V-door. Pull out of hole one more stand from 2311’ to 2250’. Monitor well. Troubleshoot and work on pump #3 motor. Change out topdrive gripper dies. Replace #1 transmission shifter. Clean and prep rig floor before running back in hole. Run back in hole (one stand) from 2250’ to 2311’. Pick up and make up last stand in V-door. Break circulation and wash down from 2311’ to 2320’. Circulate out 4’ of fill. Drill ahead from 2320’ to 2472’. Check for flow. Drill from 2472’ to 2946’ (surface casing point). Circulate hole clean. Check flow. Pump pill. Blow down lines. NFU 24-26 18 12/01/2014: Pull out of hole from 2946’ (SLM) to 806’ (top of HWDP) Monitor well (static). Continue pulling out of hole to 151’ (top of NM flex collars). Work back through, wipe and clean tight (20K to 40K over-pull) spots at 2450’, 2032’, 1906’, 1749’, 540’ on way out. Hole took proper fill. Service rig. Monitor well (static). Clean rig floor. Run back in hole from 151’ (SLM in) to 2378’. Observe broken hydraulic hose to elevator actuator assembly. Kelly up and fix hose. Continue running in hole from 2378’ to 2884’. Kelly up and wash down from 2884’ to bottom at 2946’ (with no fill). Circulate (staging-up pump output to 500 gpm) and condition hole. Record 89 units of wiper gas on first bottoms up. Circulate mud weight down 9.2 ppg. Pull out of hole from 2946’ to surface, laying down jars and all directional tools on way out. Clear and clean rig floor and make preparations for running 9 5/8” surface casing. Pick up and rig up all Weatherford casing running tools. Change out bails (from short to long). 12/02/2014: Continue rigging up to run 9 5/8” surface casing. Hold pre-job meeting on running casing with Weatherford hands, company representatives and crew. Pick up, make up and run in hole with shoe and float joint. Check floats (OK). Continue running in hole with 9 5/8” casing as per CIE. Fill pipe on the fly and top off every 5 joints. Continue running casing in hole, with no issues on way in, to 2946’. Make topdrive and crossover assembly to 9 5/8” casing. Break circulation and stage up pump output to 400 gpm. No mud losses observed during circulating. Record 11 units of trip gas during first circulation. Cementers leave location (for priority cement job with other customer). Continue circulating while waiting on cementers. Rig up cellar pump. Change liners in #3 mud pump. Cementers return to location. Rig up cementers. Hold brief pre-job meeting on cementing operations with current crew and all other hands. Install plugs in cementing head. 12/03/2014: Move unneeded subs and equipment from middle of rig floor to their proper place. Lift Weatherford slips to V-door side of rig prior to continuing cementing operations. Hold longer, more detailed pre-job meeting on cementing operations with newly arrived crew and all other hands. Perform cementing operations as per CIE. Fill and test cementing lines to 2500psi. Batch and test 9.6 ppg spacer. Pump 40 bbls of 9.6 ppg spacer at 2-3 bpm, then follow with 285 bbls of 12.5 ppg lead cement at 3-5 bpm and then 41 bbls of 14.8 bbls of tail cement at 2 bpm. Drop bottom plug and displace with 219 bbls of 9.2 ppg mud. (Excess cement returns going to cellar and continuously flushed and pumped out throughout displacement and clean-up operations). Bump plug at 06:30 hours. Cement in place. No flow-back. Blow down pumps and flush stack and lines. Flush and wash cellar until free of cement. Flush annular completely clean while it is being functioned. Clear rig floor of all remaining casing running and handling equipment. Clean rig floor. Perform inspection, minor prep work and troubleshooting of bridge cranes before doing upcoming heavy lifting. Re-connect accumulator hoses. Manage movement and re- positioning of office trailer and new company man living quarters. Disassemble and rig-down flow line and pitcher nipple. Change out liners in #1 and #2 mud pumps. Change shaker screens. Clean pits. Nipple down diverter line. Pick up Hydril. Cut casing. Move boxes of cement. Clean containment area. 12/04/2014: Finish nippling down diverter. Disassemble diverter and ready sections for transport. Cut and remove 13 5/8” wellhead. Finish top of 13 3/8” casing. Make rough cut on 9 5/8” casing and remove section. Perform final cut and prep top of 9 5/8” casing. Weld 11” wellhead on 9 5/8” casing and wait to cool down. Test seal assembly. Test wellhead. Prep and rig up to install/nipple up BOPs. Finish cleaning pits in preparation for KLA-Shield mud system. Begin building KLA-Shield mud system in pits (using Pit #3 as a batch mixing pit and then distributing fluid to other pits). Make up Hydril, Double Gate, Mud Cross, Single Gate, DSA and Spool, and all associated valves. Reposition BHI MWD/LWD tools on location to create unobstructed nearby working area for forklift. NFU 24-26 19 12/05/2014: Continue building KLA-Shield mud system. Nipple up BOP stack. Hook-up and function test accumulator lines. Remote worked properly. Re-attach choke and kill lines. Secure stack with turnbuckles. Set mousehole. Rig up elevators. Make up and set test joint/test plug. Fill stack. Perform shell test to 250 psi Low / 4000 psi High. Observe leak at kill hose hub connection. Fix leak. State representative arrives to witness BOPE testing. Test all BOPE as per C.I.E. procedures. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test all other BOPE (dart valve, upper Kelly, upper pipe rams, CMVs 10-11-12-6-9-8, lower Kelly, outside kill, floor valve, CMVs 4-1-2-5-7, inside kill, lower pipe rams, HCR, in-line choke, blind rams, CMVs 4-7-3) to 250 psi Low / 4000 psi High for 5 minutes each. Pull test joint/test plug. Set wear bushing. Perform accumulator drawdown test. Blow down choke and mud lines. Pick up BHA. Change bend on mudmotor to 1.1 degrees. 12/06/2014: Continue to pick up, make up and run in hole with BHA. Load nuclear sources. Finish picking up BHA and running in to 426’. Attempt to shallow test directional/LWD tools (at 220 spm, 350 gpm, 690 psi). Unable to sustain high enough pump rate to function LWD downhole tools properly. Slip drill line . Reset block height and crown-o-matic. Crossover and continue running in hole with 5” drill pipe from 426’ to 2837’. Kelly up and wash down from 2837’ to tag top of cement at 2870’. Rig up and perform casing test (at 3000 psi for 30 minutes). Continue drilling out cement and remaining shoe tract from 2870’ to 2946’ (cement, float at 2890’, cement, casing shoe at 2938’, rat hole to 2946’). Drill new hole from 2946’ to 2970’. Circulate bottoms up and continue circulating, adding Desco II and Bicarb mud products to deal with thick mud and cement flocculation. Displace old mud with 30 bbl Hi-Vis spacer in front of 200 bbls 9.0 ppg Kla-Shield mud. Continue to circulate and condition with new mud and reduce mud weight to 8.85 ppg as per drill cite manager. Cease pumping and perform Formation Integrity Test to 13.62 EMW. Blow down stack and choke. Line back up for hard shut-in. Drill ahead from 2970’ to 3273’. 12/07/2014: Drill ahead from 3273’ to 4036’. Circulate bottoms up and continue circulate and condition hole. Check flow. Pull out of hole on wiper trip from 4036’ to 2693’. Hold BOP drill and hold group meeting. Service rig. Run back in hole from 2963’ to 3974’. Kelly up and wash down from 3974’ to bottom at 4036’. Drill from 4036’ to 4298’. 12/08/2014: Drill from 4298’ to 5490’. 12/09/2014: Circulate bottoms up at 5490’ and continue to condition mud. Check flow. Pull out of hole on Wiper Trip from 5490’ to 4797’. Pump 9.5 ppg dry job. Continue to pull out of hole on Wiper Trip from 4797’ to 1513’. Pick up and make agitator and shock sub. Service rig. Conduct BOP drill. Run back in hole from 1513’ to (just outside shoe) at 2989’. Briefly circulate and fill pipe. Calibrate block height. Continue running back in hole from 2989’ to 5391’. Kelly up and break circulation. Wash down from 5391’ to bottom at 5490’. (No fill on bottom). Drill ahead from 5490’ to 6143’. 12/10/2014: Drill from 6143’ to 6648’. Circulate bottoms up. Check for flow. Pull out of hole on wiper trip from 6648’ to 5490’. Service wash pipe. Run back in hole from 5490’ to 6586’. Break circulation and wash down from 6586’ to 6648’ with no fill. Pick up and make up stands in the mousehole. Continue drilling ahead from 6648’ to 6837’. Note 400psi drop in pump pressure. Circulate bottoms up while reciprocating pipe. Continue to circulate and condition hole while building a dry job. Pull out of hole 5 stands from 6837’ to 6522’. Pump 20 bbl (10.8ppg) dry job. NFU 24-26 20 12/11/2014: Pull out of hole (SLM) from 6522’ to 5391’. Detect small fragments of hard plastic and metal falling down onto the rig floor. Stop all activity and investigate all the way up to the crown. On top of the derrick, observe that the Pason Block Height Sensor is shattered, the bolts retaining the mount for the sensor immediately adjacent the fast crown block sheave are broken and most had fallen down, and the mount itself was sheared away by severe impact and then wedged next to the sheave support frame. The damage was photographed and then all loose and/or damaged materials and equipment were cleared, moved and/or secured to mitigate the hazards of flying debris. Continue pulling out of hole (SLM) from 5391’ to 1538’. Break, wash out, lay down and off load agitator and shock sub. Continue pulling out of hole (SLM) from 1538’ to top of HWDP at 822’. Continue pulling out of hole with HWDP to 198’ and with lower assembly flex collars to 139’. Pull stand to CCN tool and remove sources. Remove, clean and re- install screen. Pull, break and lay down all LWD tools. Pull to Ontrak tool. Plug-in and download all memory data. Break, lay down and inspect bit. Finish breaking and laying down LWD tools. Clear rig floor and prep for testing BOPE as per C.I.E. Pull wear ring. Rig up and install all test equipment and tools. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test all other BOPE (upper pipe rams, dart valve, upper Kelly, CMVs 12-11-10, check valve, upper pipe rams, TIW, lower Kelly, CMVs 6-9- 8-1, outside kill) to 250 psi Low / 4000 psi High for 5 minutes each. 12/12/2014: Continue testing BOPE (CMVs 2-7-5, inside kill, HCR, manual choke, lower pipe rams, blind rams, CMVs 3,4) to 250 psi Low / 4000 psi High for 5 minutes each. Perform accumulator drawdown test. Tested super choke and manual choke to 1000psi. Set wear ring and lay down test joint. Rig up Pollard Wireline. Pick up, make up and run in hole with CBL logging assembly. Log surface casing interval and pull out of hole. Rig down wireline equipment. Clear rig floor. Pick up, make up and run in hole bit, mudmotor and LWD tools to CCN collar. Load sources. Continue running in hole with remaining lower assembly tools and HWDP to 822’. Prep to pick up 5” drill pipe. Pick up, make up and continue running in hole with 8 single joints of drill pipe to 1071’. Hold BOP drill. Check crown-o-matic. Continue to pick up, make up and run in hole with 14 more single joints of drill pipe to 1511’. Pick up and make up agitator and shock sub. Continue to pick up, make up and running in hole with 84 more single joints of drill pipe (106 joints total) to 4184’. Fill pipe and break circulation. Dynamic test MWD-LWD tools. Continue to run in hole with stands of drill pipe to 6774’. Kelly up. Set depth and do check survey. Wash down from 6774’ to bottom at 6837’. Lose 28 bbls of mud over shakers during initial circulation. Circulate hole clean while washing down. Record 105 units of trip gas. Drill from 6837’ to 6852’. 12/13/2014: Drill from 6852’ to 7340’. Pull off bottom and circulate. Hold pre-job meeting with Pason technician who arrived on location to install new block height sensor on top of crown. Circulate while technician is performing installation. Installation fails due failure of glue to adhere to metal. Prep for drilling ahead while technician returns to rig floor. Drill ahead from 7340’ to 7596. After 7466’, observe progressive pressure loss from 2250 psi to 1400 psi. Troubleshoot pressure loss. Pressure test mud pump #3. Stand back current stand to 7593’ and then pull next full stand out of hole to 7530’ and stand back. Circulate and reciprocate while inspecting mud pump #3 and #3 charge pump. 12/14/2014: Pull out of hole from 7561’ looking for washout. Discover washout at 6992’. Replace washed out joint with new joint. Pump and circulate after replacing joint to check system all the way around. Run back in hole from 6992’ to 7530’. Kelly up and wash down from 7530’ to 7596’ with no fill. Drill from 7596’ to 8522’. 12/15/2014: Drill from 8522’ to 8970’. Circulate bottoms up. Flow check. Pull out of hole on wiper trip from 8970’ to 7640’. Monitor well. Service rig. Replace broken bolt. Replace cap gasket on #2 mud pump. Run back in hole from 7640’ to 8900’. Kelly up and wash down from 8900’ to bottom at 8970’. Work on washed-out cap gasket on #2 mud pump. Drill from 8970’ to 9058’. Cease drilling ahead after slow progressive pump deterioration, and failure to maintain sufficient dynamic discharge from at least two pumps. Continue pumping and reciprocating on #3 mud pump while repairing isolation valve on #2 mud pump. NFU 24-26 21 12/16/2014: (Note: break and lay down last joint to 9033’ before reciprocating, then pull another joint to 8970’). Continue to circulate and reciprocate pipe on #3 mud pump, while repairing the pumps. Replace internal parts on 4” Demco isolation valve to #2 mud pump. Replace the #1 pod on #2 mud pump. Increase the lubricant concentration in the drilling mud to 3%. Gas circulated down to zero units. During circulating and reciprocating, observe hydraulic leak in Top Drive. Slowly work pipe back down to 9023’ while pump repairs are being completed. Pull back to 8970’ and put all three pumps on line with no problems at high rate. Wash down to 9032’. With hydraulic leak getting worse, decision made to pull to the shoe to repair Top Drive. Begin pulling out of hole from 9032’. (Pull tight, slow and working pipe the first 3 stands to 8842’, then pull progressively easier and faster). Pull out of hole 10 stands to 8407’. Pump dry job (31 bbls, 10.1 ppg). Continue pulling out of hole from 8407’ to 2829’ (just inside shoe). Repair hydraulic valve block 0-rings and extend pin. Check crown-o-matic. Run back in hole from 2829’ to 4684’. Fill pipe. Continue to run back in hole from 4684’ to 5000’. 12/17/2014: Continue to run in hole from 5000’, filling pipe every 2000’. Tag up at 9019’. Pull back up to 8970’ and kelly up. Wash and ream from 8972’ to 9058’. Drill from 9058’ to 9070’. Record 240 units of wiper gas. Start losing pump pressure just after bottoms up (from 2200psi to 1700psi). Note trouble issues. Monitor well for flow, and well is static. (Pump pressure falls off to 1200psi). Pull out of hole from 9070’ looking for washout. Find washout in joint at 7246’. Lay down washed out single and pick up and make up new single (of same length). Run back in hole from 7246’ to 8187’. Kelly up. Wash and ream from 8187’ to 9070’. Record 42 units of wiper gas. Drill from 9070’ to 9524’. 12/18/2014: Continue to drill from 9525’ to 9537’. Make a connection. Detect washout at top of current stand (stand 139). Set stand back and pick up next stand (stand 140). (Note 15’ difference). Continue to drill from 9537’ to 9750’. Circulate and wait on orders. Decision made that 9750’ will be Total Depth of well. Circulate bottoms up. Take slow pump rate. Monitor well and well is static. Pull out of hole wet from 9750’ to 9600’. Kelly up. Wash and wipe hole from 9600’ to 9540’. (Hole taking proper fill). Continue pulling out of hole from 9540’ to 8533’. Monitor well and well is static. Hold BOP drill (and note 3 minute response time). Run back in hole from 8533’ to 9662’. Kelly up. Wash down from 9662’ to 9750’. Tag bottom and start circulating bottoms up. Start and pump around Hi-Vis sweep. Record 136 units of wiper gas. Pump 3 bottoms ups total. Check for flow. Pull out of hole 10 stands to 9097’. Pump 20 bbl dry job. Continue pulling out of hole from 9097’ to 3174’. Rig up to pull the rest of the way out of hole laying down drill pipe. 12/19/2014: Continue to rig up for laying down drill pipe. Pull out of hole laying down 5” drill pipe from 3174’ to 909’. Service rig, Monitor well. Well is static. Fill trip tank. Continue pulling out of hole laying down 5” drill pipe and HWDP to top of flex collars at 198’. Break and lay down flex collars, sub and stabilizer to stop sub at 125’. Clean and clear rig floor. Pull to CCN tool and remove radioactive sources. Pull, break and lay down all remaining LWD/Directional tools and bit. Pull wear ring. Test BOPE as per C.I.E. procedures. Install 5” test joint and rig up all test equipment. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test other BOPE (all other valves and rams) to 250 psi Low / 4000 psi High for 5 minutes each. Rig down test equipment. 12/20/2014: Prep rig floor, and rig up to test 7” casing rams. Set 7” test plug. Test 7” casing rams to 250 psi Low / 3000 psi High for 10 minutes. Rig down test equipment. Pull and lay down test joint. Blow down topdrive, choke manifold and all related mud lines. Prep and rig up to run 7” casing. Finish rig up of Weatherford casing tongs, air slips and elevators. Run 7” production casing as per C.I.E.. Pick up, make up and run in hole 7” shoe track to 128’. Test floats. Floats held. Continue picking up, making up and running in hole with 7” casing from 128’ to surface casing shoe at 2938’. Kelly up and circulate surface to surface. Record 10 units shallow trip gas. Continue running in hole with 7’ casing from 2938’ to 3949’. NFU 24-26 22 12/21/2014: Fill 7” casing on the fly while running in, and topping off every 10stands. Continue running in hole with 7” production casing from 3949’ to 6267’. Kelly up and break circulation, staging up pump output from 80 gpm to 350 gpm with no losses. Rotate casing 15 rpm. Torque to rotate leveled off at 10K. Shut down rotary. Continue to circulate and reciprocate with no rotary for 2 bottoms ups. Record 136 units of trip gas at 6267’. Continue running 7” casing in hole from 6267’ to 8405’. Check actual displacement to calculated and record 5 bbl lost to hole at that point. Swap over to 200 ton elevators. Continue running in hole from 8405’ to 8944’. Hole tight. Kelly up and attempt to pump at reduced rate. Rotate casing at 15K torque. Attempt to work free. Able to start increasing travel distance, and staging up pump output, while working casing. Record 275 units of trip gas from 8944’ while working casing. Work casing free, start pumping at higher rates and wash through tight hole zone. Continue running 7” casing in hole, washing down and rotating as needed, from 8944’ to end of run at 9734’. Record maximum gas of 77 units while washing down after 8944’. Circulate and reciprocate surface to surface at 9734’. Pick up working joint to circulate on bottom. Record maximum 66 units of trip gas at bottom of 7” casing run. 12/22/2014: Lay down working joint and CRT tool. Blow down topdrive. Pick up landing joint. Rig up and install cementing head and load plugs. Circulate and reciprocate at 8 bpm with no losses. Hold pre-job meeting on cementing procedures with Baker cementers and all rig hands. Prime lines and kick out bottom plug with 5 bbls of water. Pressure test lines to 4000 psi. Bleed off pressure. Batch up and pump 40 bbls of 10.5ppg Sealbond Spacer, then batch up and pump 161 bbls of 12.7ppg lead cement. Reciprocate during all the cement pumping. Batch up and follow lead cement by pumping 99 bbls 13.5ppg tail cement. Shut down and flush 1502 treating iron to rig cellar with 5 bbls water. Drop top plug. Line back up to well and displace cement with 369 bbls 8.5ppg brine. Plug bumped (at 09:00 hrs) at 370 bbls away. Floats holding. Get 3.5 bbls back. Blow down cementing lines and all associated mud lines. Clear rig floor of all cementing equipment. Back out and lay down landing joint. Swap elevators and bails. Install packoff and test to 5000psi. Clean rig floor. Rig up to lay down drill pipe. Lay down all remaining drill pipe. (Continue with all remaining procedures before completion phase: finish laying down drill pipe, run test plug and test BOPs , set wear bushing, pick up tubing string with mill and scrapers and clean out casing, test casing, run CBL). NFU 24-26 23 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) 20.80 0 358.00 20.80 0 0 0 0 179 1.26 193.43 178.99 -1.69 -0.40 0.92 0.80 243 1.29 201.47 242.97 -3.05 -0.83 1.76 0.28 304 0.63 181.94 303.96 -4.02 -1.09 2.32 1.19 367 0.81 17.61 366.96 -3.94 -0.97 2.17 2.26 430 4.03 9.56 429.90 -1.33 -0.47 0.87 5.13 492 4.80 7.60 491.71 3.39 0.24 -1.30 1.27 554 5.22 9.52 553.48 8.74 1.05 -3.77 0.73 617 5.73 3.14 616.19 14.70 1.69 -6.28 1.26 679 6.79 354.48 677.82 21.44 1.51 -8.25 2.29 742 8.94 348.71 740.22 29.95 0.19 -9.71 3.63 806 9.63 345.70 803.39 40.02 -2.10 -10.74 1.32 870 9.47 345.76 866.50 50.31 -4.72 -11.53 0.25 932 9.47 345.54 927.65 60.19 -7.25 -12.28 0.06 995 9.08 329.21 989.84 69.48 -11.09 -11.59 4.21 1058 9.00 312.39 1052.07 77.07 -17.27 -8.14 4.18 1121 8.80 296.35 1114.32 82.54 -25.23 -2.34 3.94 1184 7.99 279.80 1179.65 85.42 -33.87 4.93 4.03 1247 7.58 261.66 1239.08 85.56 -42.29 12.88 3.94 1310 9.09 261.62 1301.41 84.24 -51.33 21.86 2.40 1372 11.48 261.24 1362.41 82.58 -62.27 32.77 3.86 1433 14.18 261.03 1421.89 80.49 -75.66 46.12 4.43 1496 16.51 263.59 1482.64 78.29 -92.18 62.48 3.85 1558 17.30 258.27 1541.96 75.43 -109.96 80.25 2.80 1622 17.37 251.89 1603.06 70.53 -128.36 99.25 2.97 1685 17.74 244.41 1663.13 63.46 -145.95 118.18 3.63 1748 19.20 242.69 1722.89 54.56 -163.82 137.95 2.47 1810 21.17 242.51 1781.08 44.71 -182.81 159.09 3.18 1874 22.57 245.47 1840.47 34.28 -204.24 182.72 2.78 1938 22.74 251.17 1899.54 25.18 -227.12 207.31 3.44 1999 22.67 252.63 1955.81 17.87 -249.50 230.85 0.93 2062 23.06 252.59 2013.86 10.55 -272.86 255.32 0.62 2124 23.28 252.71 2070.86 3.28 -296.14 279.71 0.36 2190 24.13 250.14 2131.29 -5.18 -321.28 306.24 2.03 2250 24.60 249.89 2185.95 -13.64 -344.55 330.99 0.80 2313 24.33 247.73 2243.29 -23.07 -368.87 357.05 1.48 2377 24.46 246.83 2301.58 -33.28 -393.25 383.41 0.62 NFU 24-26 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) 2440 24.98 246.91 2358.81 -43.63 -417.48 409.67 0.83 2503 24.06 248.15 2416.13 -53.62 -441.64 435.75 1.67 2567 24.17 248.59 2474.54 -63.26 -465.94 461.86 0.33 2630 24.33 248.79 2531.98 -72.67 -490.05 487.71 0.29 2693 23.81 247.54 2589.50 -82.22 -513.90 513.36 1.16 2756 23.69 247.33 2647.17 -91.96 -537.33 538.67 0.23 2821 23.91 247.23 2706.64 -102.09 -561.53 564.83 0.34 2881 24.37 247.36 2761.39 -111.56 -584.16 589.30 0.77 2968 24.49 247.79 2840.60 -125.28 -617.42 625.20 0.25 3031 24.27 248.03 2897.99 -135.06 -641.52 651.16 0.38 3094 24.18 247.81 2955.44 -144.78 -665.47 676.96 0.20 3158 24.18 247.76 3013.82 -154.69 -689.74 703.12 0.03 3220 24.06 247.91 3070.41 -164.25 -713.21 728.41 0.22 3283 23.93 248.17 3127.97 -173.83 -736.97 753.98 0.27 3346 23.85 247.92 3185.57 -183.37 -760.63 779.45 0.20 3410 23.75 247.99 3244.12 -193.06 -784.57 805.23 0.16 3473 23.73 247.57 3301.79 -202.65 -808.05 830.54 0.27 3535 23.73 247.62 3358.55 -212.16 -831.12 855.43 0.03 3598 23.53 247.71 3416.27 -221.76 -854.47 880.63 0.32 3661 23.37 246.51 3474.07 -231.51 -877.57 905.63 0.80 3724 23.24 246.52 3531.93 -241.44 -900.43 930.46 0.21 3789 23.12 246.77 3591.68 -251.59 -923.92 955.96 0.24 3853 22.88 245.97 3650.59 -261.61 -946.83 980.86 0.62 3916 22.73 245.81 3708.67 -271.58 -969.12 1005.17 0.26 3980 22.42 245.38 3767.76 -281.73 -991.49 1029.61 0.55 4044 22.56 245.42 3826.90 -291.93 -1013.75 1053.95 0.22 4107 23.29 246.85 3884.92 -301.85 -1036.19 1078.39 1.46 4171 22.91 246.92 3943.79 -311.71 -1059.29 1103.42 0.60 4236 22.79 246.88 4003.69 -321.61 -1082.50 1128.58 0.19 4299 22.57 246.89 4061.82 -331.15 -1104.84 1152.79 0.35 4361 22.39 246.63 4119.10 -340.50 -1126.63 1176.42 0.33 4424 22.14 246.64 4177.41 -349.97 -1148.54 1200.21 0.40 4486 21.85 246.23 4234.89 -359.25 -1169.82 1223.34 0.53 4550 21.48 246.25 4294.37 -368.77 -1191.45 1246.87 0.58 4614 21.19 245.98 4353.99 -378.20 -1212.74 1270.05 0.48 4678 20.88 245.99 4413.72 -387.55 -1233.72 1292.92 0.48 4741 20.99 246.47 4472.56 -396.62 -1254.32 1315.33 0.32 4802 21.51 247.03 4529.42 -405.34 -1274.64 1337.37 0.92 4866 21.14 247.49 4589.03 -414.34 -1296.10 1360.58 0.63 4928 20.92 247.10 4646.90 -422.93 -1316.63 1382.77 0.42 4991 20.74 247.32 4705.79 -431.61 -1337.28 1405.11 0.31 NFU 24-26 25 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) 5054 20.53 247.00 4764.74 -440.23 -1357.74 1427.25 0.38 5116 20.14 246.75 4822.88 -448.69 -1377.56 1448.73 0.64 5180 19.83 247.11 4883.03 -457.26 -1397.68 1470.53 0.52 5244 19.58 246.97 4943.28 -465.68 -1417.55 1492.05 0.40 5307 19.46 247.14 5002.66 -473.88 -1436.93 1513.04 0.21 5371 19.06 246.68 5063.08 -482.16 -1456.35 1534.08 0.67 5432 18.97 246.17 5120.75 -490.11 -1474.57 1553.88 0.31 5522 18.37 245.32 5206.01 -501.94 -1500.84 1582.55 0.73 5585 17.70 244.96 5265.92 -510.14 -1518.54 1601.93 1.08 5649 17.05 244.24 5326.99 -518.34 -1535.80 1620.91 1.07 5711 16.92 244.41 5386.29 -526.18 -1552.12 1638.88 0.22 5773 16.81 244.08 5445.62 -534.00 -1568.32 1656.73 0.24 5837 16.60 243.59 5506.92 -542.11 -1584.84 1674.96 0.40 5899 16.38 243.77 5566.37 -549.91 -1600.61 1692.40 0.36 5961 16.17 243.54 5625.89 -557.62 -1616.18 1709.61 0.35 6023 15.70 243.42 5685.51 -565.22 -1631.41 1726.47 0.76 6088 13.27 244.72 5748.44 -572.35 -1646.02 1742.59 3.77 6151 11.74 244.23 5809.94 -578.22 -1658.34 1756.13 2.43 6214 10.24 248.35 5871.78 -583.07 -1669.31 1768.08 2.69 6277 8.65 251.57 5933.93 -586.64 -1679.01 1778.41 2.66 6340 7.12 250.92 5996.33 -589.41 -1687.20 1787.05 2.43 6403 6.29 249.93 6058.90 -591.87 -1694.13 1794.41 1.33 6466 5.65 248.67 6121.56 -594.18 -1700.26 1800.95 1.04 6529 4.53 248.06 6184.31 -596.24 -1705.46 1806.54 1.78 6592 3.69 241.99 6247.14 -598.12 -1709.55 1811.02 1.50 6656 2.74 240.63 6311.04 -599.84 -1712.70 1814.55 1.49 6719 2.10 234.19 6373.99 -601.25 -1714.95 1817.13 1.10 6783 1.24 239.66 6437.96 -602.29 -1716.50 1818.93 1.37 6844 1.06 235.02 6498.95 -602.95 -1717.53 1820.12 0.33 6906 1.00 233.24 6560.94 -603.60 -1718.44 1821.18 0.11 6968 1.03 229.16 6622.93 -604.29 -1719.29 1822.21 0.13 7031 0.79 264.86 6685.92 -604.70 -1720.15 1823.16 0.96 7093 0.74 290.62 6747.91 -604.60 -1720.95 1823.89 0.56 7157 0.69 294.21 6811.91 -604.29 -1721.69 1824.49 0.10 7222 0.61 285.54 6876.90 -604.04 -1722.38 1825.06 0.19 7283 0.62 279.36 6937.90 -603.90 -1723.02 1825.62 0.11 7347 0.55 283.33 7001.90 -603.77 -1723.66 1826.19 0.13 7411 0.48 287.34 7065.90 -603.62 -1724.22 1826.67 0.12 7473 0.42 297.99 7127.89 -603.44 -1724.67 1827.03 0.17 7535 0.31 292.31 7189.89 -603.27 -1725.02 1827.32 0.19 7598 0.39 315.61 7252.89 -603.05 -1725.33 1827.54 0.26 7662 0.35 290.25 7316.89 -602.82 -1725.66 1827.79 0.26 NFU 24-26 26 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) 7723 0.34 296.24 7377.89 -602.68 -1726.00 1828.06 0.06 7786 0.19 263.32 7440.89 -602.61 -1726.27 1828.30 0.33 7848 0.28 250.03 7502.89 -602.67 -1726.52 1828.55 0.17 7911 0.33 229.14 7565.89 -602.84 -1726.80 1828.87 0.19 7974 0.29 182.06 7628.89 -603.12 -1726.94 1829.09 0.40 8037 0.41 179.37 7691.88 -603.51 -1726.95 1829.22 0.19 8099 0.68 166.10 7753.88 -604.09 -1726.85 1829.32 0.48 8162 0.73 165.75 7816.88 -604.84 -1726.67 1829.38 0.08 8223 0.63 162.84 7877.87 -605.53 -1726.47 1829.42 0.17 8287 0.87 155.04 7941.87 -606.31 -1726.16 1829.37 0.41 8351 0.87 151.37 8005.86 -607.18 -1725.72 1829.23 0.09 8413 0.87 149.40 8067.85 -608.00 -1725.26 1829.05 0.05 8475 0.99 142.22 8129.84 -608.83 -1724.69 1828.77 0.27 8537 1.18 138.45 8191.83 -609.73 -1723.94 1828.35 0.33 8601 1.35 140.38 8255.82 -610.80 -1723.02 1827.82 0.27 8664 1.36 135.25 8318.80 -611.90 -1722.02 1827.22 0.19 8726 1.47 133.11 8380.78 -612.97 -1720.92 1826.52 0.20 8790 1.64 130.12 8444.76 -614.12 -1719.62 1825.66 0.29 8852 0.85 139.89 8506.74 -615.04 -1718.65 1825.02 1.31 8914 0.62 142.32 8568.74 -615.66 -1718.15 1824.75 0.37 8977 0.64 146.28 8631.73 -616.22 -1717.74 1824.54 0.08 9040 0.55 139.68 8694.73 -616.75 -1717.35 1824.34 0.18 9102 0.62 127.52 8756.73 -617.18 -1716.9 1824.04 0.23 9167 0.76 114.46 8821.72 -617.57 -1716.22 1823.53 0.32 9229 0.92 123.02 8883.72 -618.01 -1715.43 1822.92 0.33 9292 0.99 128.97 8946.71 -618.63 -1714.59 1822.31 0.19 9353 1.24 130.93 9007.70 -619.39 -1713.68 1821.69 0.41 9416 1.30 130.15 9070.68 -620.30 -1712.62 1820.98 0.10 9479 1.51 131.71 9133.66 -621.31 -1711.45 1820.19 0.34 9542 1.71 132.28 9196.64 -622.50 -1710.13 1819.32 0.32 9603 1.78 130.72 9257.61 -623.73 -1708.74 1818.40 0.14 9668 1.82 131.50 9322.58 -625.07 -1707.20 1817.36 0.07 9693 1.90 132.41 9347.56 -625.61 -1706.60 1816.97 0.34 *9750 1.90 132.41 9404.53 -626.89 -1705.21 1816.05 0.00 *Projection NF U 2 4 - 2 6 27 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 1 1 2 ¼ H C C M X L 1 5 2 3 1 9 7 1 3x 2 0 , 1 x 1 0 c j 0. 9 9 7 14 0 ’ 2 9 4 6 ’ 2 8 0 6 ’ 5 7 . 3 2 4 9 . 0 2 - 2 - W T - A - E - I - E R - T D 2 8 ¾ N O V S K H 5 1 9 M A 1 9 7 1 8 0 5x 1 4 0. 7 5 2 29 4 6 ’ 6 8 3 7 ’ 3 8 9 1 ’ 5 8 . 3 9 6 6 . 7 1 - 2 - C T - S - X - I - W T - P P 2R 1 8 ¾ N O V S K H 5 1 9 M A 1 9 7 1 8 0 5x 1 5 0. 8 6 3 68 3 7 ’ 9 7 5 0 ’ 2 9 1 3 ’ 5 5 . 3 0 5 2 . 7 1 - 2 - C T - C - X - I - W T - T D NF U 2 4 - 2 6 28 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 4 6 ’ ; K l a - S h i e l d 29 4 6 ’ – 9 7 5 0 ’ 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) 11 / 2 5 / 1 4 1 3 8 8 . 7 5 5 9 1 6 1 6 / 2 0 / 2 8 1 4 2 3 . 5 0 / 9 7 0 . 0 2 5 . 0 9 . 6 1 5 0 0 2 0 11 / 2 6 / 1 4 1 8 5 8 . 6 5 1 9 1 1 6 / 1 0 / 1 3 1 4 2 3 . 8 0 / 9 6 0 . 0 2 5 . 0 9 . 5 1 5 0 0 2 0 11 / 2 7 / 1 4 4 3 1 8 . 8 8 6 1 5 3 0 1 9 / 3 4 / 3 8 1 1 . 5 2 6 . 0 0 / 9 4 0 . 2 5 2 6 . 2 5 9 . 4 4 0 0 4 0 11 / 2 8 / 1 4 1 2 4 7 9 . 0 8 6 1 7 3 4 1 1 / 2 4 / 2 7 9 . 9 2 7 . 0 0 / 9 3 0 . 3 3 1 . 2 5 9 . 9 3 0 0 2 0 11 / 2 9 / 1 4 2 0 6 2 9 . 4 6 0 1 2 2 4 7 / 2 0 / 2 4 8 . 8 2 6 . 0 0 / 9 4 0 . 2 2 5 . 0 9 . 0 3 5 0 2 0 11 / 3 0 / 1 4 2 9 4 6 9 . 4 5 5 1 0 1 7 8 / 1 7 / 1 8 9 . 7 2 6 . 5 0 / 9 4 0 . 2 1 7 . 5 9 . 6 2 5 0 4 0 12 / 0 1 / 1 4 2 9 4 6 9 . 1 4 9 7 1 5 6 / 1 8 / 1 9 1 2 . 6 2 6 . 0 0 / 9 4 1 . 0 1 7 . 5 9 . 6 2 0 0 4 0 12 / 0 2 / 1 4 2 9 4 6 9 . 1 3 6 6 7 3 / 1 9 / 3 0 1 2 . 5 1 6 . 0 0 / 9 4 0 . 0 0 1 1 7 . 5 9 . 3 2 0 0 2 0 12 / 0 3 / 1 4 2 9 4 6 C l e a n p i t s 12 / 0 4 / 1 4 2 9 4 6 B u i l d m u d 12 / 0 5 / 1 4 2 9 4 6 8 . 7 6 0 9 1 4 6 / 9 / 1 1 9 . 0 1 4 . 0 0 / 9 6 0 0 . 0 1 0 . 3 1 7 0 0 0 4 0 12 / 0 6 / 1 4 3 2 1 0 8 . 9 4 4 9 1 4 5 / 7 / 8 7 . 5 1 2 . 0 0 / 9 8 0 2 . 5 1 0 . 1 1 7 0 0 0 4 0 12 / 0 7 / 1 4 4 0 6 9 9 . 3 4 8 1 3 1 8 6 / 7 / 8 5 . 8 1 6 . 0 0 / 9 4 0 . 1 5 2 . 5 9 . 9 2 2 0 0 0 4 0 12 / 0 8 / 1 4 5 3 4 0 9 . 3 6 5 2 4 2 8 5 / 8 / 8 4 . 7 1 6 . 0 1 / 9 3 0 . 1 5 . 0 9 . 6 1 6 0 0 0 4 0 12 / 0 9 / 1 4 6 0 5 3 9 . 3 6 7 2 5 2 5 5 / 7 / 9 4 . 6 1 6 . 0 1 / 9 3 0 . 1 5 . 0 9 . 8 2 0 0 0 0 4 0 12 / 1 0 / 1 4 6 8 3 7 9 . 3 6 8 2 2 2 6 6 / 8 / 9 4 . 8 1 6 . 0 1 / 9 3 0 . 1 7 . 0 9 . 5 1 8 0 0 0 4 0 12 / 1 1 / 1 4 6 8 3 7 9 . 3 6 3 2 2 2 6 6 / 8 / 1 0 4 . 6 1 6 . 0 1 / 9 3 0 . 1 7 . 0 9 . 5 1 8 0 0 0 4 0 12 / 1 2 / 1 4 6 8 3 7 9 . 3 7 2 2 2 2 5 6 / 8 / 1 0 4 . 6 1 6 . 0 1 / 9 3 0 . 1 7 . 0 9 . 5 1 8 0 0 0 4 0 12 / 1 3 / 1 4 7 5 9 3 9 . 3 7 3 2 4 2 5 5 / 7 / 8 4 . 2 1 6 . 0 1 / 9 4 0 . 1 6 . 2 5 9 . 7 1 7 0 0 0 4 0 12 / 1 4 / 1 4 8 4 4 4 9 . 4 6 5 2 7 2 8 5 / 7 / 8 4 . 5 1 6 . 0 2 / 9 2 0 . 1 6 . 2 5 9 . 5 1 6 0 0 0 4 0 12 / 1 5 / 1 4 9 0 3 4 9 . 4 6 0 2 5 2 6 5 / 7 / 7 4 . 2 1 6 . 0 2 / 9 2 0 . 1 6 . 2 5 9 . 4 1 6 5 0 0 4 0 12 / 1 6 / 1 4 9 0 5 8 9 . 4 6 0 2 5 2 5 5 / 7 / 7 4 . 6 1 6 . 0 3 / 9 1 0 . 1 7 . 0 9 . 4 1 6 0 0 0 4 0 12 / 1 7 / 1 4 9 4 2 9 9 . 4 5 6 1 8 2 0 4 / 5 / 6 4 . 6 1 6 . 0 3 / 9 1 0 . 1 7 . 0 9 . 5 1 7 0 0 0 4 0 12 / 1 8 / 1 4 9 7 5 0 9 . 4 5 4 1 8 2 0 4 / 6 / 6 4 . 6 1 6 . 0 2 / 9 2 0 . 1 7 . 0 9 . 5 1 6 0 0 0 4 0 12 / 1 9 / 1 4 9 7 5 0 9 . 4 5 6 1 5 1 6 3 / 5 / 5 4 . 6 1 6 . 0 2 / 9 2 0 . 1 7 . 0 9 . 5 2 1 0 0 0 4 0 12 / 2 0 / 1 4 9 7 5 0 9 . 4 5 8 1 8 2 2 4 / 5 / 6 4 . 6 1 6 . 0 2 / 9 2 0 . 1 7 . 0 9 . 5 2 1 0 0 0 4 0 12 / 2 1 / 1 4 9 7 5 0 9 . 4 5 8 1 8 2 2 4 / 5 / 6 4 . 6 1 6 . 0 2 / 9 2 0 . 1 7 . 0 9 . 5 2 1 0 0 0 4 0 12 / 2 2 / 1 4 9 7 5 0 8 . 5 D i s p l w / b r i n e 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 2 4 - 2 6 29 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 0 50 0 10 0 0 15 0 0 20 0 0 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 1 1 / 2 4 / 2 0 1 4 1 1 / 2 5 / 2 0 1 4 1 1 / 2 6 / 2 0 1 4 1 1 / 2 7 / 2 0 1 4 1 1 / 2 8 / 2 0 1 4 1 1 / 2 9 / 2 0 1 4 1 1 / 3 0 / 2 0 1 4 1 2 / 1 / 2 0 1 4 1 2 / 2 / 2 0 1 4 1 2 / 3 / 2 0 1 4 1 2 / 4 / 2 0 1 4 1 2 / 5 / 2 0 1 4 1 2 / 6 / 2 0 1 4 1 2 / 7 / 2 0 1 4 1 2 / 8 / 2 0 1 4 1 2 / 9 / 2 0 1 4 1 2 / 1 0 / 2 0 1 4 1 2 / 1 1 / 2 0 1 4 1 2 / 1 2 / 2 0 1 4 1 2 / 1 3 / 2 0 1 4 1 2 / 1 4 / 2 0 1 4 1 2 / 1 5 / 2 0 1 4 1 2 / 1 6 / 2 0 1 4 1 2 / 1 7 / 2 0 1 4 1 2 / 1 8 / 2 0 1 4 1 2 / 1 9 / 2 0 1 4 1 2 / 2 0 / 2 0 1 4 1 2 / 2 1 / 2 0 1 4 1 2 / 2 2 / 2 0 1 4 12/23/2014 12/24/2014 12/25/2014 12/26/2014 12/27/2014 12/28/2014 DA T E D E P T H ( F T ) 12 1/4" Hole 8 3/4" Hole N o r t h F o r k U n i t 2 4 - 2 6 NFU 24-26 30 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) 135 90 68 111 WOB 11 10 7 14 RPM 30 32 29 39 Mud Weight 9.3 9.3 9.3 9.3 Chloride 20,000 20,000 20,000 20,000 Total Gas 140 140 49 155 C1 (ppm) 27,916 27,895 9,838 31,106 C2 (ppm) C3 (ppm) - C4 (ppm) - - - C5 (ppm) - - - Lithology Cuttings Analysis Odor Fluorescence none 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: 5908' MD 5922' MD 5575.01' TVD 5588.45' TVD Craig Silva, Ralph Winkelman This is the "5600" Sand, very close to its projected top. Gas Show Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 9, 2014 18:49 Tuffaceous Sandstone = medium gray with very strong pale yellowish brown and faint to strong olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; very fine fraction mostly glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; overall complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 60-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/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) 96 135 100 135 WOB 6 9 8 9 RPM 32 35 29 35 Mud Weight 9.3 9.3 9.3 9.3 Chloride 16,000 16,000 16,000 16,000 Total Gas 56 100 83 110 C1 (ppm) 11,899 19,751 16,488 21,710 C2 (ppm) 39 150 96 168 C3 (ppm) 12 47 30 52 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence none 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: 6990' MD 7005' MD 6644.93' TVD 6659.92' TVD Craig Silva, Ralph Winkelman GAS SHOW Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 05:53 Tuffaceous Sandstone = medium gray with very strong pale yellowish brown and faint to strong olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; very fine fraction mostly glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; overall complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 60-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/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) 70 139 71 160 WOB 7 11 6 12 RPM 29 31 29 34 Mud Weight 9.3 9.3 9.3 9.3 Chloride 16,000 16,000 16,000 16,000 Total Gas 137 129 36 231 C1 (ppm) 26,889 25,432 7,562 45,371 C2 (ppm) 194 204 14 404 C3 (ppm) 66 52 5 107 C4 (ppm) C5 (ppm) - Lithology Cuttings Analysis Odor Fluorescence none 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 = medium gray with very strong pale yellowish brown and faint to strong olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; very fine fraction mostly glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; overall complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 60-75%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 04:04 Craig Silva, Ralph Winkelman GAS SHOW 7040' MD 7080' MD 6694.92' TVD 6734.91' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/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) 59 53 68 57 WOB 6 6 7 6 RPM 29 31 29 31 Mud Weight 9.3 9.3 9.3 9.3 Chloride 16,000 16,000 16,000 16,000 Total Gas 29 32 25 33 C1 (ppm) 6,054 6,464 5,166 6,762 C2 (ppm) C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence none 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 = medium gray with very strong pale yellowish brown and faint to moderate olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; most very fine grains are glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; note complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 60-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 05:12 Craig Silva, Ralph Winkelman Gas Show 7115' MD 7125' MD 6769.91' TVD 6779.91' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/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) 61 68 93 92 WOB 6 5 5 6 RPM 29 30 31 33 Mud Weight 9.3 9.3 9.3 9.3 Chloride 20,000 20,000 20,000 20,000 Total Gas 61 61 72 90 C1 (ppm) 12,278 12,080 14,252 18,012 C2 (ppm) 59 44 87 102 C3 (ppm) 13 12 21 22 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence none 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: 7135' MD 7160' MD 6789.91' TVD 6814.91' TVD Craig Silva, Ralph Winkelman GAS SHOW Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 05:33 Tuffaceous Sandstone = medium gray with strong pale yellowish brown and olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; 90% of very fine grains are glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; note complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 65-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 6 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph) 93 107 68 111 WOB 6 6 7 6 RPM 33 34 29 36 Mud Weight 9.3 9.3 9.3 9.3 Chloride 20,000 20,000 20,000 20,000 Total Gas 104 219 42 273 C1 (ppm) 20,442 42,909 8,365 53,629 C2 (ppm) 138 405 39 514 C3 (ppm) 31 86 6 110 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence none 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 = medium gray with faint to strong pale yellowish brown and olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; very fine fraction mostly glass shards winnowed from volcanic ash; equant to very slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; trace distinctive sharply angular clear quartz; range discoidal to spherical with very dominant subdiscoidal to subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; complex inter- grain material of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 60-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 06:32 Craig Silva, Ralph Winkelman Gas Show 7175' MD 7185' MD 6829.91' TVD 6839.91' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 7 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph) 37 42 53 53 WOB 5 6 8 8 RPM 31 31 34 35 Mud Weight 9.3 9.3 9.3 9.3 Chloride 16,000 17,000 17,000 17,000 Total Gas 16 25 18 38 C1 (ppm) 3,511 5,700 3,884 8,820 C2 (ppm) C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence none 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: 7379' MD 7427' MD 7033.90' TVD 7081.90' TVD Craig Silva, Ralph Winkelman Gas Show Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 13, 2014 12:46 Tuffaceous Sandstone = medium gray to light medium gray with faint to strong pale yellowish brown and light olive gray secondary hues; moderately well sorted at fine upper-medium lower; range very fine upper to spotty medium upper; very fine grains mostly glass shards winnowed from volcanic ash; equant to slightly prismoidal; angular to rounded; dominant subangular to slightly subrounded; rare sharply angular clear quartz; discoidal to spherical range with very dominant subdiscoidal to slightly subspherical; both matrix and grain supported; dominantly matrix supported weakly consolidated sandstone and minor loose disaggregated grains; overall complex inter-grain of abundant volcanic ash-derived clay-silt, devitrified ash, calcite-silica-siderite cementation and various alteration minerals; sublithic arenite; 65-70%quartz and variable minor fraction of amorphous volcanic glass; 10-15% various crypto-silica (chalcedony, chert) and other non-differentiated silica, trace-10% feldspar, 15-20% lithics and mafic minerals; dominant lithics are medium dark gray to grayish black metamorphic phyllite and argillite rock fragments; distinctive spotty greenstone lithics, trace micas. Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 8 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph) 73 53 78 87 WOB 10 7 13 9 RPM 41 36 41 41 Mud Weight 9.4 9.4 9.4 9.4 Chloride 16,000 16,000 16,500 16,000 Total Gas 77 137 125 241 C1 (ppm) 15,628 26,989 24,561 47,443 C2 (ppm) 104 185 235 384 C3 (ppm) 30 62 68 122 C4 (ppm) - - - C5 (ppm) - - - Lithology Cuttings Analysis Odor Fluorescence none 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: 95% disaggregated loose grains.Very minor patches of very fragile light gray to white volcanic ash matrix supported sandstone. The matrix is patially to entirely soluble, and easily disturbed during hydration in the mud and when sample processing. Light gray to very light gray with local white specks and patches; very faint light olive gray secondary hue; moderately well sorted overall within the fine lower to medium lower range, and well distributed very spotty grains outside the range; appears subtle fining upward through show section; full range from angular to rounded and discoidal to spherical, but very dominant subrounded to subspherical mode with equant to very slightly prismoidal grain dimensions; well distributed specks of ashy material, and spotty calcite; transitional composition between sublithic arenite and lithic quartz arenite; note increased ratio of (moncrystalline and polycrystalline) silica/quartz to amophous silica/glass shards; while percentage of lithics and mafic minerals decreases, the diversity increases; distinctive variegated greenstone rock fragments, well-distributed red to reddish orange jasper and greenish yellow epidote. Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 15, 2014 01:33 Craig Silva, Ralph Winkelman This was the first sample of the well that was almost entirely disaggregated. Despite the overall poor sample quality, this sample was relatively "clean". Gas Show 8493' MD 8528' MD 8147.84' TVD 8182.83' TVD Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 9 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: Country: Averages Before During After Maximum ROP (fph) 54 48 49 129 WOB 11 9 7 20 RPM 39 22 17 44 Mud Weight 9.4 9.4 9.4 9.4 Chloride 16,500 16,500 16,500 16,500 Total Gas 54 54 38 203 C1 (ppm) 10,024 10,478 7,742 40,053 C2 (ppm) 38 62 25 238 C3 (ppm) 10 12 9 90 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence 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: 8885' MD 9015' MD 8539.74' TVD 8669.73' TVD Craig Silva, Ralph Winkelman Thick intervals of conglomeratic sand and conglomerate, with their assumed potential for significant fluid movement, have been rare at North Fork. Porosity and permeability for this zone can only be guessed at without a reference to a similar produced zone. These conglomerates are not dominated by a single characteristic of cementation or matrix fill but, as with many of the NFU sandstones, display intergrain support that is complex and diverse. GAS SHOW Kenai Borough Alaska USA Cook Inlet Energy 50-231-20045-00-00 NFU 24-26 North Fork Miller 37 December 15, 2014 12:53 Conglomerate/Conglomeratic Sand/Sand/Tuffaceous Sandstone/Sandstone = light gray-very light gray with pale brown secondary hues and white specks;very fragile, loose pulverulent ash matrix;medium light gray(SD) to light gray(tuffaceous SS) to variegated gray(CGL) to salt and pepper (SS) to specks of other colors;prominent colorless to pale gray translucent to transparent quartz, trace "mega-shards" of volcanic glass, light to medium gray translucent to opaque cryptosilica, variegated light greenish gray metalithic greenstones and distinctive trace-rare dusky red (jasper), orange (metavolcanics), greenish yellow (epidote) and sparkly microshards;poorly sorted overall from very fine upper to very coarse upper to granules and (4mm) pebbles;both interbedded and massive SS moderately well sorted at fine upper to medium lower;dominantly angular to subangular and subdiscoidal within full range of roundedness and shape;very calcareous (from mineral cement and powdery material) to non-calcareous;trace marginally hard SS;abundant very sharp bit-broken CGL fragments plus well rounded, smooth CGL clasts;rare consolidated CGL with lithic SS clasts. Pixler Plot 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 NFU 24-26 31 6 DAILY REPORTS Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Nov 26, 2014 DEPTH 156 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 140 24 HOUR FOOTAGE 16 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21.00 0.00 358.00 21.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140' 16 0.42 In Hole 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 140 / 140 TVD MW 8.6 VIS 49 PV 9 YP 10 FL 14.0 Gels 5/11/14 CL- 1500 FC 2 SOL 3.9 SD 0 OIL 0/95 MBT 25.0 pH 9.6 Ca+ 20 Alk 0.3 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 Set annular in place. Install pitcher nipple and tie into flow line. Hook up accumulator control lines. Function test diverter. Hook up tie-downs for trip tank return and fill up line. Rig up for picking up drill pipe. Perform AOGCC-observed test of diverter system. Clean triplex pump suction strainer to improve pump rate performance. Test gas sensors. Start AOGCC-observed testing of Pason PVT system and immediately observe some false tank levels. Troubleshoot trip tank sensor and re-calibrate all tanks. AOGCC representative would also not accept the second phase of testing when some of the tank readings appeared unsteady and occasionally jumped to false levels. Pick up HWDP while troubleshooting and correcting PVT system. Finish picking up HWDP. Perform acceptable test of PVT system for AOGCC representative to complete all the state requirements. Pick up 8” Extreme™ mudmotor with 1.2° bend. Make up Bit #1RR. Hold pre-spud/pre-job meeting with all personnel on location to discuss safety and environmental issues, CIE’s expectations for the project and review well control procedures for the diverter. Pick up one stand of HWDP and make up cross-over to mudmotor. Fill hole with drilling fluid and check for leaks on all equipment. Tighten flange on pitcher nipple. Wash in and tag bottom of conductor at 140'. Spud well and drill 12 1/4" hole from 140’ to 156’. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: 2265 Rig-up: 2000 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Nov 27, 2014 DEPTH 431 PRESENT OPERATION Troubleshooting cuttings handling system TIME 24:00 YESTERDAY 156 24 HOUR FOOTAGE 275 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 179.00 1.26 193.43 178.99 243.00 1.29 201.47 242.97 304.00 0.63 181.94 303.96 367.00 0.81 017.61 366.96 430.00 4.03 009.56 429.90 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140 291 5.50 In Hole 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 8.8 VIS 86 PV 15 YP 30 FL 11.5 Gels 19/34/38 CL- 400 FC 2 SOL 6.0 SD 0.25 OIL 0/94 MBT 26.25 pH 9.4 Ca+ 40 Alk 0.20 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 Drill from 156’ to 219’. Circulate two bottoms ups. Pull out of hole to mudmotor. Pick up MWD. Scribe PWD. Pick up NMFC. Plug into MWD and program tools. Pick up and make up one joint of drill pipe. Run in and shallow test MWD tools. Break and lay down joint of drill pipe. Pick up, make up and run in second NMFC and jars. Drill from 219’ to 243’. Observe overload of cuttings in BOS system. Clear trough and system. Troubleshoot and reset crown-o-matic. Repair air-cooling hose on carrier motor. Drill from 243’ to 431’. BOS equipment plugging off with rock cuttings. Shut down and clean all equipment. Note trough is full and spilling into half-tank. Clean half-tank and clear rocks from pump. Build trough extensions to allow excess cuttings to move into half-tank. Use vac truck to remove cuttings. While breaking out of a stand, the dies slipped on a saver sub quill clamp for the top drive. Remove and replace dies. Re-torque saver sub quill clamp. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: 2265 (Rig down of old rig system: 2000) REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Nov 28, 2014 DEPTH 1295 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 431 24 HOUR FOOTAGE 864 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 492.00 4.80 007.60 491.71 679.00 6.79 354.48 677.82 870.00 9.47 345.76 866.50 1058.00 9.00 312.39 1052.07 1247.00 7.58 261.66 1239.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140 1155 23.83 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 248 @ 433 2.9 @ 1087 68.0 70.9 FT/HR SURFACE TORQUE 5410 @ 946 0 @ Sliding 1075.4 4660.0 AMPS WEIGHT ON BIT 33 @ 946 0.3 @ 695 5.9 14.5 KLBS ROTARY RPM 142 @ 740 0 @ Sliding 132.3 128.0 RPM PUMP PRESSURE 1674 @ 946 468 @ 605 1110.8 1504.1 PSI DRILLING FLUIDS REPORT DEPTH 1247 / 1239 TVD MW 9.0 VIS 86 PV 17 YP 34 FL 9.9 Gels 11/24/27 CL- 300 FC 2 SOL 7.0 SD 0.3 OIL 0/93 MBT 31.25 pH 9.9 Ca+ 20 Alk 0.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 23 @ 1163 1.5 @ 870 9.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6443 @ 1163 277 @ 870 876.3 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 5 / 10 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish tightening saver sub clamp. Adjust gripper height. Drill from 431’ to 741’. Pick up, monitor well and check for flow. Drill from 741’ to 1295’. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: 2265 REPORT BY Craig Silva Cook Inlet Energy North Kenai Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Nov 29, 2014 DEPTH 2157 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 1295 24 HOUR FOOTAGE 862 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1310 9.09 261.62 1301.41 1496 16.51 263.59 1482.64 1748 19.20 242.69 242.69 1938 22.74 251.17 251.17 2124 23.28 252.71 252.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140 2017 41.32 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 141.4 @ 1635 4.4 @ 1337 64.1 109.2 FT/HR SURFACE TORQUE 6290 @ 1951 0 @ Sliding 2691.8 4610.0 AMPS WEIGHT ON BIT 27 @ 1934 0.9 @ 1327 13.9 16.4 KLBS ROTARY RPM 111 @ 2107 0 @ Sliding 25.3 10.5 RPM PUMP PRESSURE 1788 @ 2051. 1048 @ 1620 1567.0 1652.7 PSI DRILLING FLUIDS REPORT DEPTH 2062 / 2013 TVD MW 9.4 VIS 60 PV 12 YP 24 FL 8.8 Gels 7/20/24 CL- 350 FC 2 SOL 6.0 SD 0.2 OIL 0/94 MBT 25.0 pH 9.0 Ca+ 20 Alk 0.22 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 46 @ 1981 4 @ 1333 14.6 TRIP GAS CUTTING GAS @ @ WIPER GAS 26 (at 1621') CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9278 @ 1981 916 @ 1333 2945.2 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 16 / 23 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 1295’ to 1621’. Circulate two bottoms up. Monitor well. Synchronize rig generator. Pull out of hole wet on wiper trip from 1621’ to 1371’. Monitor well. Blow down topdrive. Fill trip tank. Continue pulling out of hole on wiper trip from 1371’ to top of HWDP at 806’. Monitor well. Run back in hole (SLM) from 806’ to 1558’. Kelly up topdrive. Wash down from 1558’ to bottom at 1621’ and continue drilling ahead. Drill from 1621’ to 2157’. CANRIG PERSONNEL ON BOARD 2 DAILY COST - DML: 2265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Nov 30, 2014 DEPTH 2946 PRESENT OPERATION Preparing for wiper trip at surface casing point TIME 24:00 YESTERDAY 2157 24 HOUR FOOTAGE 789 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2190 24.13 250.14 2131.29 2377 24.46 246.83 2185.95 2567 24.17 248.59 2474.54 2693 23.81 247.54 2589.50 2881 24.37 247.36 2761.39 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140 2806 57.32 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 192.2 @ 2505 2.1 @ 2278 65.6 35.0 FT/HR SURFACE TORQUE 9350 @ 2774 0 @ Sliding 6979.6 7580.0 AMPS WEIGHT ON BIT 31 @ 2591 1 @ 2885 22.2 28.3 KLBS ROTARY RPM 155 @ 2492 0 @ Sliding 59.1 71.7 RPM PUMP PRESSURE 1976 @ 2632 1092 @ 2366 1785.4 1822.8 PSI DRILLING FLUIDS REPORT DEPTH 2946 / 2820 TVD MW 9.4 VIS 55 PV 10 YP 17 FL 9.7 Gels 8/17/18 CL- 250 FC 2 SOL 6.5 SD 0.2 OIL 0/94 MBT 17.5 pH 9.6 Ca+ 40 Alk 0.40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 53 @ 2919 8 @ 2340 19.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10509 @ 2919 1593 @ 2330 3924.5 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 11 / 14 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue drilling ahead from 2157’ to 2320’. Lose function of rig pump #3. Break and lay down last in-string stand in V-door. Pull out of hole one more stand from 2311’ to 2250’. Monitor well. Troubleshoot and work on pump #3 motor. Change out topdrive gripper dies. Replace #1 transmission shifter. Clean and prep rig floor before running back in hole. Run back in hole (one stand) from 2250’ to 2311’. Pick up and make up last stand in V-door. Break circulation and wash down from 2311’ to 2320’. Circulate out 4’ of fill. Drill ahead from 2320’ to 2472’. Check for flow. Drill from 2472’ to 2946’ (surface casing point). Circulate hole clean. Check flow. Pump pill. Blow down lines. CANRIG PERSONNEL ON BOARD 2 DAILY COST .. DML: 2265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Dec 01, 2014 DEPTH 2946 PRESENT OPERATION Preparing to run 9 5/8" Casing TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 0 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2946 (Projection) 24.20 247.36 2820.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR 12.25 HCC MXL1 5231971 3x20, 1x10cj 140 2946 2806 57.32 2-2-WT-A-E-I-ER-TD Surface casing point 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 2946 / 2820 TVD MW 9.1 VIS 49 PV 7 YP 15 FL 12.6 Gels 6/18/19 CL- 200 FC 2 SOL 6.0 SD 1.0 OIL 0/94 MBT 17.5 pH 9.6 Ca+ 40 Alk 0.35 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS 89 (at 2946) 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 of hole from 2946’ (SLM) to 806’ (top of HWDP) Monitor well (static). Continue pulling out of hole to 151’ (top of NM flex collars). Work back through, wipe and clean tight (20K to 40K over-pull) spots at 2450’, 2032’, 1906’, 1749’, 540’ on way out. Hole took proper fill. Service rig. Monitor well (static). Clean rig floor. Run back in hole from 151’ (SLM in) to 2378’. Observe broken hydraulic hose to elevator actuator assembly. Kelly up and fix hose. Continue running in hole from 2378’ to 2884’. Kelly up and wash down from 2884’ to bottom at 2946’ (with no fill). Circulate (staging-up pump output to 500 gpm) and condition hole. Record 89 units of wiper gas on first bottoms up. Circulate mud weight down 9.2 ppg. Pull out of hole from 2946’ to surface, laying down jars and all directional tools on way out. Clear and clean rig floor and make preparations for running 9 5/8” surface casing. Pick up and rig up all Weatherford casing running tools. Change out bails (from short to long). CANRIG PERSONNEL ON BOARD 2 DAILY COST . . DML: 2265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Dec 02, 2014 DEPTH 2946 PRESENT OPERATION Preparing to cement 9 5/8" Casing TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 0 CASING INFORMATION 16" Conductor at 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2946 24.20 247.36 2820.68 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 2946 / 2820 TVD MW 9.1 VIS 36 PV 6 YP 7 FL 12.5 Gels 3/19/30 CL- 200 FC 1 SOL 6.0 SD .001 OIL 0/94 MBT 17.5 pH 9.3 Ca+ 20 Alk 0.3 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 11 (at 2946) 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 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue rigging up to run 9 5/8” surface casing. Hold pre-job meeting on running casing with Weatherford hands, company representatives and crew. Pick up, make up and run in hole with shoe and float joint. Check floats (OK). Continue running in hole with 9 5/8” casing as per CIE. Fill pipe on the fly and top off every 5 joints. Continue running casing in hole, with no issues on way in, to 2946’. Make topdrive and crossover assembly to 9 5/8” casing. Break circulation and stage up pump output to 400 gpm. No mud losses observed during circulating. Record 11 units of trip gas during first circulation. Cementers leave location (for priority cement job with other customer). Continue circulating while waiting on cementers. Rig up cellar pump. Change liners in #3 mud pump. Cementers return to location. Rig up cementers. Hold pre-job meeting on cementing operations with current crew and all other hands. Install plugs in cementing head. CANRIG PERSONNEL ON BOARD 2 DAILY COST . DML: 2265 REPORT BY Craig Silva Cook Inlet Energy Noth Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Rod Maniaci DATE Dec 03, 2014 DEPTH 2946 PRESENT OPERATION Complete all nipple down and pad clean-up procedures TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2946' 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk 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 Move unneeded subs and equipment from middle of rig floor to their proper place. Lift Weatherford slips to V-door side of rig prior to continuing cementing operations. Hold longer, more detailed pre-job meeting on cementing operations with newly arrived crew and all other hands. Perform cementing operations as per CIE. Fill and test cementing lines to 2500psi. Batch and test 9.6 ppg spacer. Pump 40 bbls of 9.6 ppg spacer at 2-3 bpm, then follow with 285 bbls of 12.5 ppg lead cement at 3-5 bpm and then 41 bbls of 14.8 bbls of tail cement at 2 bpm. Drop bottom plug and displace with 219 bbls of 9.2 ppg mud. (Excess cement returns going to cellar and continuously flushed and pumped out throughout displacement and clean-up operations). Bump plug at 06:30 hours. Cement in place. No flow-back. Blow down pumps and flush stack and lines. Flush and wash cellar until free of cement. Flush annular completely clean while it is being functioned. Clear rig floor of all remaining casing running and handling equipment. Clean rig floor. Perform inspection, minor prep work and troubleshooting of bridge cranes before doing upcoming heavy lifting. Re- connect accumulator hoses. Manage movement and re-positioning of office trailer and new company man living quarters. Disassemble and rig- down flow line and pitcher nipple. Change out liners in #1 and #2 mud pumps. Change shaker screens. Clean pits. Nipple down diverter line. Pick up Hydril. Cut casing. Move boxes of cement. Clean containment area. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: 2265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Steve Ratcliff DATE Dec 04, 2014 DEPTH 2946 PRESENT OPERATION Nippling up BOPE TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"' at 2946' 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk 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 nippling down diverter. Disassemble diverter and ready sections for transport. Cut and remove 13 5/8” wellhead. Finish top of 13 3/8” casing. Make rough cut on 9 5/8” casing and remove section. Perform final cut and prep top of 9 5/8” casing. Weld 11” wellhead on 9 5/8” casing and wait to cool down. Test seal assembly. Test wellhead. Prep and rig up to install/nipple up BOPs. Finish cleaning pits in preparation for KLA- Shield mud system. Begin building KLA-Shield mud system in pits (using Pit #3 as a batch mixing pit and then distributing fluid to other pits). Make up Hydril, Double Gate, Mud Cross, Single Gate, DSA and Spool, and all associated valves. Reposition BHI MWD/LWD tools on location to create unobstructed nearby working area for forklift. CANRIG PERSONNEL ON BOARD 4 DAILY COST 3265 REPORT BY Craig Silva Cook Inlet Energy North Fork DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Steve Ratliff DATE Dec 05, 2014 DEPTH 2946 PRESENT OPERATION Making up directional/LWD tools of BHA TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2946' 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 2 8.75 NOV SKH519M A19180 5x14 2946 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 2946 / 2820 TVD MW 8.7 VIS 60 PV 9 YP 14 FL 9.0 Gels 6/9/11 CL- 17000 FC 1 SOL 4.0 SD 4.0 OIL 0/96 MBT pH 10.3 Ca+ 40 Alk 3.30 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 building KLA-Shield mud system. Nipple up BOP stack. Hook-up and function test accumulator lines. Remote worked properly. Re- attach choke and kill lines. Secure stack with turnbuckles. Set mousehole. Rig up elevators. Make up and set test joint/test plug. Fill stack. Perform shell test to 250 psi Low / 4000 psi High. Observe leak at kill hose hub connection. Fix leak. State representative arrives to witness BOPE testing. Test all BOPE as per C.I.E. procedures. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test all other BOPE (dart valve, upper Kelly, upper pipe rams, CMVs 10-11-12-6-9-8, lower Kelly, outside kill, floor valve, CMVs 4-1-2-5-7, inside kill, lower pipe rams, HCR, in- line choke, blind rams, CMVs 4-7-3) to 250 psi Low / 4000 psi High for 5 minutes each. Pull test joint/test plug. Set wear bushing. Perform accumulator drawdown test. Blow down choke and mud lines. Pick up BHA. Change bend on mudmotor to 1.1 degrees. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Steve Ratliff DATE Dec 06, 2014 DEPTH 3273 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 2946 24 HOUR FOOTAGE 327 CASING INFORMATION 9 5/8" AT 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2968 24.49 247.79 2840.60 3031 24.27 248.03 2897.99 3094 24.18 247.81 2955.44 3158 24.18 247.76 3013.82 3220 24.06 247.91 3070.41 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75 NOV SKH519M A19180 5x14 2946 327 6.50 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 335.0 @ 3086 3.1 @ 2965 73.7 113.3 FT/HR SURFACE TORQUE 13000 @ 2947 6000 @ 2950 9100 10000.0 AMPS WEIGHT ON BIT 20 @ 2964 1 @ 2977 7.2 6.2 KLBS ROTARY RPM 107 @ 2948 1 @ 3256 27.8 34.5 RPM PUMP PRESSURE 1488 @ 3090 731 @ 2947 1223.2 1374.3 PSI DRILLING FLUIDS REPORT DEPTH 3210 / 3061 MW 8.9 VIS 44 PV 9 YP 14 FL 7.5 Gels 5/7/9 CL- 17000 FC 1 SOL 2.0 SD 0 OIL 0/98 MBT 2.5 pH 10.1 Ca+ 40 Alk 2.54 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 40 @ 3147 0 @ 2950 13.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8162 @ 3147 185 @ 2950 3052.2 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 12 / 17 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Tuffaceous Siltstone. Minor Coal/Carbonaceous Material/Carbonaceous Shale, Tuffaceous Sandstone/Sandstone, Volcanic Ash PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE..........TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Continue to pick up, make up and run in hole with BHA. Load nuclear sources. Finish picking up BHA and running in to 426’. Attempt to shallow test directional/LWD tools (at 220 spm, 350 gpm, 690 psi). Unable to sustain high enough pump rate to function LWD downhole tools properly. Slip drill line . Reset block height and crown-o-matic. Crossover and continue running in hole with 5” drill pipe from 426’ to 2837’. Kelly up and wash down from 2837’ to tag top of cement at 2870’. Rig up and perform casing test (at 3000 psi for 30 minutes). Continue drilling out cement and remaining shoe tract from 2870’ to 2946’ (cement, float at 2890’, cement, casing shoe at 2938’, rat hole to 2946’). Drill new hole from 2946’ to 2970’. Circulate bottoms up and continue circulating, adding Desco II and Bicarb mud products to deal with thick mud and cement flocculation. Displace old mud with 30 bbl Hi-Vis spacer in front of 200 bbls 9.0 ppg Kla-Shield mud. Continue to circulate and condition with new mud and reduce mud weight to 8.85 ppg as per drill cite manager. Cease pumping and perform Formation Integrity Test to 13.62 EMW. Blow down stack and choke. Line back up for hard shut-in. Drill ahead from 2970’ to 3273’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Steve Ratliff DATE Dec 07, 2014 DEPTH 4298 PRESENT OPERATION Drilling Ahead TIME 24:00 YESTERDAY 3273 24 HOUR FOOTAGE 1025 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3283 23.93 248.17 3127.97 3535 23.73 247.62 3358.55 3789 23.12 246.77 3591.68 4044 22.56 245.42 3826.90 4299 22.57 246.89 4061.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75 NOV SKH519M A19180 5x14 2946 1352 21.37 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 232.7 @ 3500 2.4 @ 4076 101.5 115.6 FT/HR SURFACE TORQUE 14470 @ 4163 290 @ 4070 10471.5 11900.0 AMPS WEIGHT ON BIT 37 @ 3889 0.5 @ 3887 6.2 8.8 KLBS ROTARY RPM 56 @ 4063 1 @ 3794 20.7 2.3 RPM PUMP PRESSURE 1989 @ 4056 1146 @ 4215 1542.3 1738.0 PSI DRILLING FLUIDS REPORT DEPTH 4069 / 3850 TVD MW 9.3 VIS 48 PV 13 YP 18 FL 5.8 Gels 6/7/8 CL- 22000 FC 1 SOL 6.0 SD 0.15 OIL 0/94 MBT 2.5 pH 9.9 Ca+ 40 Alk 3.45 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 81 @ 4162 1 @ 4069 33.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 35 (at 4036) CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17608 @ 4162 459 @ 4073 6863.7 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 18 / 44 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Claystone, Tuffaceous Siltstone. Minor Coal/Carbonaceous Material/Carbonaceous Shale, Tuffaceous Sandstone/Sand/Non-Differentiated Sandstone, Volcanic Ash PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE..........CARBONACEOUS CLAYSTONE/COAL..........TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Drill ahead from 3273’ to 4036’. Circulate bottoms up and continue circulate and condition hole. Check flow. Pull out of hole on wiper trip from 4036’ to 2693’. Hold BOP drill and hold group meeting. Service rig. Run back in hole from 2963’ to 3974’. Kelly up and wash down from 3974’ to bottom at 4036’. Drill from 4036’ to 4298’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3265 REPORT BY Craig Silva Cook Inlet Energy Noth Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Steve Ratliff DATE Dec 08, 2014 DEPTH 5490 PRESENT OPERATION Circulating hole clean before Wiper Trip TIME 24:00 YESTERDAY 4298 24 HOUR FOOTAGE 1192 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4361 22.39 246.63 4119.10 4614 21.19 245.98 4353.99 4866 21.14 247.49 4589.03 5180 19.83 247.11 4883.03 5432 19.97 246.17 5120.75 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75 NOV SKH519M A19180 5x14 2946 25.44 37.55 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 234.9 @ 5237 0.2 @ 4757 90.9 69.6 FT/HR SURFACE TORQUE 17860 @ 5111 11 @ 5482 10716.6 14.5 AMPS WEIGHT ON BIT 35 @ 5111 0.3 @ 5406 6.8 9.4 KLBS ROTARY RPM 40 @ 4441 0 @ 5258 16.3 22.0 RPM PUMP PRESSURE 2535 @ 5111 1163 @ 5483 1710.7 1434.5 PSI DRILLING FLUIDS REPORT DEPTH 5340 / 5034 TVD MW 9.3 VIS 65 PV 24 YP 28 FL 4.7 Gels 5/8/8 CL- 16000 FC 1 SOL 6.0 SD 0.1 OIL 1/93 MBT 5.0 pH 9.6 Ca+ 40 Alk 2.60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 177 @ 5438 2 @ 4754 46.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 43325 @ 5177 887 @ 4754 9037.9 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 9 / 56 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Sandstone/Sandstone/Sand, Tuffaceous Claystone, Tuffaceous Siltstone, Coal/Carbonaceous Shale/Carbonaceous Material. Minor Non-Differentiated Sandstone, Volcanic Ash. Trace Calcareous Tuff. PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/SANDSTONE/SAND..........TUFFACEOUS SILTSTONE/TUFFACEOUS CLAYSTONE.......... DAILY ACTIVITY SUMMARY Drill from 4298' to 5490'. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3265 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 9, 2014 DEPTH 6143 PRESENT OPERATION Drilling Ahead TIME 24:00 YESTERDAY 5490 24 HOUR FOOTAGE 653 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5522 18.37 245.32 5206.01 5649 17.05 244.24 5326.99 5837 16.60 243.59 5506.92 6023 15.70 243.42 5685.51 6151 11.74 244.23 5809.94 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75 NOV SKH519M A19180 5x14 2946 3197 47.33 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 306.3 @ 5641 3.1 @ 5691 82.3 74.7 FT/HR SURFACE TORQUE 17560 @ 5912 0 @ Sliding 12242.4 15.2 AMPS WEIGHT ON BIT 35 @ 6045 1 @ 5895 10.7 7.8 KLBS ROTARY RPM 56 @ 6031 0 @ Sliding 20.4 24.0 RPM PUMP PRESSURE 2556 @ 6081 1336 @ 5516 2109.7 2336.7 PSI DRILLING FLUIDS REPORT DEPTH 6053 / 5714 TVD MW 9.3 VIS 67 PV 25 YP 25 FL 4.6 Gels 5/7/9 CL- 20000 FC 1 SOL 6.0 SD 0.1 OIL 1/93 MBT 5.0 pH 9.8 Ca+ 40 Alk 3.10 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 319 @ 5987 8 @ 6113 58.3 TRIP GAS CUTTING GAS @ @ WIPER GAS 41 (at 5490) CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 63435 @ 5987 2126 @ 5538 10715.6 CONNECTION GAS HIGH ETHANE (C-2) 244 @ 5987 4 @ 6001 3.9 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 8 / 23 PENTANE (C-5) @ @ HYDROCARBON SHOWS Minor gas show at Tyonek "5600" Sand INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5908-5922 Tuffaceous Sandstone with abundant ash matrix. Visual porosity looks poor due to matrix volume, but SS disaggregates easily suggesting fair permeability. High gas: 155U, Avg thru intvl: 140U, Back ground: 111U Tuffaceous SS: med gry, pl yel brn sec hue; dom mod w srtd at fnU-mL; sbdiscdl-sbspher; complex mtrx+gr supprt; all mod-mod strng evsc in HCL; v ashy sublithic aren. LITHOLOGY Major Tuffaceous Sandstone/Sandstone/Sand, Tuffaceous Siltstone, Tuffaceous Claystone, Coal/Carbonaceous Shale, Minor Non- Differentiated Sandstone, Volcanic Ash, Calcareous Tuff. PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/SANDSTONE/SAND..........TUFFACEOUS SILTSTONE-CLAYSTONE.......... DAILY ACTIVITY SUMMARY Circulate bottoms up at 5490’ and continue to condition mud. Check flow. Pull out of hole on Wiper Trip from 5490’ to 4797’. Pump 9.5 ppg dry job. Continue to pull out of hole on Wiper Trip from 4797’ to 1513’. Pick up and make agitator and shock sub. Service rig. Conduct BOP drill. Run back in hole from 1513’ to (just outside shoe) at 2989’. Briefly circulate and fill pipe. Calibrate block height. Continue running back in hole from 2989’ to 5391’. Kelly up and break circulation. Wash down from 5391’ to bottom at 5490’. (No fill on bottom). Drill ahead from 5490’ to 6143’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 10, 2014 DEPTH 6837 PRESENT OPERATION Pumping dry job for trip out of hole TIME 24:00 YESTERDAY 6143 24 HOUR FOOTAGE 694 CASING INFORMATION 9 5/8" @ 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6214 10.24 248.35 5871.78 6340 7.12 250.92 5996.33 6529 4.53 248.06 6184.31 6656 2.74 240.63 6311.04 6783 1.24 239.66 6437.96 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 214.9 @ 6200 1.1 @ 6548 76.5 76.7 FT/HR SURFACE TORQUE 18480 @ 6243 0 @ Sliding 12485.8 18390.0 AMPS WEIGHT ON BIT 20 @ 6231 0.2 @ 6576 6.6 5.4 KLBS ROTARY RPM 57 @ 6764 0 @ Sliding 11.5 30.8 RPM PUMP PRESSURE 2622 @ 6571 1686 @ 6835 2319.7 1922.7 PSI DRILLING FLUIDS REPORT DEPTH 6837 / 6492 TVD MW 9.6 VIS 68 PV 22 YP 26 FL 4.8 Gels 6/8/9 CL- 18000 FC 1 SOL 6.0 SD 0.1 OIL 1/93 MBT 7.0 pH 9.5 Ca+ 40 Alk 2.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 190 @ 6604 6 @ 6266 31.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 47 (at 6648) CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 29552 @ 6395 1179 @ 6266 6584.5 CONNECTION GAS HIGH ETHANE (C-2) 97 @ 6305 1 @ 6295 1.5 AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a (POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS Two minor gas shows, the "6000" Sand and another small sand. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 1) 6311-6339, 2) 6400-6415 Both zones with similar lithology of Tuffaceous Sandstone. Poor visual porosity due to volcanic ash matrix volume. All samples easily separated so suspect fair permeability. 1)Range only 48-74u, but background at 8u; 2) Rand 50-111u, background at 12u Tuffaceous SS: med gray, pl yel brn sec hue; dom mod w srtd at fnU-mL; sbdiscdl- sbspher;complex mtrx-gr spprt; gen strng evsc in HCL; ashy sublithic aren. LITHOLOGY Major Tuffaceous Sandstone/Sandstone/Sand, Tuffaceous Siltstone, Tuffaceous Claystone, Coal/Carbonanaceous Shale. Minor Volcanic Ash, Calcareous Tuff. Trace Non-Differentiated Sandstone. PRESENT LITHOLOGY TUFFACEOUS SANDSTONE..........TUFFACEOUS SILTSTONE-CLAYSTONE.......... DAILY ACTIVITY SUMMARY Drill from 6143’ to 6648’. Circulate bottoms up. Check for flow. Pull out of hole on wiper trip from 6648’ to 5490’. Service wash pipe. Run back in hole from 5490’ to 6586’. Break circulation and wash down from 6586’ to 6648’ with no fill. Pick up and make up stands in the mousehole. Continue drilling ahead from 6648’ to 6837’. Note 400psi drop in pump pressure. Circulate bottoms up while reciprocating pipe. Continue to circulate and condition hole while building a dry job. Pull out of hole 5 stands from 6837’ to 6682’. Pump 20 bbl (10.8ppg) dry job. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 11, 2014 DEPTH 6837 PRESENT OPERATION Testing BOPE TIME 24:00 YESTERDAY 6837 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6837 (Projected) 0.52 (Projected) 239.66 6491.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75 NOV SKH519M A19180 5x14 2946 6837 3891 58.39 1-2-CT-S-X-I-WT-PP Apparent BHA tool failure 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 6837 / 6492 TVD MW 9.3 VIS 63 PV 22 YP 26 FL 4.6 Gels 6/8/10 CL- 18000 FC 1 SOL 6.0 SD 0.1 OIL 1/93 MBT 7.0 pH 9.5 Ca+ 40 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 Pull out of hole (SLM) from 6522’ to 5391’. Detect small fragments of hard plastic and metal falling down onto the rig floor. Stop all activity and investigate all the way up to the crown. On top of the derrick, observe that the Pason Block Height Sensor is shattered, the bolts retaining the mount for the sensor immediately adjacent the fast crown block sheave are broken and most had fallen down, and the mount itself was sheared away by severe impact and then wedged next to the sheave support frame. The damage was photographed and then all loose and/or damaged materials and equipment were cleared, moved and/or secured to mitigate the hazards of flying debris. Continue pulling out of hole (SLM) from 5391’ to 1538’. Break, wash out, lay down and off load agitator and shock sub. Continue pulling out of hole (SLM) from 1538’ to top of HWDP at 822’. Continue pulling out of hole with HWDP to 198’ and with lower assembly flex collars to 139’. Pull stand to CCN tool and remove sources. Remove, clean and re-install screen. Pull, break and lay down all LWD tools. Pull to Ontrak tool. Plug-in and download all memory data. Break, lay down and inspect bit. Finish breaking and laying down LWD tools. Clear rig floor and prep for testing BOPE as per C.I.E. Pull wear ring. Rig up and install all test equipment and tools. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test all other BOPE (upper pipe rams, dart valve, upper Kelly, CMVs 12-11-10, check valve, upper pipe rams, TIW, lower Kelly, CMVs 6-9-8-1, outside kill) to 250 psi Low / 4000 psi High for 5 minutes each. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 12, 2014 DEPTH 6852 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 6837 24 HOUR FOOTAGE 15 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6844 1.06 235.02 6498.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 15 0.20 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 168.4 @ 6846 41.3 @ 6849 89.6 82.7 FT/HR SURFACE TORQUE 15750 @ 6842 15260 @ 6846 16648.6 15440.0 AMPS WEIGHT ON BIT 4 @ 6842 0 @ 6849 1.7 1.3 KLBS ROTARY RPM 30 @ 6842. 21 @ 6851 27.0 27.2 RPM PUMP PRESSURE 1765 @ 6847. 1066 @ 6845.00000 1597.7 1728.3 PSI DRILLING FLUIDS REPORT DEPTH 6837 / 6492 TVD MW 9.3 VIS 72 PV 22 YP 25 FL 4.6 Gels 6/8/10 CL- 18000 FC 1 SOL 6.0 SD 0.1 OIL 1/93 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.10 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 23 @ 6842 20 @ 6850 24.4 TRIP GAS 105 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6308 @ 6852 4909 @ 6852 5594 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 22 / 27 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Sandstone/Sandstone/Sand, Tuffaceous Siltstone-Claystone. Minor Coal, Volcanic Ash. PRESENT LITHOLOGY COAL..........TUFFACEOUS SILTSTONE..........TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Continue testing BOPE (CMVs 2-7-5, inside kill, HCR, manual choke, lower pipe rams, blind rams, CMVs 3,4) to 250 psi Low / 4000 psi High for 5 minutes each. Perform accumulator drawdown test. Tested super choke and manual choke to 1000psi. Set wear ring and lay down test joint. Rig up Pollard Wireline. Pick up, make up and run in hole with CBL logging assembly. Log surface casing interval and pull out of hole. Rig down wireline equipment. Clear rig floor. Pick up, make up and run in hole bit, mudmotor and LWD tools to CCN collar. Load sources. Continue running in hole with remaining lower assembly tools and HWDP to 822’. Prep to pick up 5” drill pipe. Pick up, make up and continue running in hole with 8 single joints of drill pipe to 1071’. Hold BOP drill. Check crown-o-matic. Continue to pick up, make up and run in hole with 14 more single joints of drill pipe to 1511’. Pick up and make up agitator and shock sub. Continue to pick up, make up and running in hole with 84 more single joints of drill pipe (106 joints total) to 4184’. Fill pipe and break circulation. Dynamic test MWD-LWD tools. Continue to run in hole with stands of drill pipe to 6774’. Kelly up. Set depth and do check survey. Wash down from 6774’ to bottom at 6837’. Lose 28 bbls of mud over shakers during initial circulation. Circulate hole clean while washing down. Record 105 units of trip gas. Drill from 6837’ to 6852’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 13, 2014 DEPTH 7596 PRESENT OPERATION Troubleshooting pressure loss problem TIME 24:00 YESTERDAY 6852 24 HOUR FOOTAGE 744 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6906 1.00 233.24 6560.94 7093 0.74 290.62 6747.91 7283 0.62 279.36 6937.90 7411 0.48 287.34 7065.90 7535 0.31 292.31 7189.89 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 759 12.20 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 167.7 @ 6984 13.9 @ 6860 69.1 27.6 FT/HR SURFACE TORQUE 19930 @ 7574 10 @ 7023 17957.3 19530.0 AMPS WEIGHT ON BIT 16 @ 6937 0.2 @ 7212 7.1 7.5 KLBS ROTARY RPM 56 @ 6898 10 @ 7283 23.7 31.6 RPM PUMP PRESSURE 2588 @ 7232 1382 @ 6856 2240.6 1445.2 PSI DRILLING FLUIDS REPORT DEPTH 7593 / 7248 TVD MW 9.3 VIS 73 PV 24 YP 25 FL 4.2 Gels 5/7/8 CL- 17000 FC 1 SOL 6.0 SD 0.1 OIL 1/94 MBT 6.25 pH 9.7 Ca+ 40 Alk 2.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 309 @ 7036 6 @ 7367 49.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 60790 @ 7036 1524 @ 7367 10127.7 CONNECTION GAS HIGH ETHANE (C-2) 526 @ 7036 0 @ 46.4 AVG PROPANE (C-3) 184 @ 7036 0 @ 12.5 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 5 / 12 PENTANE (C-5) @ @ HYDROCARBON SHOWS 6 potential Gas Show intervals. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 1)6990-7005; 2)7040- 7080; 3) 7115-7125; 4) 7135-7160; 5) 7175-7185; 6) 7379-7427 All six zones are dominated by calcareous tuffaceous sandstone that appears to "clean up" in thin intervals; overall the matrix volume of each SS is significant and the visual porosity is poor to marginally fair. The fragility of the SSs suggest fair perms. MAX GAS: 1)110u, 2) 231u, 3)141u, 4)60u, 5)273u, 6)38u; Overall background is 5u Very closely associated lithology in all 6 cases. Tuffaceous SS: med gray, pl yel brn sec hues; dom mod wsrted at fU-mL; subrd-sbdiscdl,ang-sbspher, complex ashy calcareous matrx, strng evsc; both mtrx and gr spprtd; ashy sublithic arenite; 15-20% metalith rk frgs and maf mnrls. LITHOLOGY Major Tuffaceous Sandstone/Non-Differentiated Sandstone/Sand, Tuffaceous Siltstone, Tuffaceous Claystone, Coal/Carbonaceous Shale. Minor Volcanic Ash. Trace Calcareous Tuff. PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/NON-DIFFERENTIATED SANDSTONE/SAND DAILY ACTIVITY SUMMARY Drill from 6852’ to 7340’. Pull off bottom and circulate. Hold pre-job meeting with Pason technician who arrived on location to install new block height sensor on top of crown. Circulate while technician is performing installation. Installation fails due failure of glue to adhere to metal. Prep for drilling ahead while technician returns to rig floor. Drill ahead from 7340’ to 7596. After 7466’, observe progressive pressure loss from 2250 psi to 1400 psi. Troubleshoot pressure loss. Pressure test mud pump #3. Pull last stand out of hole to 7593’ and stand back. Circulate and reciprocate while inspecting mud pump #3 and #3 charge pump. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 14, 2014 DEPTH 8522 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 7596 24 HOUR FOOTAGE 926 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7598 0.39 315.61 7252.89 7848 0.28 250.03 7502.89 8099 0.68 166.10 7753.88 8351 0.87 151.37 8005.86 8537 1.18 138.45 8181.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 1685 27.11 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 697.6 @ 7967 4.4 @ 8105 69.5 66.5 FT/HR SURFACE TORQUE 22650 @ 8127 19 @ 8400. 13680.8 20.8 AMPS WEIGHT ON BIT 22 @ 8127 0 @ 7842. 7.5 8.7 KLBS ROTARY RPM 56 @ 8127 0 @ 8364 28.5 39.9 RPM PUMP PRESSURE 2774 @ 7976 2098 @ 7694 2558.9 2481.1 PSI DRILLING FLUIDS REPORT DEPTH 8444 / 8099 TVD MW 9.4 VIS 65 PV 27 YP 28 FL 4.5 Gels 5/7/8 CL- 16000 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 6.225 pH 9.5 Ca+ 40 Alk 2.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 262 @ 7926 8 @ 8445 41.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 10 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 49318 @ 7926 1812 @ 8445 8264.6 CONNECTION GAS HIGH ETHANE (C-2) 2919 @ 7800 0 @ 8027 72.6 AVG PROPANE (C-3) 206 @ 7926 0 @ 7875 13.6 CURRENT BUTANE (C-4) 91 @ 8332 0 @ 8323 0.5 CURRENT BACKGROUND/AVG 52 / 225 PENTANE (C-5) @ @ HYDROCARBON SHOWS Significant gas show with good characteristics at report depth INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8495-8462 Sand is almost entirely disaggreagated and thus is different from all of the other tuffaceous sandstones with shows. Porosity and permeability indeterminate due loose grains, but probably is good. Entire sand over 100u; avg at 197u and Max at 288u Tuffaceous SS that, except for traces is all disaggregated loose sand; light gray, fn-med, m w srtd, subrndd-sbang, subspher-subdiscdl; closer to lithic quartz arenite; prob good por/perm LITHOLOGY Major Tuffaceous Siltstone/Claystone, Tuffaceous Sandstone/Non-Differentiated Sandstone/Sand, Coal/Carbonaceous Shale, Minor Volcanic Ash, Calcareous Tuff. PRESENT LITHOLOGY SAND.......... DAILY ACTIVITY SUMMARY Pull out of hole from 7561’ looking for washout. Discover washout at 6992’. Replace washed out joint with new joint. Pump and circulate after replacing joint to check system all the way around. Run back in hole from 6992’ to 7530’. Kelly up and wash down from 7530’ to 7596’ with no fill. Drill from 7596’ to 8522’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Al Lunda Monie Sainz DATE Dec 15, 2014 DEPTH 9058 PRESENT OPERATION Circulating and reaming while repairing mud pumps TIME 24:00 YESTERDAY 8522 24 HOUR FOOTAGE 536 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8664 1.36 135.25 8318.80 8726 1.47 133.11 8380.78 8790 1.64 130.12 8444.76 8852 0.85 139.89 8506.74 8914 0.62 142.32 8568.74 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 2221 39.03 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 192.3 @ 8660 2.0 @ 8937 59.5 9.5 FT/HR SURFACE TORQUE 23990 @ 8946 20440 @ 9449 20989.7 20790.0 AMPS WEIGHT ON BIT 20 @ 8935 0.3 @ 9052 9.8 5.2 KLBS ROTARY RPM 55 @ 8701 0 @ 8789. 21.0 39.8 RPM PUMP PRESSURE 2855 @ 8834 1388 @ 8971 2601.9 1442.9 PSI DRILLING FLUIDS REPORT DEPTH 9034 / 8689 TVD MW 9.4 VIS 60 PV 25 YP 26 FL 4.2 Gels 5/7/7 CL- 16500 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 6.25 pH 9.4 Ca+ 40 Alk 1.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 289 @ 8532 14 @ 9047 52.6 TRIP GAS CUTTING GAS @ @ WIPER GAS 59 (at 8970) CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 59835 @ 8873 773 @ 8973 10197.8 CONNECTION GAS HIGH ETHANE (C-2) 521 @ 8532 1 @ 8838 70.8 AVG PROPANE (C-3) 159 @ 8532 0 @ 8838 18.3 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS Gas show at several zones close to report depth INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION From 8885' to report depth at 8058' Sand/Tuffaceous Sandstone/Conglomeratic Sand/Conglomerate. Obvious possibilities for high permeabilities in Conglomerates. Max 203u; consistent moderate background of 38u thru most of section. Each "channel" with over 120u Sand/Tuff SS/CGL Sd/CGL: med lt gry and poly-gry, med sd to peb cgl, p srtd,gen tuf matrx, full range of grain characteristics, mixed v calc and non-calc; mod diverse lithics group. LITHOLOGY Major Tuffaceous Siltstone-Claystone, Tuffaceous Sandstone/Sand/Non-Differentiated Sandstone, Conglomeratic Sand/Conglomerate, Coal/Carbonaceous Shale. Minor Volcanic Ash, Calcareous Tuff. Trace Consolidated Conglomerate. PRESENT LITHOLOGY ..........SAND..........CONGLOMERATIC SAND..........CONGLOMERATE.......... DAILY ACTIVITY SUMMARY Drill from 8522’ to 8970’. Circulate bottoms up. Flow check. Pull out of hole on wiper trip from 8970’ to 7640’. Monitor well. Service rig. Replace broken bolt. Replace cap gasket on #2 mud pump. Run back in hole from 7640’ to 8900’. Kelly up and wash down from 8900’ to bottom at 8970’. Work on washed-out cap gasket on #2 mud pump. Drill from 8970’ to 9058’. Cease drilling ahead after slow progressive pump deterioration, and failure to maintain sufficient dynamic discharge from at least two pumps. Continue pumping and reciprocating on #3 mud pump while repairing isolation valve on #2 mud pump. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 16, 2014 DEPTH 9058 PRESENT OPERATION Running back in hole after repairing Top Drive TIME 24:00 YESTERDAY 9058 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9058 (Projection) 0.62 142.32 8712.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 2221 39.03 In Hole 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 9058 / 8713 TVD MW 9.4 VIS 60 PV 25 YP 25 FL 4.6 Gels 5/7/7 CL- 16000 FC 1 SOL 6.0 SD 0.1 OIL 3/91 MBT 7.0 pH 9.4 Ca+ 40 Alk 1.5 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 N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY (Note: break and lay down last joint to 9033’ before reciprocating, then pull another joint to 8970’). Continue to circulate and reciprocate pipe on #3 mud pump, while repairing the pumps. Replace internal parts on 4” Demco isolation valve to #2 mud pump. Replace the #1 pod on #2 mud pump. Increase the lubricant concentration in the drilling mud to 3%. Gas circulated down to zero units. During circulating and reciprocating, observe hydraulic leak in Top Drive. Slowly work pipe back down to 9023’ while pump repairs are being completed. Pull back to 8970’ and put all three pumps on line with no problems at high rate. Wash down to 9032’. With hydraulic leak getting worse, decision made to pull to the shoe to repair Top Drive. Begin pulling out of hole from 9032’. (Pull tight, slow and working pipe the first 3 stands to 8842’, then pull progressively easier and faster). Pull out of hole 10 stands to 8407’. Pump dry job (31 bbls, 10.1 ppg). Continue pulling out of hole from 8407’ to 2829’ (just inside shoe). Repair hydraulic valve block 0-rings and extend pin. Check crown-o-matic. Run back in hole from 2829’ to 4684’. Fill pipe. Continue to run back in hole from 4684’ to 5000’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 17, 2014 DEPTH 9524 PRESENT OPERATION Drilling ahead TIME 24:00 YESTERDAY 9058 24 HOUR FOOTAGE 466 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9040 0.55 139.68 8694.73 9167 0.76 114.46 8821.72 9292 0.99 128.97 8946.71 9416 1.30 130.15 9070.68 9542 1.71 132.28 9196.64 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 2687 48.81 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 199.0 @ 9103 1.9 @ 9261 56.1 51.2 FT/HR SURFACE TORQUE 20430 @ 9064 n/a @ Torq failure n/a n/a AMPS WEIGHT ON BIT 22 @ 9329 0 @ 9076 13.4 12.3 KLBS ROTARY RPM 26 @ 9061 n/a @ Rpm failure n/a n/a RPM PUMP PRESSURE 2865 @ 9446 1497 @ 9206 2563.2 2136.2 PSI DRILLING FLUIDS REPORT DEPTH 9429 / 9084 TVD MW 9.4 VIS 56 PV 18 YP 20 FL 4.6 Gels 4/5/6 CL- 17000 FC 1 SOL 6.0 SD 0.1 OIL 3/91 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.9 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 192 @ 9300 8 @ 9287 25.6 TRIP GAS CUTTING GAS @ @ WIPER GAS 240 (at 9058) CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 38342 @ 9300 1621 @ 9287 5094.2 CONNECTION GAS HIGH ETHANE (C-2) 151 @ 9300 0 @ 9411 13.7 AVG PROPANE (C-3) 47 @ 9300 0 @ 9411 5.1 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 10 / 25 PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE in this interval. All high gases recorded from coals. Highest gas from any sand is 29 units. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Sandstone/Sand/Other Sandstone, Coal/Carbonaceous Shale, Tuffaceous Siltstone-Claystone, Volcanic Ash. Minor Conglomeratic Sand/Conglomerate. Trace Calcareous Tuff PRESENT LITHOLOGY ..........TUFFACEOUS SANDSTONE..........COAL.......... DAILY ACTIVITY SUMMARY Continue to run in hole from 5000’, filling pipe every 2000’. Tag up at 9019’. Pull back up to 8970’ and kelly up. Wash and ream from 8972’ to 9058’. Drill from 9058’ to 9070’. Record 240 units of wiper gas. Start losing pump pressure just after bottoms up (from 2200psi to 1700psi). Note trouble issues. Monitor well for flow, and well is static. (Pump pressure falls off to 1200psi). Pull out of hole from 9070’ looking for washout. Find washout in joint at 7246’. Lay down washed out single and pick up and make up new single (of same length). Run back in hole from 7246’ to 8187’. Kelly up. Wash and ream from 8187’ to 9070’. Record 42 units of wiper gas. Drill from 9070’ to 9524’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML 3200 REPORT BY Craig Silva Cook Inlet Energy Noth Fork Unit DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 18, 2014 DEPTH 9750 PRESENT OPERATION Pulling out of hole TIME 24:00 YESTERDAY 9524 24 HOUR FOOTAGE 226 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9542 1.71 132.28 9196.64 9603 1.48 130.72 9257.61 9668 1.82 131.50 9322.58 9693 1.90 132.41 9347.56 9750 (Projection) 1.90 132.41 9404.53 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 2913 55.30 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 150.5 @ 9728 1.4 @ 9531 46.3 16.5 FT/HR SURFACE TORQUE 0 @ 0 @ Sensor failure AMPS WEIGHT ON BIT 17 @ 9532 1 @ 9735 9.3 3.0 KLBS ROTARY RPM 0 @ 0 @ Sensor failure RPM PUMP PRESSURE 2726 @ 9532 2136 @ 9524 2613.7 2565.9 PSI DRILLING FLUIDS REPORT DEPTH 9750 / 9405 TVD MW 9.4 VIS 56 PV 18 YP 20 FL 4.6 Gels 4/5/6 CL- 23000 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 220 @ 9734 10 @ 9532 29.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 136 (at 9750') CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 43589 @ 9734 2134 @ 9532 5887.6 CONNECTION GAS HIGH ETHANE (C-2) 175 @ 9734 0 @ 23.3 AVG PROPANE (C-3) 65 @ 9734 0 @ 10.8 CURRENT BUTANE (C-4) 22 @ 9734 0 @ 0.6 CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ 0 @ 0.0 HYDROCARBON SHOWS All of the highest gases appeared to be from coals, Gas from sand intervals ranged from 10-35 units, with the exception of a single 2' interval at 9739'-9740' with gas to 85 units. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Major Tuffaceous Sandstone/Sand/Other Sandstone, Coal/Carbonaceous Shale, Tuffaceous Siltstone-Claystone, Volcanic Ash. Minor Conglomeratic Sand/Conglomerate. Trace Calcareous Tuff. PRESENT LITHOLOGY ..........TUFFACEOUS SANDSTONE..........TUFFACEOUS SILTSTONE-CLAYSTONE.......... DAILY ACTIVITY SUMMARY Continue to drill from 9525’ to 9537’. Make a connection. Detect washout at top of current stand (stand 139). Set stand back and pick up next stand (stand 140). (Note 15’ difference). Continue to drill from 9537’ to 9750’. Circulate and wait on orders. Decision made that 9750’ will be Total Depth of well. Circulate bottoms up. Take slow pump rate. Monitor well and well is static. Pull out of hole wet from 9750’ to 9600’. Kelly up. Wash and wipe hole from 9600’ to 9540’. (Hole taking proper fill). Continue pulling out of hole from 9540’ to 8533’. Monitor well and well is static. Hold BOP drill (and note 3 minute response time). Run back in hole from 8533’ to 9662’. Kelly up. Wash down from 9662’ to 9750’. Tag bottom and start circulating bottoms up. Start and pump around Hi-Vis sweep. Record 136 units of wiper gas. Pump 3 bottoms ups total. Check for flow. Pull out of hole 10 stands to 9097’. Pump 20 bbl dry job. Continue pulling out of hole from 9097’ to 3174’. Rig up to pull the rest of the way out of hole laying down drill pipe. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 19, 2014 DEPTH 9750 PRESENT OPERATION Rigging down after testing BOPE TIME 24:00 YESTERDAY 9750 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2938' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9750 (Projection) 1.90 132.41 9404.53 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2R1 8.75 NOV SKH519M A19180 5x15 6837 9750 2913 55.30 1-2-CT-C-X-I-WT-TD T.D. of well 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 9750 / 9404 TD MW 9.4 VIS 56 PV 18 YP 20 FL 4.6 Gels 4/5/6 CL- 21000 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.8 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 rig up for laying down drill pipe. Pull out of hole laying down 5” drill pipe from 3174’ to 909’. Service rig, Monitor well. Well is static. Fill trip tank. Continue pulling out of hole laying down 5” drill pipe and HWDP to top of flex collars at 198’. Break and lay down flex collars, sub and stabilizer to stop sub at 125’. Clean and clear rig floor. Pull to CCN tool and remove radioactive sources. Pull, break and lay down all remaining LWD/Directional tools and bit. Pull wear ring. Test BOPE as per C.I.E. procedures. Install 5” test joint and rig up all test equipment. Test annular to 250 psi Low / 2500 psi High for 5 minutes each. Test other BOPE (all other valves and rams) to 250 psi Low / 4000 psi High for 5 minutes each. Rig down test equipment. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML 3200 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 20, 2014 DEPTH 9750 PRESENT OPERATION Running in hole with 7" casing TIME 24:00 YESTERDAY 9750 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" at 2938' 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 9750 / 9404 TVD MW 9.4 VIS 80 PV 15 YP 16 FL 4.6 Gels 3/5/5 CL- 21000 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 10 (at 2938 shoe) 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 Prep rig floor, and rig up to test 7” casing rams. Set 7” test plug. Test 7” casing rams to 250 psi Low / 3000 psi High for 10 minutes. Rig down test equipment. Pull and lay down test joint. Blow down topdrive, choke manifold and all related mud lines. Prep and rig up to run 7” casing. Finish rig up of Weatherford casing tongs, air slips and elevators. Run 7” production casing as per C.I.E.. Pick up, make up and run in hole 7” shoe track to 128’. Test floats. Floats held. Continue picking up, making up and running in hole with 7” casing from 128’ to surface casing shoe at 2938’. Kelly up and circulate surface to surface. Record 10 units shallow trip gas. Continue running in hole with 7’ casing from 2938’ to 3949’. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML 2100 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 21, 2014 DEPTH 9750 PRESENT OPERATION Finished running 7" production casing. Preparing to cement. TIME 24:00 YESTERDAY 9750 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 2938' 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 9750 / 9404 TVD MW 9.4 VIS 80 PV 15 YP 16 FL 4.6 Gels 3/5/5 CL- 21000 FC 1 SOL 6.0 SD 0.1 OIL 2/92 MBT 7.0 pH 9.5 Ca+ 40 Alk 1.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 275 (at 8944) 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 23 / 33 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Fill 7” casing on the fly while running in, and topping off every 10stands. Continue running in hole with 7” production casing from 3949’ to 6267’. Kelly up and break circulation, staging up pump output from 80 gpm to 350 gpm with no losses. Rotate casing 15 rpm. Torque to rotate leveled off at 10K. Shut down rotary. Continue to circulate and reciprocate with no rotary for 2 bottoms ups. Record 136 units of trip gas at 6267’. Continue running 7” casing in hole from 6267’ to 8405’. Check actual displacement to calculated and record 5 bbl lost to hole at that point. Swap over to 200 ton elevators. Continue running in hole from 8405’ to 8944’. Hole tight. Kelly up and attempt to pump at reduced rate. Rotate casing at 15K torque. Attempt to work free. Able to start increasing travel distance, and staging up pump output, while working casing. Record 275 units of trip gas from 8944’ while working casing. Work casing free, start pumping at higher rates and wash through tight hole zone. Continue running 7” casing in hole, washing down and rotating as needed, from 8944’ to end of run at 9734’. Record maximum gas of 77 units while washing down after 8944’. Circulate and reciprocate surface to surface at 9734’. Record maximum 66 units of trip gas at bottom of 7” casing run. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML 2100 REPORT BY Craig Silva Cook Inlet Energy North Fork Field DAILY WELLSITE REPORT North Fork Unit # 24-26 REPORT FOR Rod Maniaci Monie Sainz DATE Dec 22, 2014 DEPTH 9750 PRESENT OPERATION Laying down 5" drill pipe TIME 24:00 YESTERDAY 9750 24 HOUR FOOTAGE 0 CASING INFORMATION 7" at 9725' 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 9750 / 9404 TVD MW 8.5 VIS Brine PV YP FL Gels CL- FC SOL 3% KCL SD OIL MBT pH Ca+ Alk 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 Lay down working joint and CRT tool. Blow down topdrive. Pick up landing joint. Rig up and install cementing head and load plugs. Circulate and reciprocate at 8 bpm with no losses. Hold pre-job meeting on cementing procedures with Baker cementers and all rig hands. Prime lines and kick out bottom plug with 5 bbls of water. Pressure test lines to 4000 psi. Bleed off pressure. Batch up and pump 40 bbls of 10.5ppg Sealbond Spacer, then batch up and pump 161 bbls of 12.7ppg lead cement. Reciprocate during all the cement pumping. Batch up and follow lead cement by pumping 99 bbls 13.5ppg tail cement. Shut down and flush 1502 treating iron to rig cellar with 5 bbls water. Drop top plug. Line back up to well and displace cement with 369 bbls 8.5ppg brine. Plug bumped (at 09:00 hrs) at 370 bbls away. Floats holding. Get 3.5 bbls back. Blow down cementing lines and all associated mud lines. Clear rig floor of all cementing equipment. Back out and lay down landing joint. Swap elevators and bails. Install packoff and test to 5000psi. Clean rig floor. Rig up to lay down drill pipe. Lay down all remaining drill pipe. (Continue with all remaining procedures before completion phase: finish laying down drill pipe, run test plug and test BOPs , set wear bushing, pick up tubing string with mill and scrapers and clean out casing, test casing, run CBL). CANRIG PERSONNEL ON BOARD 2 DAILY COST DML 2280 Rig Down 2300 REPORT BY Craig Silva